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214-056
From:Smith, Travis T To:Loepp, Victoria T (OGC) Cc:Earhart, Will C Subject:CRU CD4-96 (PTD#214-056) High IA Pressure Date:Monday, July 12, 2021 5:15:08 PM Attachments:CD4-96A.pdf CD4-96 90-day TIO.pdf Victoria— CRU producer well CD4-96 (PTD#214-056) has exhibited elevated IA pressure in excess of 2000 psi. The well is currently shut-in due to the Alpine facility turnaround. The IA pressure is currently at 1733 psi after having been bled. The production casing is 7” 26# L80 with a burst rating of 7240 psi. We will pursue diagnostics to determine if the high pressure is coming from a downhole source or the gas lift manifold at surface and address as appropriate. A 90-day TIO and well schematic are attached. Please let me know if you have any questions or disagree with the plan. Thanks, Travis Smith WNS Intervention & Integrity Engineer 907-670-4014 Travis.T.Smith@conocophillips.com Annular Communication Surveillance 13-Apr-2021Well Name:CD4-96 Start Date:13-Apr-2021 12-Jul-2021Days:90 End Date:12-Jul-2021 50 60 70 80 90 100 110 120 130 140 150 0 500 1000 1500 2000 2500 13-Apr-2116-Apr-2119-Apr-2122-Apr-2125-Apr-2128-Apr-211-May-214-May-217-May-2110-May-2113-May-2116-May-2119-May-2122-May-2125-May-2128-May-2131-May-213-Jun-216-Jun-219-Jun-2112-Jun-2115-Jun-2118-Jun-2121-Jun-2124-Jun-2127-Jun-2130-Jun-213-Jul-216-Jul-219-Jul-2112-Jul-21Temperature (degF)Pressure (PSI)Pressure Summary WHP IAP OAP WHT 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1 13-Apr-21Injection Rate (BPD or MSCFD)Injection Rate Summary DGI MGI PWI SWI BLPD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: ELINE 15,216.0 7/8/2014 CD4-96A postojl Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: T/S failed TIFL 10/31/2020 CD4-96A claytg Casing Strings Casing Description INTERMEDIATE OD (in) 9 5/8 ID (in) 8.84 Top (ftKB) 1,565.8 Set Depth (ftKB) 13,260.0 Set Depth (TVD) … 6,924.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-M Casing Description 7" PRODUCTION TIE- BACK OD (in) 7 ID (in) 6.28 Top (ftKB) 33.8 Set Depth (ftKB) 12,776.4 Set Depth (TVD) … 6,715.4 Wt/Len (l… 26.00 Grade L80 Top Thread BTCM Casing Description LINER 7" OD (in) 7 ID (in) 6.28 Top (ftKB) 12,765.4 Set Depth (ftKB) 15,220.0 Set Depth (TVD) … 7,491.6 Wt/Len (l… 26.00 Grade L80 Top Thread Ten Blue Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 12,765.4 6,710.3 62.42 PACKER BAKER LINER TOP PACKER. 6.200 12,789.2 6,721.2 62.66 NIPPLE RS NIPPLE 6.200 12,792.0 6,722.5 62.69 HANGER FLEX-LOCK LINER HANGER 6.220 Casing Description LINER 4 1/2" OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 14,952.3 Set Depth (ftKB) 19,293.0 Set Depth (TVD) … 7,556.1 Wt/Len (l… 12.60 Grade C-110 Top Thread H521 Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 14,952.3 7,449.4 77.11 PACKER Baker 5" x 7" HRD ZXP Liner Top Packer 4.340 14,972.3 7,453.8 77.52 NIPPLE BAKER RS NIPPLE 4.250 14,975.2 7,454.4 77.57 HANGER BAKER FLEX-LOCK LINER HANGER 4.370 14,984.3 7,456.3 77.75 SBE BAKER SEAL BORE 4.000 15,897.5 7,514.2 88.67 SLEEVE PETROQUIP SLIDING SLEEVE OPEN 5/16/2015 2.813 16,703.8 7,521.9 89.42 SWELL PACKER TAM SWELL PACKER, HYBRID ACTIVATED 3.958 17,108.5 7,525.5 88.62 SWELL PACKER TAM SWELL PACKER, HYBRID ACTIVATED 3.958 17,801.7 7,540.6 90.08 FRAC SLEEVE BAKER FRAC SLEEVE ( MILLED OUT TO 2.70" ID) 2.700 18,582.7 7,551.2 89.38 FRAC SLEEVE BAKER FRAC SLEEVE ( MILL OUT TO 2.70" ID) 2.700 19,237.0 7,555.1 89.04 FRAC SLEEVE BAKER PRESSURE SLEEVE 3.860 19,243.7 7,555.2 89.04 VALVE WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 31.4 Set Depth (ft… 14,999.2 Set Depth (TVD) (… 7,459.5 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.4 31.4 0.00 HANGER HANGER, ELASTOMER 3.900 113.0 113.0 0.16 XO REDUCING XO, 4.5 IBTM BOX x 3.5 EUE PIN 2.992 2,111.0 1,942.2 46.96 SAFETY VLV CAMCO TRMAXX-5E W/ 2.813' X PROFILE 2.812 14,872.8 7,430.6 75.68 GAUGE SLB SOLID GAUGE MANDREL 2.913 14,919.8 7,441.9 76.46 NIPPLE X NIPPLE W/ 2.813" PROFILE 2.813 14,952.7 7,449.5 77.12 SEAL ASSY BAKER GBH-22 SEAL ASSY 2.980 Frac Summary Start Date 2/18/2015 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 2/18/2015 Top Depth (ftKB) 17,801.0 Btm (ftKB) 17,802.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Start Date 2/23/2015 Proppant Designed (lb) Proppant In Formation (lb) Stg # 1 Start Date 2/23/2015 Top Depth (ftKB) 19,237.0 Btm (ftKB) 19,238.0 Link to Fluid System Vol Clean (bbl) Vol Slurry (bbl) Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 5,303.9 3,430.0 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 2,013.0 3/2/2015 2 10,326.0 5,663.1 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,976.0 3/2/2015 3 13,838.1 7,138.4 CAMCO KBMG 1 GAS LIFT OV BK 0.250 10/31/2020 Notes: General & Safety End Date Annotation 5/16/2015 NOTE: CMD UP TO CLOSE/DOWN TO OPEN 9/25/2014 NOTE: 7”, 29#, TN110, H563 From 14,784.33' to 15,220' MD 9/25/2014 NOTE: 7", 26#, L80, Tenaris Blue from 12765.40' to 14,784.33' MD HORIZONTAL, CD4-96A, 11/1/2020 6:54:27 AM Vertical schematic (actual) LINER 4 1/2"; 14,952.3-19,293.0 FRAC; 19,237.0 FRAC; 17,801.0 LINER 7"; 12,765.4-15,220.0 SEAL ASSY; 14,952.7 NIPPLE; 14,919.8 GAUGE; 14,872.8 GAS LIFT; 13,838.1 INTERMEDIATE; 1,565.8- 13,260.0 7" PRODUCTION TIE-BACK; 33.8-12,776.4 GAS LIFT; 10,326.0 GAS LIFT; 5,303.9 SURFACE; 36.6-2,939.0 SAFETY VLV; 2,111.0 CONDUCTOR; 36.6-114.0 XO REDUCING; 113.0 HANGER; 31.4 WNS PROD KB-Grd (ft) 36.60 Rig Release Date 12/16/2013 CD4-96A ... TD Act Btm (ftKB) 19,293.0 Well Attributes Field Name ALPINE Wellbore API/UWI 501032067301 Wellbore Status PROD Max Angle & MD Incl (°) 92.21 MD (ftKB) 15,251.67 WELLNAME WELLBORECD4-96A Annotation Last WO: End DateH2S (ppm) DateComment SSSV:TRDP p 7-D 05-L. yIte, Hanna 2 3 8 S 0 From: Wallace, Chris D (DOA) <chris.wallace@alaska.gov> Sent: Tuesday, November 28, 2017 10:27 AM To: Sylte, Hanna Subject: [EXTERNAL]CRU CD4-96A(PTD 2140560) Sundry 315-044 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.aov. RBDMS 64--L 0 6 2017 1 STATE OF ALASKA AIWA OIL AND GAS CONSERVATION CON.SION 2 8 8 5 1 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon Repair w ellFracture �' p Rug Perforations Perforate Other Alter Casing r' Pull Tubing fl Stimulate-Frac rd Waiver Time Extension Stimulation Change Approved Program rOperat. Shutdown r Stimulate-Other fl Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development T Exploratory 214-056-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-103-20673-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 384209,388077,388902,384211,387209,388905,390337 CRU CD4-96A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Colville River Field/Alpine Oil Pool 11.Present Well Condition Summary: Total Depth measured 19293 feet Plugs(measured) none true vertical 7556 feet Junk(measured) none Effective Depth measured 19244 feet Packer(measured) 12765, 14952 true vertical 7555 feet (true vertical) 6710,7449 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114 114 SURFACE 2902 13.75 2939 2369 INTERMEDIATE 11694 9.625 13260 6924 c/1 c LINER " LINER 7 24552 7 15220 7499 R EC E I Yr' ED LINER 4.5" 4341 4.5 19293 7556 ��p g APR 15 2015 Perforation depth: Measured depth: not perfd SCANNED DEC 1 5 2317. True Vertical Depth: not perfd AOGCC Tubing(size,grade,MD,and ND) 3.5, L-80, 14999 MD, 7460 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER LINER TOP PACKER @ 12765 MD and 6710 TVD PACKER-BAKER HRD ZXP LINER TOP PACKER @ 14952 MD and 7449 TVD SSSV-CAMCO TRMAXX-5E @ 2111 MD and 1942 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 17801-17802, 19237-19238 Treatment descriptions including volumes used and final pressure: 17300#of 16/20 sand and 64193#of 16/20 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 639 3184 148 -- 251 Subsequent to operation 993 1786 515 -- 170 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development 17 Service fl Stratigraphic 16.Well Status after work: Oil 1 7 Gas fl WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ 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: 315-044 Contact Robert Blakney @ 265-6417 Email Robert.G.Blakneyna conocophillips.com Printed Name Robert Blak - Title Sr. Completions Engineer Signature //� Phone:265-6417 Date //q-kc ,,-- APR 1 8 2015 RBDM3J Gbi-J f 210.0.O I E P rc.c c:,,,,-e,,, ,, /sv/�7-- Form 10-404 Revised 10/2012 Submit Original Only' p i x WNS PROD • CD4-96A ConocoPhil ipsØck Well Attributes Max Angle&MD TD Alaska Inc 1 14,1 Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) Conomthaips 501032067301 ALPINE PROD 92.21 15,251.67 19,293.0 •)) - Comment H2O(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date HORIZONTAL-CD4-96A,3/520153.43.22 PM SSSV:TRDP Last WO: 36.60 12/16/2013 Vertical schematic factual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date BANGER,314 Mu,'(: Last Tag:ELINE 15,216.0 7/8/2014 Rev Reason:GLV C/O,FRAC lehallf 3/4/2015 1� 'a L Casing Strings s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread - . . CONDUCTOR 20 19.124 36 6 114.0 114.0 94.00 H-40 Welded TN s Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread i SURFACE 133/8 12.415 36.6 2,939.0 2,369.0 68.00 L-80 BTCM ,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.835 1,565.8 13,260.0 6,924.3 40.00 L-80 BTC-M Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread i € 7"PRODUCTION TIE- 7 6.276 33.8 12,776.4 6,715.4 26.00 L80 BTCM XO REDUCING;113.0` BACK CONDUCTOR;36.6-114.0-4 II l Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread LINER 7" 7 6.276 12,765.4 15,220.0 7,491.6 26.00 L80 Ten Blue Liner Details Il Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 12,765.4 6,710.3 62.42 PACKER BAKER LINER TOP PACKER. 6.200 ri SAFETY VLV,2,111.0 _T 12,789.2 6,721.2 62.66 NIPPLE RS NIPPLE 6.200 12,792.0 6,722.5 62.69 HANGER FLEX-LOCK LINER HANGER 6.220 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I Grade Top Thread r4s LINER 41/2" 41/21 3958 14,952.31 19,293.01 7,556 601C-110 110 IH521 SURFACE; 366-2,939.0 t Liner Details Nominal ID GAS LIFT;5,303.9 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) MIN 14,952.3 7,449.4 77.11 PACKER Baker 5"x 7"HRD ZXP Liner Top Packer 4.340 ia 14,972.3 7,453.8 77.52 NIPPLE BAKER RS NIPPLE 4.250 ;! I GAS LIFT;10,326.0 3 14,975.2 7,454.4 77.57 HANGER BAKER FLEX-LOCK LINER HANGER 4.370 14,984.3 7,456.3 77.75 SBE BAKER SEAL BORE 4.000 15,897.5 7,514.2 88.67 SLEEVE PETROQUIP SLIDING SLEEVE OPEN 2/26/2015 2.813 T PRODUCTION TIE-BACK; 16,703.8 7,521.9 89.42 SWELL TAM SWELL PACKER,HYBRID ACTIVATED 3.958 33.8-12,776.4 PACKER I It 17,108.5 7,525.5 88.62 SWELL TAM SWELL PACKER,HYBRID ACTIVATED 3.958 PACKER 17,801.7 7,540.6 90.08 FRAC SLEEVE BAKER FRAC SLEEVE 2.073 J _7 18,582.7 7,551.2 89.38 FRAC SLEEVE BAKER FRAC SLEEVE 2.010 INTERMEDIATE;1,565.8- 19,237.0 7,555.1 89.04 FRAC SLEEVE BAKER PRESSURE SLEEVE 3-860 13.260.0 GAS LIFT;13,838.1 19,243.7 7,555.2 89.04 VALVE WELLBORE ISOLATION VALVE 0.000 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..i Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO 31/2 2.992 31.4 14,999.2 7459.5 930 L-80 EUE it Completion Details GAUGE;14,872.8 �A1 Nominal ID It Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) I. 314 31.4 0.00 HANGER HANGER,ELASTOMER 3.900 NIPPLE;14,919.8 113.0 113.0 0.16 XO XO,4.5 IBTM BOX x 3.5 EUE PIN 2.992 Ili, REDUCING 2,111.0 1,942.2 46.96 SAFETY VLV CAMCO TRMAXX-5E W/2.813'X PROFILE 2.812 SEAL ASSY;14,952.7 14,872.8 7,430.6 75.68 GAUGE SLB SOLID GAUGE MANDREL 2.913 I=i'r1 .. 14,919.8 7,441.9 76.46 NIPPLE X NIPPLE W/2.813"PROFILE 2.813 I i14,952.7 7,449.5 77.12 SEAL ASSY BAKER GBH-22 SEAL ASSY 2.980 Stimulations&Treatments Min Top Max Btm r ... Depth Depth Top(TVD) Bier(ND) KIIIIIIT (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com LINER 7";12765.4-15,220.0 17,801.0 17,802.0 7,540.6 7,540.6 FRAC 2/18/2015 PUMP 17,3008 16/20 SAND thru open Baker Frac Sleeve at 17801' 19,237.0 19,238.0 7,555.1 7,555.1 FRAC 2/23/2015 FRACTURE STIMULATION THRU SLEEVE AT 19,237-19,238 PLACING 64,1938 OF 16/20 FRAC SAND(SCREENED OUT) Mandrel Inserts St ati Wit' on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Com 1 5,303.9 3,430.0 CAMCO KBMG GAS LIFT GLV BK 0.188 2,013.0 3/2/2015 _ 2 10,326.0 5,663.1 CAMCO KBMG -GAS LIFT GLV BK 0.188 1,976.0 3/2/2015 3 13,838.1 7,138.4 CAMCO KBMG GAS LIFT OV BK 0.250 0.0 3/2/2015 Ur Notes:General&Safety End Date Annotation 9/25/2014 NOTE:7",298,TN110,H563 From 14,784.33'to 15,220'MD 9/25/2014 NOTE:7",268,L80,Tenaris Blue from 12765.40'to 14,784.33'MD FRAC;17801.0 { J- [0 L FRAC;19237.0 f 0 0 I LINER 41/2°;14,952.3-19,293.0 1.11 CD4-96A WELL WORK SUMMARY DATE SUMMARY • • 2/7/2015 PRE FRAC, ENCOUNTER PARAFFIN @ 550' SLM, W/G-RING, ATTEMPT TO SCRATCH W/NO RESULTS, LAY DOWN FOR NIGHT 2/8/2015 ATTEMPT TO DRIFT TBG. ENCOUNTERED PARAFFIN IN SSSV AT 2111'. CUT W/2.80" SCRATCHER, DRIFT TO 5000' SLM, DRIFT W/2.79" G-RING TO 15,000' SLM, SET 3-1/2" PX PLUG BODY WITH PUMP SUPPORT @ 14922' SLM, JOB IN PROGRESS. 2/9/2015 SET PX PRONG @ 14916' SLM, UNABLE TO GET TBG TO HOLD PSI, RUN IN AND RESET PX PRONG, TEST PLUG W/LIL RED TO 3500 PSI, LOST 224 PSI FIRST 15, SECOND 15 LOST 176 PSI, THIRD 10 MIN TEST LOST 80 PSI, LIL RED HAVING MECHANICAL ISSUES, LDFN, LIL RED TO CONTINUE TESTING 2/9/2015 PUMPED 24 BBLS DSL DOWN TBG TO PRESSURE UP PLUG TO 3500 PSI. JOB COMPLETE. 2/10/2015 PULLED 1" OV AT 13,838' RKB. JOB IN PROGRESS. 2/11/2015 PULLED 1" GLV'S @ 10326'AND 5304' RKB, REPLACED w/ 1" DGLV'S. READY FOR CIRC OUT. IN PROGRESS 2/11/2015 PUMPED 330 BBLS OF SEAWATER FOLLOWED BY 80 BBLS DSL DOWN TBG, TAKING RETURNS UP IA TO FLOWLINE OF NEIGHBORING WELL, U-TUBED IA AND TBG TO FREEZE PROTECT BOTH. JOB COMPLETE. 2/13/2015 COMPLETE CIRC OUT w/74 BBLS SEAWATER &80 BBLS DIESEL. SET DV @ 13838' RKB. SET ISO SLEEVE @ 2111' RKB FOR MITT. MITT TO 3600 psi. ***PASS***. PULL ISO SLEEVE @ 2111' RKB. IN PROGRESS. 2/14/2015 PRESSURE TBG UP TO 1500 PSI, THEN MIT-IA TO 3500 PSI, BLEED PRESSURE OFF BOTH JOB COMPLETE 2/14/2015 PULLED PRONG ASSY @ 14920' RKB. DRIFT TREE w/3.89"G.RING TO 35' SLM. UNABLE TO PASS TIGHT AREA. IN PROGRESS. 2/15/2015 PULLED 2.81" PXN PLUG BODY @ 14920' RKB. SET 2.81" FRAC SLEEVE (OAL = 87"/2.84" NO- GO/2.29" DRIFT) @ 2111' RKB. READY FOR FRAC TREATMENT. 2/18/2015 Performed fracture stimulation treatment @ 20 bpm placing 17,300#of 16/20 frac sand, 95% of design. Well freeze protected w/ 17 bbls of diesel. Will return for more stages after coil shifts sleeve. 2/19/2015 PULLED FRAC SLEEVE @ 2111' RKB. READY FOR COIL. 2/21/2015 RIGGED UP ON WELL, DICOVERED COUNTER PROBLEMS AFTER RIH TO 500'. POOH TO FIX COUNTER, WHEN STACKING DOWN TO FIX COUNTER FOUND CTC WAS LEAKING. CUT 50' OF PIPE TO GET A GOOD PT ON A CONECTOR. RE-START IN THE MORNING, IN PROGRESS. 2/22/2015 SHIFT SLIDING SLEEVE CLOSED @ 15898' RKB. READY FOR SLICKLINE TO SET FRAC SLEEVE. 2/22/2015 SET FRAC SLEEVE (OAL = 80"/2.84" NO-GO/2.29" DRIFT) @ 2111' RKB. READY FOR FRAC. 2/23/2015 Attempt toe stage fracture stimulation treatment @ 20 bpm placing 64,193#of 16/20 frac sand before screen out, able to pump 49 bbls total flush, 10 bbls diesel in well. 2/24/2015 PULLED FRAC SLEEVE @ 2111' RKB. READY FOR CTU. 2/25/2015 SLB CTU #4: PERFORM FRAC SAND FILL CLEAN OUT FROM 4929'TO 17700' (END OF COIL) WITH JET SWIRL NOZZLE AND SLICK SEAWATER AND FLOW-VIS SWEEPS. MAINTAIN 1:1 RETURNS THROUGHOUT. MODERATE TO HEAVY SAND CONCENTRATIONS OBSERVED DURING, EST TOTAL SOLIDS VOLUME AT 87 BBLS, MAKE UP SHIFTING TOOL BHA TO OPEN SLIDING SLEEVE AT 15898' IN PROGRESS -24 HOUR OPERATIONS. 2/26/2015 SLB CTU#4: SHIFT OPEN CMD SLIDING SLEEVE AT 15898' RKB, BULLHEAD 55 BBLS OF DIESEL DOWN THE TBG TO F/P DOWN TO 3900'TVD, READY FOR S/L, JOB COMPLETE. 2/26/2015 GUAGE TBG AND BRUSH AND FLUSH TO 14,920' RKB. SET 2.81"XX PLUG @ 14,920' RKB. PULLED DV @ 13,838' RKB. JOB SUSPENDED DUE TO WIND. 3/1/2015 SET OV(1/4" PORT) @ 13,838' RKB. PULLED DV AND SET GLV(3/16" PORT, TRO=1976) @ 10,326' RKB. PULLED DV AND SET GLV(3/16" PORT, TRO=2013) @ 5304' RKB. PULLED XX PLUG @ 14920' RKB. PERFORMED GOOD CLOSURE TEST ON SSSV. COMPLETE 3/18/2015 SPEAR 5 BBLS METHANOL DOWN IA FOR FLOWBACK JOB COMPLETE ! • Client: ConocoPhillips Alaska Inc. i �� ` Well: CD4-96A r)' Basin/Field: Colville Prudhoe Basin- Alpine State: Alaska County/Parish: North Slope Borough Case: 631561372 Disclosure Type: Post-Job Well Completed: 2/23/2015 Date Prepared: 3/4/2015 1:49 PM Report ID: RPT-35386 Fluid Name&Volume Additive Additive Description Concentration Volume B882 Guar Polymer Slurry 8 Gal/1000 Gal 725.0 Gal F103 Surfactant 1.2 Gal/1000 Gal 105.0 Gal J134 Breaker 0.8 Lb/1000 Gal 75.0 Lb J475 Breaker 8.8 Lb/1000 Gal 797.0 Lb Proppant Transport 90,658 Gal J532 Crosslinker 4.2 Gal/1000 Gal 380.0 Gal L065 Scale Inhibitor 2.1 Gal/1000 Gal 192.0 Gal M002 Additive0.7 Lb/1000 Gal 60.0 Lb M275 Bactericide 0.9 Lb/1000 Gal 78.0 Lb S522-1620 Propping Agent varied concentrations 107,436.0 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)* 86.40898 % 66402-68-4 Ceramic materials and wares,chemicals 12.41152 % 64742-47-8 Distillates(petroleum),hydrotreated light 0.38392 % 9000-30-0 Guar gum 0.34611 % 56-81-5 1,2,3-Propanetriol 0.10258 % 7727-54-0 Diammonium peroxodisulphate 0.07509 % 1303-96-4 Sodium tetraborate decahydrate 0.06155 % 107-21-1 Ethylene glycol 0.04435 % 129898-01-7 2-Propenoic acid,polymer with sodium phosphinate 0.04148 % 111-76-2 2-butoxyethanol 0.01822 % 67-63-0 Propan-2-ol 0.01822 % 25038-72-6 Vinylidene chloride/methylacrylate copolymer 0.01628 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite 0.01000 % 34398-01-1(7E0) Linear C11 alcohol ethoxylate(7eo) 0.00911 % 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo) 0.00911 % 68131-39-5 C12-15 alcohol ethyoxylated 0.00911 % 9012-54-8 Hemicellulase enzyme 0.00866 % 7647-14-5 Sodium chloride 0.00838 % 1310-73-2 Sodium hydroxide(impurity) 0.00716 % 7631-86-9 Silicon Dioxide 0.00615 % 91053-39-3 Diatomaceous earth,calcined 0.00451 % 10043-52-4 CALCIUM CHLORIDE 0.00423 % 108-32-7 4-methyl-1,3-dioxolan-2-one 0.00308 % 10377-60-3 Magnesium nitrate 0.00090 % 14807-96-6 Magnesium silicate hydrate(talc) 0.00050 % 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one 0.00048 % _ 7786-30-3 Magnesium chloride 0.00045 % 111-46-6 2,2"-oxydiethanol(impurity) 0.00045 % 68153-30-0 Amine treated smectite clay 0.00038 % 9002-84-0 poly(tetrafluoroethylene) 0.00021 % 2682-20-4 2-methyl-2h-isothiazol-3-one 0.00015 % 7447-40-7 Potassium chloride(impurity) 0.00013 % 14808-60-7 Crystalline silica(impurity) 0.00009 % 14464-46-1 Cristobalite 0.00009 % 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. Page:1/1 SCW720 DISCLOSURE-473 gals pumped Trade name CAS# % by mass Water 7732-18-5 48.4% Ethylene glycol 107-21-1 30.0% Polymer Nonhazardous Trade Secret 19.4% Calcium chloride (CaCl2) 10043-52-4 2.0% Potassium chloride 7447-40-7 0.1% Sodium chloride 7647-14-5 0.1% ConocoPhillips a554{( TRANSMITTAL FROM: Sandra D. Lemke, AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD4-96A/CD4-96APB1 DATE: 03/18/2015 Transmitted: Colville River Unit, Alaska CD4-96A/CD4-96APB1 �(�Q� �ccJ 1 CD and hardcopy report 1 ; tb REVISED-portion of the log display missing in original distribution i u�1 v Halliburton-Surface data logging and End of Well report- mud logging data for CD4-96A/CD4-96APB1; 08/26/2014; I general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 color log print each: CD4-96A Formation Evaluation 2"MD Gas ratio 2" MD Drilling Engineering 2"MD rI CD4-96APD1 SCANNED JUL 3 12015 Formation Evaluation 2"MD 'Gas ratio 2"MD Drilling Engineering 2"MD Please promptly sign, scan and return electronically to Sandra.D.LemketaCOP.com CC: CD4-96A - transmittal folder, production well files, eSearRECEIVED 3 1 Receipt A .._ _ - ' Date: AOGCC 615-Technical Data Management I ConocoPhillips i Anchorage, Alaska I Ph: 9072656947 LK-o S LQ CIV D ConocoPhillips APR 272015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 April 23, 2015 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 SCANNED M4' 0 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet 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, MJ oveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Gement, Corrosion inhibitor, Sfnlavy,Top-off Report of Sundry Operations(10-404) Alpine Field Date 4/23/2016 CD4 PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal 7.10 CD4-96 50103206730000 21405600 33" N/A 33" N/A 12.3 4/20/2015 CD4-209 50103205320000 20606500 19' 1.24 20" 4/3/2015 _ 7.6 4/20/2015 CD4-213 50103205400200 21200500 15" N/A 15" N/A 4.5 3/24/2015 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. al 14 _ 05/ Well History F' Identifier Organizing(done) wo-sided ❑ Rescan Needed RE AN: OVERSIZED: NOTES: Vcor Items: ❑ Mas: Grayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: all Date: 3 a /6-- /s/ rriP Project Proofing BY: Maria Date:3/4:2-7//5- /s/ iinf Scanning Preparation7 x 30 = �I 0 + d4-� = TOTAL PAGES c� r (Count does not include cover sheet) BY: Date: 3 a„ J /s/ Production Scanning Stage 1 Page Count from Scanned File: c ..3 1P(Count does include cover s eet) Pa•a Count Matches Number in Scann'ng Pre aration: YES NO /l4 BY: de, Date: 3 a+/ IS' /s/ IStage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: do NO TOTAL PAGES: (( 2 Digital version appended by: Meredith Michal Date: 313))l5 /s/ Final Page9 Count: Stage 1 + Stage 2: TOTAL PAGES: 3 4- " Scanning is complete at this point unless rescanning is required. 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T c a `° 2N co O Q I/^� 6 Z L L o v 1 T E U a Es 3 Q 2 o 2 Z O c) I�, com co w } Ic) } hico . u1 Ce t O it O N To m CL JU rn 0 J p W = ui N et a O 1° N a 0 it E w W z J Nco co J CT) CL 0 — E J E O Q - m Z °8 ,— o i N Q ` 0• 0 N J o. C coJ a) _ -° E 0. co0 2 o U I cp ii= o 1 O N a ✓ U 9(.1 c. d oN } O E Q a o E to v 11 v EE f- •cr `o 5 : Pr/3 z/ y-- o 5�- Loepp, Victoria T (DOA) From: Blakney, Robert G <Robert.G.Blakney@conocophillips.com> Sent: Tuesday, March 24, 2015 8:31 AM To: Loepp, Victoria T (DOA) Subject: RE:CD4-96a hydraulic fracturing 10-404 (PTD 214-056) Follow Up Flag: Follow up Flag Status: Flagged Thank you Victoria, -Robbie From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent: Tuesday, March 24, 2015 8:25 AM To: Blakney, Robert G Subject: [EXTERNAL]RE: CD4-96a hydraulic fracturing 10-404 Robbie, Thanx for the notification. Approval is granted to submit the 10-404 for the entire frac when the remaining stages have been pumped in mid-April. Victoria From: Blakney, Robert G [mailto:Robert.G.Blakney@conocoDhillips.com] Sent: Monday, March 23, 2015 1:48 PM To: Loepp, Victoria T(DOA) Subject: CD4-96a hydraulic fracturing 10-404 Victoria, On 2/23/2015,we screened-out during hydraulic fracturing operations of CD4-96a. We had to suspend cleanout operations on 2/26/2015, due to Doyon 19 moving to CD4-93a and covering up CD4-96a. We plan to frac the remaining stages of CD4-96a once the rig moves off CD4-93a (—mid-April). I want to make sure the state is aware of the current situation, as CPAI will not submit a 10-404 for CD4-96a until we have hydraulically fractured the remaining stages(mid-late April). Please let me know if you have any questions. Thanks, -Robbie Robert Blakney ConocoPhillips Senior Completions Engineer 907-265-6417 (office) 505—804- 5246 (cell) ATO 1740, 700 G st. Anchorage, AK 1 21 4056 E EIVED 2 5 5 4 1 ConocoPhillipsMA�t 19 2015 2 5 5 4 2 AOGCC TRANSMITTAL D DATA LOGGED CONFIDENTIAL DATA 3,Z,LOGGE /201 M.K.BENDER FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: CD4-96A/CD4-96APB1 DATE: 03/18/2015 Transmitted: Colville River Unit, Alaska CD4-96A/CD4-96APB1 1 CD and hardcopy report Halliburton-Surface data logging and End of Well report- mud logging data for CD4-96A/CD4-96APB1; 08/26/2014; general information, daily summary, days vs. depth, after action review, mud record, bit record, morning reports, survey reports; color log presentations, one set each for wellbore 1 color log print each: CD4-96A Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD CD4-96APB 1 Formation Evaluation 2" MD Gas ratio 2" MD Drilling Engineering 2" MD Please promptly sign, scan and return electronically to Sandra.D.Lemkec COP.com CC: CD4-96A - transmittal folder, production well files, eSearch Receipt: pM/4424a`Lroduct 13) «,,. AI . . .. GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph: 907.265.6947 Env Air lirommomumommoomm ..- OF Tfj� �w �\�yy� s THE STATE Alaska Oil and Gas �w � ' ofLAS ;. Conservation Commission 333 West Seventh Avenue of rh„� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALASY' Fax: 907 276 7542 www.aogcc.alaska.gov Robert Blakney Sr. Completions Engineer O 5 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CRU CD4-96A Sundry Number: 315-044 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 7 -Se)/ Daniel T. Seamount, Jr. Commissioner DATED this day of February, 2015 Encl. RECE MED ,, ' STATE OF ALASKA I•. AL .A OIL AND GAS CONSERVATION COMM. ,ON JAN 2 72015 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCC 1.Type of Request. Abandon r Plug for Redrill r Ferf orate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re-enter Susp.Well r Stimulate p •Alter casing r Other:Fracture Stimulation r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development r, 214-056-0 1 3.Address. Stratigraphic r Service "' 6 API Number P.0. Box 100360,Anchorage,Alaska 99510 50-103-20673-01 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? co 10.513 Will planned perforations require spacing exception') Yes r No 17 J CRU CD4-96A ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 384209,388077,388902,384211,387209,388905,390337 Colville River Field/Alpine 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): 19293 • 7556 - 19244' • 7555' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20 114' 114' SURFACE 2902 13.375 2939' 2369' INTERMEDIATE 11694 9.625 13260' 6924' LINER 7" 12742' 7 12776' 6716' LINER 2455 7 15220' 7499' LINER 4.5" 4341 4.5 19293' 7556' Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft). not perfd not perfd 3.5 L-80 14999 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER LINER TOP PACKER ` MD=12765 TVD=6710 PACKER-BAKER 5"x 7"HRD ZXP LINER TOP PACKER ' MD=14952 TVD=7449 SSSV-CAMCO TRMAXX-5E • MD=2111 TVD=1942 12.Attachments: Description Surrmary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development p' Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/7/2015 Oil p. Gas r WDSPL r Suspended r 16.Verbal Approval. Date: WINJ j"' GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact. Robert Blakney @ 265-6417 Email: Robert G Blakney@conocophillips.com Printed Name Robert lak Title: Sr. Completions Engineer / -7 j Signature Phone.265-6417 Date /1/ / IS Commission Use Only ` ' / Sundry Number: ✓"Qyg Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r '!3 Other: f o cf ea bo-el rtr/re.4 'I''D I �cFoc,us CA&m -t Bl idesure & iJ117 f www. ci0.cFocus.0r� 60h)5 �/o a.r regu inev .�-s ofr 20 /MC- 2S. 2 b'3 . I m W Li- Spacing Exception Required? Yes ❑ No V Subsequent Form Required: ICI- 4 O 4 /-- APPROVED BY 441Approved by: COMMISSIONER THE COMMISSION Date: 2 rov II a n l v Ildnnto 11 m the trimT .date of a royal. 0 (Revised10/2012) PP I /� C�'1 y — pp � -y-�Du Ca Form 10-403 � �� Submit Form and Attachments in Duplicate yr . z/3//5 yorlii C30w/i/2.Q/io,r CD4-96a Hydraulic Fracturing Sundry Application Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners an operators within one-half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1). / TO THE ALASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) VERIFICATION OF FACTS AND Commission in the Matter of the ) AFFIDAVIT OF DORA I.SORIA. Request of Conoco Alaska, Inc. for ) Hydraulic fracturing for CPAI ) CD4-96A under the Provisions ) of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Dora I. Soria, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Dora Soria. I am over 19 years old and have personal knowledge of the matters set forth herein. 2. I am a Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI"). 3. I am acquainted with the facts associated with the drilling of CD4-96A Well ("Well"). 4. I have reviewed the Application for Sundry Approvals for the proposal that the Well be stimulated by hydraulic fracturing as defined in 20 AAC 25.283(m). To the best of my knowledge and belief all facts therein are true and accurate. 5. Pursuant to 20 AAC 25.283 (1), CPAI, the well operator, prepared a Notice of Operations that is in compliance with the Provision of 20 AAC 25.283. A copy of this notice is attached hereto ("Notice Letter") and includes a plat attached as Exhibit 1 in compliance with 20 AAC 25.283(2). 7. On January 22, 2015, pursuant to 20 AAC 25.283 (1), CPAI sent a copy of the Notice Letter by certified mail to the last known address of all owners, landowners, surface owners, and operators of within a one-half mile radius of the current proposed trajectory stating that upon request CPAI will make a complete copy of the application available and providing CPAI's contact information. These names and addresses are set forth on Exhibit 2 attached to the Notice Letter and CPAI's Application for Sundry Approvals under 20 AAC 25.283 dated January 26, 2015. Subscribed and sworn to this 22nd day of January, 2015. Dora I. Soria STATE OF ALASKA ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 22nd day of January, 2015, by Dora I. Soria. STATE OF ALASKA ''`'\r,41 ,�r;%. "'fffyyy NOTARY PUBLIC �, Nota Public, State of Alaska T. l REBECCA SWENSEN My Commission Expires: v a-7'a0 I Lo 1My Commission Expires Aug.27,2016 4 y/ P.O.Box 100360 ConocoPh i I I i ps P :Anchorage,026K -6297 99510-0360 Phone: 907-263-6297 January 22,2015 CERTIFIED MAIL To: Operator and Owners(shown on Exhibit 2) Re: Notice of Operations pursuant to 20 AAC 25.283(1) CD4-96A Well Colville River Unit,Alaska CPAI No.203488 Dear Operator and Owners: ConocoPhillips Alaska, Inc. as Operator and on behalf of the Colville River Unit working interest owners ("CPAI"), hereby notifies you that it is submitting an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25 0 ("Application")for the CD4-96B Well(the "Well"). This notice of operations is being rovided pursuant to subsection of 20 AAC 25.283 effective January 2015. The Well has been drilled as a directional horizontal well on leases ADLs 388905,388902, 380077,384209,and 384211 as depicted on Exhibit 1 and has locations as follows: Surface Location: 2863.36'FNL,4953.87'FEL, Section 19,TIIN,R5E,UM Target Location: 1997.00'FNL,2118.10'FEL, Section 35,Ti 1N,R4E,UM Bottonthole Location: 5231.14'FNL, 1244.44'FEL,Section 35,T1 IN,R4E,UM Exhibit 1 shows the Well location and the lands that are within a one-half mile radius of the current proposed trajectory of the Well, including the reservoir section, as ellipses ("Notification Area"). $$xhibit 2 is a list of the names and addresses of all owners, landowners and operators of all properties within the Notification Area. Upon your request, CPAI will provide a complete copy of the Application. Please contact me at the address or phone number shown below if you have any questions or require any additional information. Sincerely, • �? -a- Dora I.Soria Staff Landman ConocoPhillips Alaska Inc 700 G Street Anchorage,AK 99510 Phone:(907)265 6297 Attachments: Exhibits 1 &2 Exhibit 1 ADL380075 AIA.312097 ADL384211 ADL380077 iDL38720 ADL387209 A0L384209 ADL38008. •� Colville River Unit Unit • ASRC-NPR2 AOL388903 1 ADL388905 A0t1388902 \ ADL391590 ASRC-NPR4 \ i ADL390337 ADL3bJ " Legend 112 61de Reservoir Buller 112 Me Trajectory Radius ----CD4-96A CPAI Operated Units Other Operated Units AK Leases \'-1111910111r- AVCG Tofkat C]CPAI ASF7r 2+.Sf-1 Leal REFERENCES: Ykl Dale:ConoeoPha'psAin5 Was DatabasoATDB ConoeoPhiIIips Surface Facicres North Slope 6K Survey 7/25112 Pubashrrd 3!20111 Massa Statee'de Cd&Gas Leaves 1/124015 Alaska,Inc. Wirer Yk0 Gala:DNR-Grourdeater Detson No Potabo Yleer Yki's era intho CoNto River Unci N CD4-96A Plat Analysis No Poi able%%ler Aqu•ers are in the Cob le River Uns Leases 1/16/2015 os a Exhibit 2 List of the names and addresses of all owners,landowners and operators of all properties within the Notification Area. Operator&Owner: ConocoPhillips Alaska, Inc. 700 G Street(Zip 99501) P.O.Box 100360 Anchorage,AK 99510 Attention: Patrick J.Wolfe,Manager North Slope Development Owners(Non-Operators): Anadarko E&P Onshore LLC 1099 18th Street, Suite 1800 Denver, CO 80202 Attention: Mike Nixson, Director Land-Alaska Landowners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Ave. Suite 800 Anchorage, AK 99501 Attention: Paul Decker,Acting Director Arctic Slope Regional Corporation 3900 C Street, Suite 801 Anchorage,Alaska 99503-5963 Attention: Teresa 1mm,Resource Development Manager Surface Owners: Mr.Isaac Nukapigak, President Kuukpik Corporation P.O. Box 89187 Nuigsut,AK 99789 State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7°i Ave. Suite 800 Anchorage,AK 99501 Attention: Paul Decker,Acting Director , Bcc: Robert Blakney Jill McLeod John Whitworth Misty Alexa CD4-96a Hydraulic Fracturing Sundry Application Section 2 - Plat 20 AAC 25.283 (a)(2) CD4- t• ADL38t175 CD2-36P:414CD, 7 CD2-53 CD2-27 C04-17 58 ADL372097 c 14-208PB1 co• 306 a D4-21g �_ CD2-17 CD2- 6 ‘CD4-3014 1711111k� CD .r CD4- / . A �� _`s.,\ �1 A CD4 IPB1 Z �� ��c a ; K, NANUQ 3 �_ r► CD4-31' imilm 1 -60A r�i,f 'e-� A. CD4-302 IWO 11111 1117% A* 'a-2a wit CD4-25 C"-- .ry/ � �� •� \\ — CD4-25L] r ,,,:v,'Al, N i CD4- ' � lite CD 1PB1 AD..:720' iiii ' ADL38O082 �, D4 ie„�\ CD•li. CD4 0 CD4 290 Clt• - 1 i‘ \CD4-2440. n D4-21,,• CD4-292 CD4- - '•_�'-+-��. • ir CD4209 ��CD4-93 NANUQ5 • •D4-2..".B1 D4-215 .04-2 'D4-23 A--214 ASRC-NPR2 \ .• CLP;, _ ,B1 Legend C'4-27P83 1/2 Mile Reservoir Buffer 1/2 Mile Trajectory Radius Wells in Radius A D 388905 —CD4-96A oa-96AD38 Ctt4-278902 PROP,PROD,OIL __ CD4-96APB1 Producer.Oil INJ:MWAG P+A CD4-'10APrr1 • FRAC PORT CD4-03 • PERF PUP/SLOT LINER SRC-NPR4 ADL38O • OPEN HOLE ADL39O337 D4-210A • WINDOW* IPERF * APERF • PERF PUP/SLOT LINER —1132015WeIISurvey ADL39067` OCPAI Operated Units 1 Q Other Operated Units AK Leases I IAVCG Tofkat I I CPAI 1 rr.:+rr�.: REFERENCES. - Well Data.ConocoPhillips Alaska Wells Database ATDB ConoeoPhi I I i ps Surface Facilities'North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide 0/&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data DNR-Groundwater Division >No Potable Water Wells are in the Colville River Unit. N CD4-96A Plat Analysis >No Potable Water Aquifers are in the Colville River Unit 1/12/2015 1 o.5 0 biles PacRaOusMap2015.mIE 055 118.2015 Wells within .5 mile radius WELL_NAME API PERMIT NUM BUS AREA I BUB ID FLUID TYPE STATUS WELL ID WELL TYPE CD3-106 501032061100 210-001 FIORDNECH WNS OIL ACTIVE CD3-106 PROD CD3-106L1 501032061160 210-002 FIORDNECH WNS OIL ACTIVE CD3-106 PROD CD3-307 501032052900 206-046 FIORDKUP WNS OIL PA CD3-107 PROD CD3-107 501032052901 206-189 FIORDNECH WNS OIL ACTIVE CD3-107 PROD CD3-107L1 501032052960 208-051 FIORDNECH WNS OIL ACTIVE CD3-107 PROD CD3-108 501032050700 205-033 FIORDNECH WNS MWAG ACTIVE CD3-108 INJ CD3-109 501032051000 205-059 FIORDNECH WNS OIL ACTIVE CD3-109 PROD CD3-110 501032050900 205-041 FIORDNECH WNS MWAG ACTIVE CD3-110 INJ CD3-111 501032052600 206-030 FIORDNECH WNS OIL ACTIVE CD3-111 PROD CD3-111L1 501032052660 206-042 FIORDNECH WNS OIL ACTIVE CD3-111 PROD CD3-112 501032052700 206-032 FIORDNECH WNS MWAG ACTIVE CD3-112 INJ CD3-113 501032054100 207-004 FIORDNECH WNS OIL ACTIVE CD3-113 PROD CD3-114 501032054400 207-033 FIORDNECH WNS MWAG ACTIVE CD3-114 INJ CD3-115 501032059300 209-006 FIORDNECH WNS OIL ACTIVE CD3-115 PROD CD3-117 501032059600 209-026 FIORDNECH WNS OIL ACTIVE CD3-117 PROD CD3-118 501032057000 208-025 FIORDNECH WNS MWAG ACTIVE CD3-118 INJ CD3-119 501032065300 212-007 FIORDNECH WNS OIL ACTIVE CD3-119 PROD CD3-119PB1 501032065370 212-007 FIORDNECH WNS PA CD3-119 EXPEND CD3-121 501032061500 210-022 FIORDNECH WNS MWAG ACTIVE CD3-121 INJ CD3-122 501032060900 209-153 FIORDNECH WNS OIL ACTIVE CD3-122 PROD CD3-123 501032061700 210-031-0 FIORDNECH WNS MWAG ACTIVE CD3-123 INJ CD3-124 501032061200 210-008-0 FIORDNECH WNS MWAG ACTIVE CD3-124 INJ CD3-125 501032063200 210-189-0 FIORDNECH WNS OIL ACTIVE CD3-125 PROD CD3-125PB1 501032063270 210-189-0 FIORDNECH WNS PA CD3-125 EXPEND CD3-127 501032063400 211-005-0 FIORDNECH WNS OIL ACTIVE CD3-127 PROD CD3-127PB1 501032063470 211-005-0 FIORDNECH WNS PA CD3-127 EXPEND CD3-128 501032063800 211-037-0 FIORDNECH WNS MWAG ACTIVE CD3-128 INJ CD3-130 501032067700 212-160-0 FIORDNECH WNS PROP CD3-130 SVC CD3-130PB1 501032067770 212-160-0 FIORDNECH WNS PA CD3-130 EXPEND CD3-198 501032063700 211-024-0 FIORDNECH WNS MWAG ACTIVE CD3-198 INJ CD3-199 501032063500 211-010-0 FIORDNECH WNS OIL ACTIVE CD3-199 PROD CD3-301 501032054300 206-020 FIORDKUP WNS OIL PA CD3-301 PROD CD3-301A 501032054301 210-017-0 FIORDKUP WNS OIL ACTIVE CD3-301 PROD CD3-301APB1 501032054371 210-017-0 FIORDKUP WNS PA CD3-301 EXPEND CD3-301PB1 501032054370 206-020 FIORDKUP WNS PA CD3-301 EXPEND CD3-302 501032052200 206-010 FIORDKUP WNS MWAG PA CD3-302 INJ CD3-302A 501032052201 210-035 FIORDKUP WNS MWAG ACTIVE CD3-302 INJ CD3-302PB1 501032052270 206-010 FIORDKUP WNS PA CD3-302 EXPEND CD3-302PB2 501032052271 206-010 FIORDKUP WNS PA CD3-302 EXPEND CD3-302PB3 501032052272 206-010 FIORDKUP WNS PA CD3-302 EXPEND CD3-303 501032056800 208-013 FIORDKUP WNS MWAG ACTIVE CD3-303 INJ CD3-304 501032059800 209-028 FIORDKUP WNS OIL ACTIVE CD3-304 PROD CD3-305 501032058900 208-193 FIORDKUP WNS MWAG ACTIVE CD3-305 INJ CD3-305PB1 501032058970 208-193 FIORDKUP WNS PA CD3-305 EXPEND CD3-316 501032055900 207-177 FIORDKUP WNS PA CD3-316 INJ CD3-316A 501032055901 208-011 FIORDKUP WNS PA CD3-316 INJ CD3-316APB1 501032055970 208-011 FIORDKUP WNS PA CD3-316 EXPEND CD3-316BPB1 501032055971 214-018 FIORDKUP WNS PA CD3-316 EXPEND CD3-316BXX 501032055903 214-018 FIORDKUP WNS OIL ACTIVE CD3-316 PROD • , WELL_NAME API PERMIT_NUM BUS_AREA_I BUB_ID FLUID_TYPE STATUS WELL_ID WELL_TYPE CD3-320 501032066700 213-006-0 FIORDKUP WNS SUSP CD3-320 PROD CD4-03 501032064100 211-113-0 ALP WNS MWAG ACTIVE CD4-03 INJ CD4-05 501032055800 207-155 ALP WNS OIL ACTIVE CD4-05 PROD CD4-07 501032055300 207-118 ALP WNS OIL ACTIVE CD4-07 PROD CD4-12 501032041401 210-091 ALP WNS MWAG ACTIVE CD4-12 INJ CD4-12PB1 501032041470 210-091 ALP WNS PA CD4-12 EXPEND NANUQ 5 501032041400 202-042 ALP WNS PA CD4-12 EXPLOR CD4-16 501032053500 206-131 ALP WNS OIL ACTIVE CD4-16 PROD CD4-17 501032053400 206-118 ALP WNS MWAG ACTIVE CD4-17 INJ CD4-208A 501032051701 211-060-0 ALP WNS OIL ACTIVE CD4-208 PROD CD4-208APB1 501032051771 211-060-0 ALP WNS PA CD4-208 EXPEND CD4-208 501032051700 205-162-0 NANUQ WNS MWAG PA CD4-208 INJ CD4-208PB1 501032051770 205-162-0 NANUQ WNS PA CD4-208 EXPEND CD4-209 501032053200 206-065 NANUQ WNS MWAG ACTIVE CD4-209 INJ CD4-210A 501032053301 211-072-0 ALP WNS OIL ACTIVE CD4-210 PROD CD4-210APB1 501032053370 211-072-0 ALP WNS PA CD4-210 EXPEND CD4-210 501032053300 206-077 NANUQ WNS OIL PA CD4-210 PROD CD4-211 501032053800 206-153 NANUQ WNS OIL ACTIVE CD4-211 PROD CD4-213A 501032054001 212-003-0 ALP WNS PA CD4-213 INJ CD4-213B 501032054002 212-005-0 ALP WNS MWAG ACTIVE CD4-213 INJ CD4-213BPB1 501032054070 212-005-0 ALP WNS PA CD4-213 EXPEND CD4-213BPB2 501032054071 212-005-0 ALP WNS CD4-213 CD4-213 501032054000 206-173 NANUQ WNS PA CD4-213 INJ CD4-214 501032053700 206-145 NANUQ WNS MWAG ACTIVE CD4-214 INJ CD4-215 501032053900 206-157 NANUQ WNS OIL ACTIVE CD4-215 PROD CD4-23 501032062100 210-067-0 ALP WNS OIL ACTIVE CD4-23 PROD CD4-23PB1 501032062170 210-067-0 ALP WNS PA CD4-23 EXPEND CD4-23PB2 501032062171 210-067-0 ALP WNS PA CD4-23 EXPEND CD4-24 501032060200 209-097-0 ALP WNS MWAG ACTIVE CD4-24 INJ CD4-24PB1 501032060270 209-097-0 ALP WNS PA CD4-24 EXPEND CD4-24PB2 501032060271 209-097-0 ALP WNS PA CD4-24 EXPEND CD4-25 501032060800 209-150 ALP WNS OIL ACTIVE CD4-25 PROD CD4-25L1 501032060860 210-121-0 ALP WNS OIL ACTIVE CD4-25 PROD CD4-25PB1 501032060870 209-150 ALP WNS PA CD4-25 EXPEND CD4-26 501032060000 209-049 ALP WNS MWAG ACTIVE CD4-26 INJ CD4-27 501032064400 211-146 ALP WNS MWAG ACTIVE CD4-27 INJ CD4-27PB1 501032064470 211-146 ALP WNS PA CD4-27 EXPEND CD4-27PB2 501032064471 211-146 ALP WNS PA CD4-27 EXPEND CD4-27PB3 501032064472 211-146 ALP WNS PA CD4-27 EXPEND CD4-289 501032069700 214-188-0 NANUQ WNS OIL PROP CD4-289 SVC CD4-290 501032067400 213-130-0 NANUQ WNS OIL ACTIVE CD4-290 PROD CD4-291 501032067200 213-110-0 NANUQ WNS MWAG ACTIVE CD4-291 INJ CD4-291PB1 501032067270 213-110-0 NANUQ WNS PA CD4-291 EXPEND CD4-292 501032066900 213-035-0 NANUQ WNS OIL ACTIVE CD4-292 PROD CD4-298 501032062300 210-130-0 NANUQ WNS OIL ACTIVE CD4-298 PROD CD4-298PB1 501032062370 210-130-0 NANUQ WNS PA CD4-298 EXPEND CD4-301 501032055700 207-150 NANKUP WNS PA CD4-301 PROD CD4-301A 501032055701 207-174 NANKUP WNS PA CD4-301 PROD CD4-301B 501032055702 207-180 NANKUP WNS OIL ACTIVE CD4-301 PROD CD4-302 501032054500 207-056 NANKUP WNS MWAG ACTIVE CD4-302 INJ CD4-303XX 501032060600 209-126 NANKUP WNS OIL ND CD4-303 PROD 1 WELL_NAME API PERMIT_NUM BUS_AREA_I BUB_ID FLUID_TYPE STATUS WELL_ID WELL_TYPE CD4-304 501032055500 207-132 NANKUP WNS OIL ACTIVE CD4-304 PROD CD4-304PB1 501032055570 207-132 NANKUP WNS PA CD4-304 EXPEND CD4-306 501032055000 207-094 NANKUP WNS MWAG ACTIVE CD4-306 INJ CD4-318 501032051900 205-196 NANKUP WNS OIL PA CD4-318 PROD CD4-318A 501032051901 206-113 NANKUP WNS OIL ACTIVE CD4-318 PROD CD4-318PB1 501032051970 205-196 NANKUP WNS PA CD4-318 EXPEND CD4-319 501032051600 205-148 NANKUP WNS MWAG ACTIVE CD4-319 INJ CD4-320 501032053100 206-055 NANKUP WNS OIL ACTIVE CD4-320 PROD CD4-320PB1 501032053170 206-055 NANKUP WNS PA CD4-320 EXPEND CD4-321 501032053600 206-142 NANKUP WNS MWAG ACTIVE CD4-321 INJ CD4-322 501032055100 207-101 NANKUP WNS MWAG ACTIVE CD4-322 INJ CD4-93 501032069000 214-081-0 ALP WNS OIL PROP CD4-93 PROD CD4-96 501032067300 213-129-0 ALP WNS OIL PA CD4-96 PROD CD4-96A 501032067301 214-056-0 ALP WNS OIL ACTIVE CD4-96 PROD CD4-96APB1 501032067370 214-056-0 ALP WNS PA CD4-96 EXPEND NANUK 1 501032023800 196-057 NAK NAK PA NANUK 1 EXPLOR NANUK 2 501032033200 200-030 NAK NAK PA NANUK 2 EXPLOR NANUQ 3 501032036500 201-026 NANUQ WNS PA NANUQ 3 EXPLOR Well data sourced from ConocoPhillips alaska Wells Database ATDB No Potable water wells are in the Colville River Unit - Source DNR groundwater Division CD4-96a Hydraulic Fracturing Sundry Application SECTION 3 — FRESHWATER AQUIFERS 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within a one-half mile radius of the current or proposed wellbore trajectory. See Conclusion number 3 of the Area Injection Order AIO 018.000- Colville River Field, Alpine Oil Pool: Enhanced Recovery Project, which states "No underground sources of drinking water ("USDWs") exist beneath the permafrost in the Colville River Unit area." • CD4-96a Hydraulic Fracturing 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 one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. CD4-96a Hydraulic Fracturing 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. CD4-96a Hydraulic Fracturing Sundry Application Section 6 Casing & Cement Assessments: CD4-96A: 13 & 3/8" casing cement pump report on 10/27/2013 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.0 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,200 psi and the floats were checked and they held. 9 & 5/8" casing cement pump report on 11/16/2013 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.0 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1000 psi and the floats were checked and they held. 7" casing cement pump report on 6/24/2014 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 11.0 ppg mud. Reciprocated pipe and full returns were seen throughout the job. The plug bumped @ 1,220 psi and the floats were checked and they held. Summary All casing is cemented in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. CD4-96a Hydraulic Fracturing Sundry Application SECTION 7 — PRESSURE TEST INFORMATION AND PLANS TO PRESSURE-TEST CASINGS AND TUBINGS INSTALLED IN THE WELL 20 AAC 25.283(a)(7) On 10/31/2013 the 13 & 3/8" casing was pressure tested to 3500 psi for 30 mins. On 11/18/2013 the 9 & 5/8" casing was pressure tested to 3500 psi for 30 mins. On 8/23/2014, the 7" casing was pressure tested to 2500 psi for 30 mins. On 8/23/2014 the 3.5" tubing was pressure tested to 2500 psi for 30 mins. The 3.5" tubing will be pressure tested to 3,500 psi prior to frac'ing. The 7" casing will be pressure tested to 3,500 psi prior to frac'ing. CD4-96a Hydraulic Fracturing Sundry Application SECTION 8 — PRESSURE RATINGS AND SCHEMATICS FOR THE WELLBORE, WELLHEAD, BOPE AND TREATING HEAD 20 AAC 25.283(a)(8) Size Weight Grade API Burst API Collaspe 13 & 3/8" 68 L-80 5,020 psi 2,260 psi 9 & 5/8" 40 L-80 5,750 psi 3,090 psi 7" 26 L-80 7,240 psi 5,410 psi 3.5" 9.3 L-80 10,160 psi 10,540 psi CD4-96a Hydraulic Fracturing Sundry Application Stimulation Surface Rig-Up Bleed Ta Tale Tanknk 114.7011 1[4:01 1 100 w s�A .:11 RI mg 1;1 • Minimum pressure rating on all surface 111 1� treating lines 10,000 psi • Main treating line PRV is set to 95%of max treating pressure _t • IA parallel PRV set to 3500 psi 100'1 • Frac pump trip pressure setting are staggered and set below main treating line PRV C • Tree saver used on all fracs rated for 15,000 _bp. '�a psi. t1 1.1.1 a ris Dal kOrui(kind 0 Pap-Off Tarn Pop-Off Tank Dal Pump Truck 0 aZ> 5141 r J f1 J N C d � I i Frac Pump }— —D8C1--N- Frac Pump a� Frac Pump NI 3-- I --fJ-- Frac Pump 2 Frac Pump FraL.Pur-ip Stimulation Tree Saver CD4-96a Hydraulic Fracturing Sundry Application OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) 11- FRAC IRON `CONNECTION • a i / De. • TT VKVE�� r V tO+ O� ++ NUAL OPERATED MASTERMAVALVE +i •16101 Stinger 1 Stinger Iii111 MANDRELis! L ,�I� I J , 1 (2 ti � VENT `I®I f--VALVE I_ e`N y OPEN I tl Iii' WI °ILI. ;i ; _ ®� jf C ,'+ AND / �%■ a VENT VANE WELLHEAD III —1III VALVES ��/ , .. OPEN y WELLHEAD �. ;'1. :`. VALVES i \. >> CLOSED _-' 4--� %\, \ :1 I�. K e 1 ,._:_i ti \ �� QUAD PACKOFF .�/ - y ��\�\+N ASSEMBLY IN ', r PLACE IN TUBING In 1:.,• I; 'VI \ �\ TUBING /- i r; si • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25"down 4 1/2 tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm . U I- WNS PROD CD4-96A ConocoPhillips Well Attributes Max Angle&MD TD Alaska,Inc. Weliber°APIIUWI Field Name Wellbore Status ncl 1') MO(IK8) Act Otto(ftKB) cr,r,,,fi,ll, 501032067301 ALPINE PROD 92.21 15,251.67 19,293.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date HORIZONTAL-CD4-96A 1077/20141216:19 PM SSSV:TRDP Last WO: 36.60 12/16/2013 Vemcal sUxmatw(actual) Annotation Depth(NIB) End Date Annotation Last Mod By End Date HANGER31.4- 9l11 -------•---- -1---•-•-- - Last Ta ELINE 15,216.0 7/8/2014 Rev Reason:SIDETRACK postojl 9252014 HANGER - 9' _..._._._....__.�._._._..._ 14,10 ` of ._...._._Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)...i Wt/Len(I...Grade Top Thread CONDUCTOR 20 19.124 36.6 114.0 114.0 94.0011-40 Welded .il - Casing DescriptionOD(In) 'ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Mien(L..Grade Top Thread SURFACE 133/8 12.415 36.6 2,939.0 2,369.0 68.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen(I...Grade 'Top Thread `7`^^,--.INTERMEDIATE 95/8 8.835 1565.8 13,260.0 6,924.3 40.00 L-80 BTC-M Casing Description OD(In) ID(In) Top(ftKB) 'SetWti Depth(ftKB) Set Depth(TVD)... Len(L..Grade Top Thread 7"PRODUCTION TIE- 7 6.276 33.8 12,776.4 6,715.4 26.00 L80 BTCM XO REDUCING;113.0-‘ BACK CONDUCTOR;36.6-114.0- I ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 7" 7 6.276 12,765.4 15,220.0 7,491.6 26.00 L80 Ten Blue _ Liner Details Nominal ID 11 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) ,� 12,765.4 6,710.3 1,2.42 PACKER BAKER LINER TOP PACKER. 6.200 OWE VLV.2,111° -MI I 12,7892 6,721.2 62.66 NIPPLE RS NIPPLE 6.200- EI, 12,792.0 6,722.5 62.69 HANGER FLEX-LOCK LINER HANGER 6.220 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen 11••.Grade Top Thread LINER41/2" 1 4121 3.9581 14,952.31 19,293.01 7,556.11 12.601 C-110 1H521 Liner Details SURFACE;36.0-2,939.0 - Nominal ID . Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;5,303.9 = 14,952.3 7,449.4 77.11 PACKER Baker 5"x T'HRD ZXP Liner Top Packer 4.340 MI 14,972.3 7,453.8 77.52 NIPPLE BAKER RS NIPPLE 4.250 li • MI 14,9752 7,454.4 77.57 HANGER BAKER FLEX-LOCK LINER HANGER 4.370 GAS LIFT;10,326.0 :l 14,984.3 7,456.3 77.75 SBE BAKER SEAL BORE 4.000 15,897.5 7,514.2 88.67 SLEEVE CAMCO SLIDING SLEEVE 2.813 • 16,703.8 7,521.9 89.42 SWELL TAM SWELL PACKER,HYBRID ACTIVATED 3.958 li T'PRODUCTION TIE-BACK; - PACKER 33.0-12,776.4 - - 17,108.5 7,525.5• 88.62 SWELL TAM SWELL PACKER,HYBRID ACTIVATED 3.958 ' ,. PACKER C 7 17,801.7 7,540.6 90.08 FRAC SLEEVE BAKER FRAC SLEEVE 2.073 I ts ■I 18,582.7 7,551.2 89.38 FRAC SLEEVE BAKER FRAC SLEEVE 2.010 l l 19,237.0 7,555.1 89.04 FRAC SLEEVE BAKER PRESSURE SLEEVE 3.860 INTERMEDIATE 1,565.8- 13'260'0 I 19,243.7 7,555.2 89.04 VALVE WELLBORE ISOLATION VALVE 0.000 II GAS UFT;13,838.1 ;' Tubing Strings inTubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO I 31/2 2.9921 31.41 14,999.21 7,459.51 9.301 L-80 I EUE _l. Completion Details IiiTop(ftKB) Top(ND)(ftKB) Top Incl)") Item Des Com Nominal ID(in) GUAGE;14.8728 �' 31.4 31.4 0.00 HANGER HANGER,ELASTOMER 3.900 • 113.0 113.0 0.16 XO XO,4.5 IBTM BOX x 3.5 EUE PIN 2.992 NIPPLE;14.919.8 REDUCING L 2,111.0 1,9422 46.96 SAFETY VLV CAMCO TRMAXX-5EW/2.813'X PROFILE 2.812 `_a. 14,872.8 7,430.6 75.68 GUAGE SLB SOLID GUAGE MANDREL 2.913 7" SEAL ASSY;14,952.7 `-7.4.' 14,919.8 7,441.9 76.46 NIPPLE X NIPPLE W/2.813"PROFILE 2.813 I Z.i 14,952.7 7,449.5 77.12 SEAL ASSY BAKER GBH-22 SEAL ASSY 2.980 III Mandrel Inserts I St ani av N Top(ND) Valve Latch Port Sloe TRO Run Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (In) Ipso Run Date Com atm 1 5,303.9 3,430.0 CAMCO KBMG 5.39 GAS LIFT GLV BK 0.188 2,013.0 8/30/2014 LINER 7";12,765.4-15220.0 2 10,326.0 5,663.1 CAMCO KBMG 5.39 i GAS LIFT GLV BK 0.188 1,976.0 8/302014 3 13,838.1 7,138.4 CAMCO KBMG 5.39 GAS LIFT OV BK 0.250 0.0 8/302014 Notes:General&Safety ' I I End Date Annotation 9/25/2014 NOTE:7',29#,TN110,H563 From 14,784.33'10 15,220'MD 9/25/2014 NOTE:7",2&f,L80,Tenaris Blue from 12765.40'to 14,784.33'MD 1:ri el 1C r All LINER 41/7';14,952.319293.0 Ili CD4-96a Hydraulic Fracturing Sundry Application SECTION 9 — DATA FOR FRACTURING ZONE AND CONFINING ZONES 20 AAC 25.283(a)(9) CPAI has formed the opinion, based on seismic, well, and other subsurface information currently available that: The Alpine C interval is approximately 20' TVD thick at the heel of the lateral and gradually thinning to about 4' TVD by the toe. Alpine C sandstone is very fine grained, quartz rich, with a sharp based, blocky log profile. Top Alpine C is 15,154' MD/7431' TVDSS. The estimated fracture gradient for the Alpine C is 12.5 ppg. The overlying confining zone consists of over 600' TVD of Miluveach, Kalubik and HRZ mudstones. The estimated fracture gradient for the Miluveach is 15 ppg. The estimated fracture gradient for the Miluveach is 15 ppg and for the Kalubik and the HRZ is 16 ppg. Top HRZ is 13,098' MD/6802' TVDSS. CD4-96a Hydraulic Fracturing Sundry Application SECTION 10 — LOCATION, ORIENTATION AND A REPORT ON MECHANICAL CONDITION OF EACH WELL THAT MAY TRANSECT CONFINING ZONE 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within the one-half mile radius of the proposed wellbore trajectory. Casing & Cement assessments for all wells that transect the confining zone: CD4 - 24: 7" casing cement pump report on 12/15/2009 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.2 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,300 psi and the floats were checked and they held. CD4 - 318: 7" casing cement pump report on 8/30/2006 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 10.2 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,100 psi and the floats were checked and they held. CD4 - 27: 7" casing cement pump report on 1/05/2012 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 15.8ppg Class G cement, displaced with 11.3 ppg mud. Full returns were seen throughout the job. The plug bumped @ 1,300 psi and the floats were checked and they held. CD4-96a Hydraulic Fracturing Sundry Application SECTION 11 — LOCATION OF, ORIENTATION OF AND GEOLOGICAL DATA FOR FAULTS AND FRACTURES THAT MAY TRANSECT THE CONFINING ZONES 20 AAC 25.283(a)(11) CPAI has formed the opinion based on seismic, well, and other subsurface information currently available that there are three mapped faults that transect the Alpine interval and may enter the confining zone within one half mile radius of the wellbore trajectory for CD4- 96A. These mapped faults do not intersect the CD4-96A wellbore. In addition to these faults, there may be three subseismic faults inferred while drilling at approximately 15,582' MD, 17,065' MD and 18,156' MD. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. CD4-96a Hydraulic Fracturing Sundry Application d• •• • • • ••• i • j✓" �,� ►oiviue ■ River Unit Unit \1414414444:\ Legend n w•CD4-96A Trajectory ▪ Faults within Radius mn Reservoir Section =CPA/Operated Units Q Other Operated Units !1/2 Mile Reservoir Radius 1 1 1/2 Mile Trajectory Radius REFERENCES: Well Data:ConocoPhillips Alaska Wells Database ATDB ConocoPhillips Surface Facilities:North Slope 6K Survey 7/25/12 Published 3/20/13 Alaska Statewide Oil&Gas Leases 1/12/2015 Alaska,Inc. Water Well Data:DNR-Groundwater Division >No Potable Water Wells are in the Colville River Unit. N CD4-96A Plat Analysis >No Potable Water Aquifers are in the Colville River Unit Faults 1/22/2015 0.5 0 I- - _ Mies C54-9Mle•ua mxd CSR 1/1(2015 * Map view depiction of seismically mapped faults and sub-seismic inferred faults (orientation unknown) from drilling data faults located within 1/2 mile radius of the reservoir well section (highlighted in red) in which the hydraulic fracture is planned CD4-96a Hydraulic Fracturing Sundry Application SECTION 12 — PROPOSED HYDRAULIC FRACTURING PROGRAM 20 AAC 25.283(a)(12) CD4 -96a was completed in 2014 as horizontal producer in the Alpine C formation. The well was completed with 3.5" tubing and a 4.5" liner with ball actuated sliding sleeves. After the 1St stage we will shift a sleeve to close off that section of the lateral. We will then pump the 2"d stage and drop a ball (progressively getting larger) after each remaining stage, these balls will provide isolation from the previous stage and allow us to move from the toe of the well towards the heel. Proposed Procedure: Schlumberger Pumping Services: (Alpine C Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 16 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 2800 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 202 bbl breakdown stage (27# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 6000 psi. • 140 bbls YF127ST Pad • 25 bbls YF127ST w/ 1 ppa 16/20 Carbolite • 25 bbls YF127ST w/ 3 ppa 16/20 Carbolite • 25 bbls YF127ST w/ 5 ppa 16/20 Carbolite • 25 bbls YF127ST w/ 7 ppa 16/20 Carbolite • 25 bbls YF127ST w/ 8 ppa 16/20 Carbolite • Flush with 149 bbls of linear fluid (WF127) and freeze protect 12. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 13. Shift the sleeve in the heel of the well using an E-line tractor. CD4-96a Hydraulic Fracturing Sundry Application 14. Pump the 577 bbl breakdown stage (30# linear gel, WF130) 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. 15. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 16. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 6000 psi. • 290 bbls YF130ST Pad • 90 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF130ST w/2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF130ST w/4 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 6 ppa 16/20 Carbolite • Drop ball 1 • 290 bbls YF130ST Pad • 90 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF130ST w/4 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF130ST w/6 ppa 16/20 Carbolite • 145 bbls YF130ST w/ 7 ppa 16/20 Carbolite • Drop ball 2 • 290 bbls YF130ST Pad • 90 bbls YF130ST w/ 1 ppa 16/20 Carbolite • 100 bbls YF130ST w/ 2 ppa 16/20 Carbolite • 110 bbls YF130ST w/ 3 ppa 16/20 Carbolite • 120 bbls YF130ST w/4 ppa 16/20 Carbolite • 130 bbls YF130ST w/ 5 ppa 16/20 Carbolite • 140 bbls YF130ST w/ 6 ppa 16/20 Carbolite • 145 bbls YF130ST w/ 7 ppa 16/20 Carbolite • 145 bbls YF130ST w/ 8 ppa 16/20 Carbolite • Flush with 140 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx: 400,000 lbs 16/20 Carbolite 17. 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LL LL 3 LL ~ LL LL LL LL LL LL LL LL LL LL LL 0 0 LL 0 LL LL w LL LL LL 0 LL LL LL LL LL 3 m 0 rrr >-rrsrsrr>aa>YarY,-).- -,-, C a a g u E E. c n •= N C ._::7:' d' g W W K m onwcg .9g -0231 H 1- 1- 1- 1- fFa tfHFF ,- ,- (3pFFFtFf fr zzz v • oH N a ggg g LLggggLLgLLLLJoQ Eo G 0 D O m m x w WN anaaat _ _rnrn_c _ _rn - ggg W = 7 a 0 LIJ 0 J 0 o7m 1 a W P Q 0 • arNMQNJerNMOHDnei rNMQnDno W 0nwm 0a Wli292 NfJ N oFo _O Q — tMn V m m NQN Y F Na , c (_J• • C w a Q# E F # N N N N N N N M N N N C) C) N C) C) . . . . . . . . . . . . . N ,_ N 0m 1 a F- - y Z i• Eo. r P1 ya ow o a 3 i U f°w# - N N V Y) m w # (m N N W - N N V N d C• 0 W N R') N N N N N N tc•) C) C9 `P� X J O W Z i 6 N E N O O O O M g m <-n 110 N N N N < c g Q F 3 C y O E O J IL �i m • d O O � � x J a a Client: ConocoPhillips Alaska Inc. Schlumberger Well: CD4-96A Basin/Field: Colville-Prudhoe Basin Alpine State: Alaska County/Parish: North Slope Borough Case: Disclosure Type: Pre-Job Well Completed: Date Prepared: 1/15/2015 4:14 PM Report ID: RPT-33925 Fluid Name&Volume Additive Additive Description Concentration Vo'_,ii:., B882 Guar Polymer Slurry 6.3 Gal/1000 Gal 1,225.0 Gal D047 AntiFoam Agent 0.2 Gal/1000 Gal 37.0 Gal F103 Surfactant 1 Gal/1000 Gal 194.0 Gal J475 Breaker 8 Lb/1000 Gal 1,546.0 Lb YF127ST:WF127 192,988 Gal 1532 Crosslinker 4.3 Gal/1000 Gal 839.0 Gal L065 Scale Inhibitor 2 Gal/1000 Gal 389.0 Gal M002 Additive 0.5 Lb/1000 Gal 101.0 Lb M275 Bactericide 0.3 Lb/1000 Gal 61.0 Lb S522-1620 Propping Agent varied concentrations 396,600.0 Lb The total volume listed in the tables above represents the summation of water and additives. Water is supplied by client. CAS Number Chemical Name Mass Fraction Water(Including Mix Water Supplied by Client)* -79% _ 66402-68-4 Ceramic materials and wares,chemicals -20% 64742-47-8 Distillates(petroleum),hydrotreated light <1 % 9000-30-0 Guar gum <1% 56-81-5 1,2,3-Propanetriol <0.1% 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% 111-76-2 2-butoxyethanol <0.1% 67-63-0 Propan-2-ol <0.1% 25038-72-6 Vinylidene chloride/methylacrylate copolymer <0.1% 34398-01-1(7E0) Linear C11 alcohol ethoxylate(leo, <0.01% 34398-01-1(3E0) Linear C11 alcohol ethoxylate(3eo; <0.01% 68131-39-5 C12-15 alcohol ethyoxylated <0.01 % 7647-14-5 Sodium chloride <0.01 % 68953-58-2 Dihydrogenated tallow dimethyl ammonium bentonite <0.01% 1310-73-2 Sodium hydroxide(impurity) <0.01% 7631-86-9 Silicon Dioxide <0.01% 10043-52-4 CALCIUM CHLORIDE <0.01% 108-32-7 4-methyl-1,3-dioxolan-2-one <0.01% 91053-39-3 Diatomaceous earth,calcined <0.01% 14807-96-6 Magnesium silicate hydrate(talc) <0.001% 111-46-6 2,2"-oxydiethanol(impurity) <0.001% 10377-60-3 Magnesium nitrate <0.001% 68153-30-0 Amine treated smectite clay <0.001% 9002-84-0 poly(tetrafluoroethylene) <0.001% 26172-55-4 5-chloro-2-methyl-2h-isothiazolol-3-one <0.001% 7786-30-3 Magnesium chloride <0.001% 7447-40-7 Potassium chloride(impurity) <0.001% 2682-20-4 2-methyl-2h-isothiazol-3-one <0.0001% 14808-60-7 Crystalline silica(impurity) <0.0001% 14464-46-1 Cristobalite <0.0001% Total •Mir 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. it Schlumberger 2015.Used by ConocoPhillips Alaska Inc.by permission. 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N Cll .2 O 2 Q � L Cll = .w U N CJ) E °' co p(1) U) ' .0 Ta 0 •o_ O Q — C U 11 bl ca _ H •J — CD 4- +, -0 T3)OCa O � o � s � - per•— ca —C3 a ' = > O 46 m " 4- ^' . . c co /� p a/ O2 W `+� '� Vim/ 'C+ O N CD L A�—"T L L C.) a) Q ) O) L - p }, O vvui = a. p C6 �.•- . • M � •3 -a a, Z O O C4-� � = LL LI.. A — L D 3. ca a L- ci) -0 0.Q co L- 0 CU .+_+ 7000C E ° C .3 a) " — c Eaw < •— E 'TT) O }' c Cll Cll O U) U) Q O O u) E s_ E E 0 • CD4-96a Hydraulic Fracturing Sundry Application SECTION 13 — POST-FRACTURE WELLBORE CLEANUP AND FLUID RECOVERY PLAN 20 AAC 25.283(a)(13) Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to CD1-01 disposal well until they are clean enough for production.) 21 4056 25329 cblumberger Transmittal#: 27JAN15-SPO1 Drilling & Measurements DATA LOGGED MWD/LWD Log Product Delivery t iysi2o15 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC:Makana Bender Well No: CD4-96A Date Dispatched: 27-Jan-15 Job#: 14AKA0039 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD Scope Resistivity 2"TVD x x Scope Resistivity T MD JAN 2 7 2015 x x Scope Resistivity T TVD x x yI LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey:PDF x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso©conocophillips.com AlaskaPTSPrintCenter c(Dsib.com Catherine Roso Atm:Stephanie Pacillo 907-265-6189 ATO 1707 Received By: 214056 25329 RECEIvcL FINAL JAN 2 7 2015 AOGCC NADConversion Western North Slope CD4 Nanuq Pad CD4-96A Definitive Survey Report N A D 2 7] 08 September, 2014 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-96 Well Position +N/-S 0.00 usft Northing: 5,957,544.09 usft Latitude: 70°17'33.155 N +E/-W 0.00 usft Easting: 378,252.95 usft Longitude: 150°59'8.492 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 18.90 usft Wellbore CD4-96A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/22/2014 18.76 80.77 57,557 Design CD4-96A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 15,132.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 206.81 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.32 1,046.10 CD4-96 Gyro(CD4-96) GYD-GC-SS Gyrodata gyro single shots 11/13/2013 12:01 1,139.67 2,869.84 CD4-96 MWD I(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 2,965.61 3,020.73 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND Inclinometer+known azi trend 2/11/2014 12:00: 3,114.99 12,938.76 CD4-96 MWD II(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 12,950.00 13,400.00 CD4-96APB1 Svy1 SLB_NSG+MSHOT( GYD-GC-MS Gyrodata gyrocompassing m/s 6/16/2014 9:15: 13,465.21 15,132.00 CD4-96APB1 Svy2 SLB-MWD-GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2014 10:01 15,145.00 15,251.68 CD4-96A Svy1 MWD INC ONLY FILLER INC+TREND Inclinometer+known azi trend 8/8/2014 5:42:0 15,343.82 19,231.81 CD4-96A Svy2 MWD+GMAG(CD4-96A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/5/2014 3:57:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.80 0.00 0.00 36.80 -18.90 0.00 0.00 5,957,544.09 378,252.95 0.00 0.00 UNDEFINED 75.32 0.12 214.58 75.32 19.62 -0.03 -0.02 5,957,544.06 378,252.93 0.31 0.04 GYD-GC-SS(1) 104.55 0.19 179.56 104.55 48.85 -0.11 -0.04 5,957,543.98 378,252.91 0.39 0.11 GYD-GC-SS(1) 114.15 0.14 183.36 114.15 58.45 -0.13 -0.04 5,957,543.95 378,252.91 0.51 0.14 GYD-GC-SS(1) 20"x 42" 144.37 0.04 280.72 144.37 88.67 -0.17 -0.05 5,957,543.92 378,252.89 0.51 0.18 GYD-GC-SS(1) 241.06 0.41 229.08 241.06 185.36 -0.39 -0.35' 5,957,543.70 378,252.60 0.40 0.51 GYD-GC-SS(1) 333.50 0.51 232.63 333.50 277.80 -0.86 -0.92 5,957,543.25 378,252.01 0.11 1.18 GYD-GC-SS(1) 9/8/2014 1:02:OOPM Page 2 COMPASS 5000.1 Build 65 Sc hl urnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 423.96 0.76 273.71 423.95 368.25 -1.06 -1.84 5,957,543.06 378,251.09 0.56 1.78 GYD-GC-SS(1) 520.36 1.79 306.49 520.33 464.63 -0.13 -3.69 5,957,544.02 378,249.26 1.27 1.78 GYD-GC-SS(1) 612.19 2.95 333.58 612.08 556.38 2.84 -5.90 5,957,547.03 378,247.10 1.72 0.12 GYD-GC-SS(1) 703.41 2.13 339.50 703.21 647.51 6.53 -7.53 5,957,550.74 378,245.52 0.94 -2.43 GYD-GC-SS(1) 797.65 2.47 331.34 797.37 741.67 9.96 -9.12 5,957,554.19 378,243.99 0.50 -4.77 GYD-GC-SS(1) 855.62 1.96 316.94 855.30 799.60 11.78 -10.40 5,957,556.03 378,242.75 1.30 -5.82 GYD-GC-SS(1) 950.35 1.65 246.75 949.99 894.29 12.42 -12.76 5,957,556.71 378,240.40 2.21 -5.33 GYD-GC-SS(1) 1,017.27 4.25 216.67 1,016.82 961.12 10.05 -15.12 5,957,554.38 378,237.99 4.39 -2.15 GYD-GC-SS(1) 1,046.10 5.62 215.32 1,045.54 989.84 8.04 -16.58 5,957,552.40 378,236.51 4.77 0.30 GYD-GC-SS(1) 1,139.67 9.20 213.97 1,138.32 1,082.62 -1.90 -23.41 5,957,542.57 378,229.52 3.83 12.26 MWD+IFR-AK-CAZ-SC(2) 1,233.36 14.14 215.28 1,230.04 1,174.34 -17.47 -34.21 5,957,527.18 378,218.46 5.28 31.02 MWD+IFR-AK-CAZ-SC(2) 1,326.99 19.56 216.77 1,319.62 1,263.92 -39.37 -50.21 5,957,505.54 378,202.11 5.81 57.79 MWD+IFR-AK-CAZ-SC(2) 1,377.22 22.22 214.85 1,366.54 1,310.84 -53.91 -60.67 5,957,491.18 378,191.42 5.47 75.48 MWD+IFR-AK-CAZ-SC(2) 1,422.26 24.40 213.70 1,407.91 1,352.21 -68.64 -70.70 5,957,476.61 378,181.15 4.94 93.15 MWD+IFR-AK-CAZ-SC(2) 1,472.21 26.21 211.32 1,453.06 1,397.36 -86.64 -82.16 5,957,458.79 378,169.40 4.16 114.39 MWD+IFR-AK-CAZ-SC(2) 1,516.77 27.68 209.02 1,492.79 1,437.09 -104.10 -92.30 5,957,441.50 378,158.99 4.04 134.54 MWD+IFR-AK-CAZ-SC(2) 1,567.27 30.11 205.13 1,537.00 1,481.30 -125.83 -103.37 5,957,419.96 378,147.56 6.08 158.93 MWD+IFR-AK-CAZ-SC(2) 1,611.16 33.09 204.16 1,574.38 1,518.68 -146.74 -112.95 5,957,399.21 378,137.65 6.89 181.91 MWD+IFR-AK-CAZ-SC(2) 1,631.32 34.02 203.59 1,591.18 1,535.48 -156.93 -117.46 5,957,389.10 378,132.97 4.87 193.04 MWD+IFR-AK-CAZ-SC(2) 1,705.49 37.52 205.83 1,651.35 1,595.65 -196.28 -135.61 5,957,350.04 378,114.19 5.04 236.35 MW0+IFR-AK-CAZ-SC(2) 1,749.43 39.66 204.96 1,685.69 1,629.99 -221.04 -147.36 5,957,325.48 378,102.04 5.02 263.75 MWD+IFR-AK-CAZ-SC(2) 1,799.40 41.07 205.18 1,723.77 1,668.07 -250.36 -161.07 5,957,296.40 378,087.86 2.84 296.09 MWD+IFR-AK-CAZ-SC(2) 1,893.90 45.79 206.76 1,792.38 1,736.68 -308.72 -189.55 5,957,238.50 378,058.44 5.12 361.03 MWD+IFR-AK-CAZ-SC(2) 1,988.14 46.53 206.88 1,857.65 1,801.95 -369.38 -220.22 5,957,178.35 378,026.80 0.79 429.00 MWD+IFR-AK-CAZ-SC(2) 2,082.27 46.35 206.41 1,922.52 1,866.82 -430.35 -250.81 5,957,117.89 377,995.23 0.41 497.22 MWD+IFR-AK-CAZ-SC(2) 2,177.28 48.36 207.09 1,986.88 1,931.18 -492.75 -282.27 5,957,056.01 377,962.77 2.18 567.10 MWD+IFR-AK-CAZ-SC(2) 2,273.16 53.76 207.18 2,047.12 1,991.42 -559.09 -316.27 5,956,990.24 377,927.70 5.63 641.64 MWD+IFR-AK-CAZ-SC(2) 2,322.18 56.04 208.88 2,075.30 2,019.60 -594.49 -335.12 5,956,955.16 377,908.27 5.45 681.74 MWD+IFR-AK-CAZ-SC(2) 2,365.77 57.89 209.54 2,099.07 2,043.37 -626.38 -352.95 5,956,923.56 377,889.93 4.43 718.24 MWD+IFR-AK-CAZ-SC(2) 2,460.71 60.25 210.00 2,147.86 2,092.16 -697.06 -393.39 5,956,853.54 377,848.35 2.52 799.57 MWD+IFR-AK-CAZ-SC(2) 2,554.60 60.50 211.91 2,194.28 2,138.58 -767.05 -435.37 5,956,784.25 377,805.25 1.79 880.97 MWD+IFR-AK-CAZ-SC(2) 2,649.85 61.88 215.06 2,240.19 2,184.49 -836.64 -481.42 5,956,715.43 377,758.08 3.24 963.84 MWD+IFR-AK-CAZ-SC(2) 2,742.86 63.23 219.26 2,283.07 2,227.37 -902.38 -531.28 5,956,650.50 377,707.17 4.26 1,045.01 MWD+IFR-AK-CAZ-SC(2) 2,837.37 63.96 . 224.05 2,325.12 2,269.42 -965.60 -587.52 5,956,588.21 377,649.91 4.60 1,126.80 MWD+IFR-AK-CAZ-SC(2) 2,869.84 64.39 225.42 2,339.26 2,283.56 -986.36 -608.09 5,956,567.79 377,629.01 4.02 1,154.61 MWD+IFR-AK-CAZ-SC(2) 2,939.12 64.76 229.43 2,369.02 2,313.32 -1,028.68 -654.16 5,956,526.22 377,582.27 5.25 1,213.16 INC+TREND(3) 13-3/8"x 16" 2,965.61 64.93 230.95 2,380.28 2,324.58 -1,044.03 -672.58 5,956,511.17 377,563.61 5.25 1,235.16 INC+TREND(3) 3,020.73 65.46 228.71 2,403.40 2,347.70 -1,076.30 -710.80 5,956,479.53 377,524.87 3.81 1,281.21 INC+TREND(3) 3,114.99 66.20 228.12 2,442.00 2,386.30 -1,133.38 -775.13 5,956,423.50 377,459.64 0.97 1,361.17 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:02:00PM Page 3 COMPASS 5000.1 Build 65 .._........ _.._._..... Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 3,209.60 66.52 229.05 2,479.94 2,424.24 -1,190.71 -840.12 5,956,367.23 377,393.72 0.96 1,441.65 MWD+IFR-AK-CAZ-SC(4) 3,303.50 66.16 228.43 2,517.62 2,461.92 -1,247.43 -904.78 5,956,311.58 377,328.17 0.72 1,521.44 MWD+IFR-AK-CAZ-SC(4) 3,397.99 64.30 228.94 2,557.21 2,501.51 -1,304.08 -969.21 5,956,255.99 377,262.83 2.03 1,601.06 MWD+IFR-AK-CAZ-SC(4) 3,491.63 64.66 228.61 2,597.55 2,541.85 -1,359.76 -1,032.77 5,956,201.34 377,198.38 0.50 1,679.43 MWD+IFR-AK-CAZ-SC(4) 3,586.27 64.39 228.48 2,638.26 2,582.56 -1,416.33 -1,096.80 5,956,145.83 377,133.44 0.31 1,758.79 MWD+IFR-AK-CAZ-SC(4) 3,680.38 64.59 228.30 2,678.79 2,623.09 -1,472.73 -1,160.31 5,956,090.47 377,069.04 0.27 1,837.78 MWD+IFR-AK-CAZ-SC(4) 3,774.89 64.50 228.51 2,719.41 2,663.71 -1,529.38 -1,224.13 5,956,034.86 377,004.32 0.22 1,917.12 MWD+IFR-AK-CAZ-SC(4) 3,869.26 64.53 227.91 2,760.01 2,704.31 -1,586.15 -1,287.64 5,955,979.13 376,939.90 0.57 1,996.44 MWD+IFR-AK-CAZ-SC(4) 3,963.72 64.41 227.14 2,800.72 2,745.02 -1,643.71 -1,350.51 5,955,922.61 376,876.11 0.75 2,076.17 MWD+IFR-AK-CAZ-SC(4) 4,061.51 64.30 226.49 2,843.05 2,787.35 -1,704.04 -1,414.79 5,955,863.33 376,810.87 0.61 2,159.01 MWD+IFR-AK-CAZ-SC(4) 4,159.70 64.61 226.66 2,885.39 2,829.69 -1,764.93 -1,479.13 5,955,803.49 376,745.55 0.35 2,242.38 MWD+IFR-AK-CAZ-SC(4) 4,254.11 64.15 226.96 2,926.21 2,870.51 -1,823.20 -1,541.20 5,955,746.24 376,682.56 0.57 2,322.37 MWD+IFR-AK-CAZ-SC(4) 4,347.74 63.04 226.53 2,967.85 2,912.15 -1,880.66 -1,602.27 5,955,689.78 376,620.56 1.25 2,401.21 MWD+IFR-AK-CAZ-SC(4) 4,442.50 61.89 225.90 3,011.66 2,955.96 -1,938.80 -1,662.94 5,955,632.63 376,558.97 1.35 2,480.46 MWD+IFR-AK-CAZ-SC(4) 4,536.09 60.62 225.68 3,056.66 3,000.96 -1,996.02 -1,721.75 5,955,576.38 376,499.24 1.37 2,558.06 MWD+IFR-AK-CAZ-SC(4) 4,632.01 59.12 225.96 3,104.81 3,049.11 -2,053.83 -1,781.24 5,955,519.54 376,438.83 1.58 2,636.49 MWD+IFR-AK-CAZ-SC(4) 4,727.18 59.45 225.96 3,153.42 3,097.72 -2,110.71 -1,840.06 5,955,463.63 376,379.10 0.35 2,713.78 MWD+IFR-AK-CAZ-SC(4) 4,821.01 59.37 225.92 3,201.17 3,145.47 -2,166.88 -1,898.10 5,955,408.41 376,320.16 0.09 2,790.10 MWD+IFR-AK-CAZ-SC(4) 4,915.29 59.38 227.17 3,249.20 3,193.50 -2,222.68 -1,957.00 5,955,353.58 376,260.38 1.14 2,866.46 MWD+IFR-AK-CAZ-SC(4) 5,010.08 60.25 227.14 3,296.86 3,241.16 -2,278.40 -2,017.07 5,955,298.85 376,199.41 0.92 2,943.29 MWD+IFR-AK-CAZ-SC(4) 5,109.39 61.83 227.50 3,344.94 3,289.24 -2,337.30 -2,080.95 5,955,240.99 376,134.60 1.62 3,024.67 MWD+IFR-AK-CAZ-SC(4) 5,203.58 64.83 227.59 3,387.21 3,331.51 -2,394.10 -2,143.04 5,955,185.20 376,071.60 3.19 3,103.38 MWD+IFR-AK-CAZ-SC(4) 5,299.56 64.66 226.40 3,428.17 3,372.47 -2,453.31 -2,206.52 5,955,127.04 376,007.17 1.14 3,184.85 MWD+IFR-AK-CAZ-SC(4) 5,392.87 63.31 226.51 3,469.09 3,413.39 -2,511.08 -2,267.30 5,955,070.27 375,945.47 1.45 3,263.83 MWD+IFR-AK-CAZ-SC(4) 5,486.09 63.57 226.24 3,510.77 3,455.07 -2,568.61 -2,327.66 5,955,013.73 375,884.19 0.38 3,342.40 MWD+IFR-AK-CAZ-SC(4) 5,580.38 63.54 225.13 3,552.76 3,497.06 -2,627.58 -2,388.06 5,954,955.74 375,822.84 1.05 3,422.28 MWD+IFR-AK-CAZ-SC(4) 5,674.61 62.82 226.05 3,595.28 3,539.58 -2,686.43 -2,448.13 5,954,897.88 375,761.84 1.16 3,501.90 MWD+IFR-AK-CAZ-SC(4) 5,769.13 62.64 226.64 3,638.59 3,582.89 -2,744.43 -2,508.92 5,954,840.88 375,700.12 0.59 3,581.08 MWD+IFR-AK-CAZ-SC(4) 5,863.51 62.69 226.90 3,681.93 3,626.23 -2,801.85 -2,570.01 5,954,784.46 375,638.12 0.25 3,659.88 MWD+IFR-AK-CAZ-SC(4) 5,958.90 62.77 226.20 3,725.63 3,669.93 -2,860.16 -2,631.56 5,954,727.15 375,575.64 0.66 3,739.69 MWD+IFR-AK-CAZ-SC(4) 6,053.79 62.47 226.20 3,769.27 3,713.57 -2,918.48 -2,692.38 5,954,669.83 375,513.89 0.32 3,819.17 MWD+IFR-AK-CAZ-SC(4) 6,146.64 62.60 227.14 3,812.10 3,756.40 -2,975.01 -2,752.30 5,954,614.28 375,453.06 0.91 3,896.66 MWD+IFR-AK-CAZ-SC(4) 6,240.58 62.50 227.55 3,855.40 3,799.70 -3,031.50 -2,813.61 5,954,558.80 375,390.85 0.40 3,974.72 MWD+IFR-AK-CAZ-SC(4) 6,336.26 62.65 228.39 3,899.47 3,843.77 -3,088.36 -2,876.69 5,954,502.98 375,326.86 0.79 4,053.92 MWD+IFR-AK-CAZ-SC(4) 6,430.58 62.80 227.96 3,942.69 3,886.99 -3,144.26 -2,939.17 5,954,448.10 375,263.49 0.44 4,132.00 MWD+IFR-AK-CAZ-SC(4) 6,523.57 62.58 228.74 3,985.36 3,929.66 -3,199.18 -3,000.90 5,954,394.20 375,200.88 0.78 4,208.85 MWD+IFR-AK-CAZ-SC(4) 6,617.74 62.04 229.16 4,029.12 3,973.42 -3,253.94 -3,063.79 5,954,340.47 375,137.12 0.70 4,286.09 MWD+IFR-AK-CAZ-SC(4) 6,712.46 63.21 228.93 4,072.67 4,016.97 -3,309.07 -3,127.31 5,954,286.37 375,072.72 1.25 4,363.95 MWD+IFR-AK-CAZ-SC(4) 6,807.18 64.99 230.03 4,114.04 4,058.34 -3,364.42 -3,192.08 5,954,232.08 375,007.07 2.15 4,442.57 MWD+IFR-AK-CAZ-SC(4) 6,901.57 66.76 229.83 4,152.62 4,096.92 -3,419.87 -3,258.00 5,954,177.71 374,940.26 1.89 4,521.79 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:02:00PM Page 4 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 6,995.55 66.41 230.49 4,189.97 4,134.27 -3,475.12 -3,324.22 5,954,123.54 374,873.17 0.74 4,600.97 MWD+IFR-AK-CAZ-SC(4) 7,090.90 64.90 230.38 4,229.27 4,173.57 -3,530.45 -3,391.19 5,954,069.31 374,805.32 1.59 4,680.56 MWD+IFR-AK-CAZ-SC(4) 7,185.57 66.20 230.38 4,268.46 4,212.76 -3,585.41 -3,457.57 5,954,015.44 374,738.06 1.37 4,759.55 MWD+IFR-AK-CAZ-SC(4) 7,279.26 66.23 230.13 4,306.24 4,250.54 -3,640.22 -3,523.49 5,953,961.71 374,671.27 0.25 4,838.21 MWD+IFR-AK-CAZ-SC(4) 7,372.88 66.19 230.38 4,344.01 4,288.31 -3,695.00 -3,589.36 5,953,908.01 374,604.53 0.25 4,916.80 MWD+IFR-AK-CAZ-SC(4) 7,468.22 66.20 229.97 4,382.49 4,326.79 -3,750.86 -3,656.35 5,953,853.24 374,536.64 0.39 4,996.88 MWD+IFR-AK-CAZ-SC(4) 7,561.95 66.09 229.06 4,420.40 4,364.70 -3,806.52 -3,721.55 5,953,798.66 374,470.56 0.90 5,075.96 MWD+IFR-AK-CAZ-SC(4) 7,656.89 66.15 227.79 4,458.83 4,403.13 -3,864.12 -3,786.49 5,953,742.11 374,404.70 1.22 5,156.67 MWD+IFR-AK-CAZ-SC(4) 7,749.14 65.59 227.45 4,496.54 4,440.84 -3,920.87 -3,848.68 5,953,686.39 374,341.60 0.69 5,235.37 MWD+IFR-AK-CAZ-SC(4) 7,844.14 64.30 227.03 4,536.78 4,481.08 -3,979.30 -3,911.86 5,953,629.00 374,277.48 1.42 5,316.01 MWD+IFR-AK-CAZ-SC(4) 7,938.86 64.08 227.23 4,578.02 4,522.32 -4,037.31 -3,974.36 5,953,572.01 374,214.06 0.30 5,395.98 MWD+IFR-AK-CAZ-SC(4) 8,032.81 64.14 226.83 4,619.04 4,563.34 -4,094.92 -4,036.20 5,953,515.41 374,151.30 0.39 5,475.29 MWD+IFR-AK-CAZ-SC(4) 8,125.50 64.11 227.04 4,659.49 4,603.79 -4,151.87 -4,097.13 5,953,459.46 374,089.46 0.21 5,553.60 MWD+IFR-AK-CAZ-SC(4) 8,222.02 63.80 227.20 4,701.87 4,646.17 -4,210.87 -4,160.68 5,953,401.50 374,024.97 0.35 5,634.93 MWD+IFR-AK-CAZ-SC(4) 8,313.92 63.12 227.26 4,742.93 4,687.23 -4,266.70 -4,221.03 5,953,346.66 373,963.73 0.74 5,711.98 MWD+IFR-AK-CAZ-SC(4) 8,411.28 62.18 227.06 4,787.66 4,731.96 -4,325.50 -4,284.44 5,953,288.90 373,899.38 0.98 5,793.06 MWD+IFR-AK-CAZ-SC(4) 8,503.41 62.08 227.39 4,830.73 4,775.03 -4,380.81 -4,344.22 5,953,234.57 373,838.72 0.33 5,869.39 MWD+IFR-AK-CAZ-SC(4) 8,600.42 62.67 227.20 4,875.71 4,820.01 -4,439.11 -4,407.38 5,953,177.31 373,774.62 0.63 5,949.90 MWD+IFR-AK-CAZ-SC(4) 8,691.17 64.04 227.41 4,916.41 4,860.71 -4,494.11 -4,467.00 5,953,123.29 373,714.13 1.52 6,025.88 MWD+IFR-AK-CAZ-SC(4) 8,790.02 63.59 227.25 4,960.03 4,904.33 -4,554.23 -4,532.22 5,953,064.23 373,647.95 0.48 6,108.96 MWD+IFR-AK-CAZ-SC(4) 8,882.67 62.03 227.12 5,002.36 4,946.66 -4,610.24 -4,592.67 5,953,009.22 373,586.60 1.69 6,186.21 MWD+IFR-AK-CAZ-SC(4) 8,976.21 62.04 227.42 5,046.22 4,990.52 -4,666.30 -4,653.36 5,952,954.15 373,525.02 0.28 6,263.62 MWD+IFR-AK-CAZ-SC(4) 9,071.00 61.95 227.15 5,090.73 5,035.03 -4,723.07 -4,714.85 5,952,898.39 373,462.63 0.27 6,342.02 MWD+IFR-AK-CAZ-SC(4) 9,165.30 62.79 227.13 5,134.47 5,078.77 -4,779.90 -4,776.09 5,952,842.56 373,400.48 0.89 6,420.37 MWD+IFR-AK-CAZ-SC(4) 9,258.78 62.00 227.07 5,177.78 5,122.08 -4,836.28 -4,836.77 5,952,787.17 373,338.90 0.85 6,498.07 MWD+IFR-AK-CAZ-SC(4) 9,353.22 62.03 227.12 5,222.10 5,166.40 -4,893.06 -4,897.86 5,952,731.39 373,276.90 0.06 6,576.29 MWD+IFR-AK-CAZ-SC(4) 9,447.52 62.02 227.58 5,266.33 5,210.63 -4,949.48 -4,959.11 5,952,675.97 373,214.75 0.43 6,654.28 MWD+IFR-AK-CAZ-SC(4) 9,541.95 62.38 227.04 5,310.37 5,254.67 -5,006.12 -5,020.51 5,952,620.34 373,152.45 0.63 6,732.52 MWD+IFR-AK-CAZ-SC(4) 9,636.02 62.29 227.14 5,354.05 5,298.35 -5,062.85 -5,081.53 5,952,564.62 373,090.52 0.13 6,810.68 MWD+IFR-AK-CAZ-SC(4) 9,730.64 62.31 227.38 5,398.03 5,342.33 -5,119,70 -5,143.06 5,952,508.77 373,028.08 0.23 6,889.17 MWD+IFR-AK-CAZ-SC(4) 9,825.32 62.82 227.30 5,441.66 5,385.96 -5,176.65 -5,204.86 5,952,452.84 372,965.38 0.54 6,967.87 MWD+IFR-AK-CAZ-SC(4) 9,919.47 63.85 227.56 5,483.91 5,428.21 -5,233.56 -5,266.82 5,952,396.94 372,902.51 1.12 7,046.62 MWD+IFR-AK-CAZ-SC(4) 10,013.65 63.81 227.33 5,525.44 5,469.74 -5,290.73 -5,329.08 5,952,340.80 372,839.33 0.22 7,125.72 MWD+IFR-AK-CAZ-SC(4) 10,109.47 63.92 226,77 5,567.65 5,511.95 -5,349.34 -5,392.05 5,952,283.22 372,775.43 0.54 7,206.43 MWD+IFR-AK-CAZ-SC(4) 10,202.84 63.88 226.62 5,608.73 5,553.03 -5,406.85 -5,453.06 5,952,226.71 372,713.49 0.15 7,285.28 MWD+IFR-AK-CAZ-SC(4) 10,298.09 63.81 227.01 5,650.72 5,595.02 -5,465.36 -5,515.40 5,952,169.22 372,650.22 0.37 7,365.62 MWD+IFR-AK-CAZ-SC(4) 10,390.13 63.74 227.21 5,691.39 5,635.69 -5,521.55 -5,575.90 5,952,114.02 372,588.83 0.21 7,443.06 MWD+IFR-AK-CAZ-SC(4) 10,483.60 63.96 227.44 5,732.58 5,676,88 -5,578.43 -5,637.58 5,952,058.15 372,526.24 0.32 7,521.64 MWD+IFR-AK-CAZ-SC(4) 10,579.65 63.75 228.62 5,774.91 5,719.21 -5,636.09 -5,701.69 5,952,001.55 372,461.21 1.12 7,602.02 MWD+IFR-AK-CAZ-SC(4) 10,675.73 62.80 229.21 5,818.11 5,782.41 -5,692.48 -5,766.37 5,951,946.21 372,395.63 1.13 7,681.53 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:02:0OPM Page 5 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (") (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,768.32 63.34 230.34 5,860.05 5,804.35 -5,745.79 -5,829.39 5,951,893.93 372,331.76 1.23 7,757.54 MWD+IFR-AK-CAZ-SC(4) 10,862.66 63.66 231.38 5,902.15 5,846.45 -5,799.08 -5,894.88 5,951,841.71 372,265.43 1.04 7,834.63 MWD+IFR-AK-CAZ-SC(4) 10,957.11 64.49 231.37 5,943.44 5,887.74 -5,852.10 -5,961.24 5,951,789.78 372,198.22 0.88 7,911.89 MWD+IFR-AK-CAZ-SC(4) 11,051.39 66.41 231.89 5,982.61 5,926.91 -5,905.33 -6,028.47 5,951,737.65 372,130.14 2.10 7,989.72 MWD+IFR-AK-CAZ-SC(4) 11,145.65 67.42 232.61 6,019.57 5,963.87 -5,958.42 -6,097.03 5,951,685.69 372,060.73 1.28 8,068.03 MWD+IFR-AK-CAZ-SC(4) 11,240.19 66.98 231.89 6,056.20 6,000.50 -6,011.77 -6,165.94 5,951,633.46 371,990.97 0.84 8,146.73 MWD+IFR-AK-CAZ-SC(4) 11,334.03 66.53 231.07 6,093.24 6,037.54 -6,065.47 -6,233.40 5,951,580.87 371,922.66 0.94 8,225.08 MWD+IFR-AK-CAZ-SC(4) 11,428.50 66.27 229.72 6,131.06 6,075.36 -6,120.65 -6,300.10 5,951,526.77 371,855.08 1.34 8,304.42 MWD+IFR-AK-CAZ-SC(4) 11,522.09 67.92 229.41 6,167.49 6,111.79 -6,176.57 -6,365.72 5,951,471.93 371,788.57 1.79 8,383.92 MWD+IFR-AK-CAZ-SC(4) 11,618.23 68.21 228.84 6,203.40 6,147.70 -6,234.93 -6,433.15 5,951,414.68 371,720.21 0.63 8,466.42 MWD+IFR-AK-CAZ-SC(4) 11,709.22 66.54 228.38 6,238.40 6,182.70 -6,290.45 -6,496.16 5,951,360.18 371,656.32 1.89 8,544.40 MWD+IFR-AK-CAZ-SC(4) 11,806.82 64.65 227.67 6,278.73 6,223.03 -6,349.89 -6,562.23 5,951,301.83 371,589.29 2.05 8,627.25 MWD+IFR-AK-CAZ-SC(4) 11,902.08 64.98 226.79 6,319.27 6,263.57 -6,408.43 -6,625.51 5,951,244.33 371,525.08 0.90 8,708.04 MWD+IFR-AK-CAZ-SC(4) 11,995.01 64.86 225.87 6,358.66 6,302.96 -6,466.55 -6,686.39 5,951,187.21 371,463.27 0.91 8,787.37 MWD+IFR-AK-CAZ-SC(4) 12,089.38 64.07 225.87 6,399.34 6,343.64 -6,525.84 -6,747.51 5,951,128.92 371,401.20 0.84 8,867.86 MWD+IFR-AK-CAZ-SC(4) 12,183.80 62.22 225.46 6,441.99 6,386.29 -6,584.70 -6,807.76 5,951,071.05 371,340.01 2.00 8,947.57 MWD+IFR-AK-CAZ-SC(4) 12,278.58 62.36 224.48 6,486.06 6,430.36 -6,644.06 -6,867.06 5,951,012.66 371,279.76 0.93 9,027.30 MWD+IFR-AK-CAZ-SC(4) 12,372.96 63.01 224.46 6,529.37 6,473.67 -6,703.91 -6,925.81 5,950,953.78 371,220.06 0.69 9,107.20 MWD+IFR-AK-CAZ-SC(4) 12,466.15 63.04 224.54 6,571.64 6,515.94 -6,763.14 -6,984.02 5,950,895.50 371,160.90 0.08 9,186.33 MWD+IFR-AK-CAZ-SC(4) 12,560.81 62.61 224.86 6,614.87 6,559.17 -6,823.00 -7,043.25 5,950,836.61 371,100.71 0.54 9,266.47 MWD+IFR-AK-CAZ-SC(4) 12,655.36 61.95 225.25 6,658.85 6,603.15 -6,882.13 -7,102.49 5,950,778.46 371,040.53 0.79 9,345.96 MWD+IFR-AK-CAZ-SC(4) 12,750.08 62.27 226.26 6,703.16 6,647.46 -6,940.54 -7,162.46 5,950,721.03 370,979.63 1.00 9,425.14 MWD+IFR-AK-CAZ-SC(4) 12,843.46 63.21 226.42 6,745.93 6,690.23 -6,997.84 -7,222.51 5,950,664.71 370,918.66 1.02 9,503.38 MWD+IFR-AK-CAZ-SC(4) 12,938.76 64.15 226.31 6,788.19 6,732.49 -7,056.79 -7,284.34 5,950,606.78 370,855.89 0.99 9,583.87 MWD+IFR-AK-CAZ-SC(4) 12,938.81 64.15 226.31 6,788.21 6,732.51 -7,056.82 -7,284.37 5,950,606.75 370,855,86 0.00 9,583.91 GYD-GC-MS(5) 9-5/8"x 12-1/4" 12,950.00 63.54 226.00 6,793.14 6,737.44 -7,063.78 -7,291.61 5,950,599.91 370,848.51 5.99 9,593.39 GYD-GC-MS(5) 12,975.00 64.18 224.82 6,804.15 6,748.45 -7,079.53 -7,307.60 5,950,584.41 370,832.27 4.95 9,614.66 GYD-GC-MS(5) 13,000.00 63.89 225.34 6,815.10 6,759.40 -7,095.40 -7,323.51 5,950,568.80 370,816.10 2.20 9,636.01 GYD-GC-MS(5) 13,025.00 64.17 225.27 6,826.05 6,770.35 -7,111.21 -7,339.49 5,950,553.26 370,799.87 1.15 9,657.32 GYD-GC-MS(5) 13,050.00 64.25 225.40 6,836.92 6,781.22 -7,127.03 -7,355.50 5,950,537.70 370,783.61 0.57 9,678.66 GYD-GC-MS(5) 13,075.00 64.20 225.59 6,847.80 6,792.10 -7,142.82 -7,371.55 5,950,522.18 370,767.30 0.71 9,699.99 GYD-GC-MS(5) 13,100.00 64.13 225.38 6,858.69 6,802.99 -7,158.59 -7,387.60 5,950,506.67 370,751.01 0.81 9,721.31 GYD-GC-MS(5) 13,125.00 64.65 224.61 6,869.50 6,813.80 -7,174.53 -7,403.54 5,950,490.99 370,734.81 3.47 9,742.73 GYD-GC-MS(5) 13,150.00 65.19 223.99 6,880.09 6,824.39 -7,190.74 -7,419.35 5,950,475.04 370,718.74 3.12 9,764.32 GYD-GC-MS(5) 13,175.00 65.92 223.54 6,890.44 6,834.74 -7,207.18 -7,435.09 5,950,458.86 370,702.74 3.35 9,786.09 GYD-GC-MS(5) 13,200.00 66.20 222.89 6,900.58 6,844.88 -7,223.83 -7,450.74 5,950,442.47 370,686.82 2.63 9,808.01 GYD-GC-MS(5) 13,225.00 66.64 222.23 6,910.58 6,854.88 -7,240.70 -7,466.24 5,950,425.85 370,671.06 2.99 9,830.06 GYD-GC-MS(5) 13,250.00 66.97 221.37 6,920.43 6,864.73 -7,257.83 -7,481.55 5,950,408.97 370,655.47 3.43 9,852.26 GYD-GC-MS(5) 13,275.00 67.36 220.53 6,930.13 6,874.43 -7,275.24 -7,496.65 5,950,391.81 370,640.09 3.47 9,874.60 GYD-GC-MS(5) 9/8/2014 1:02:00PM Page 6 COMPASS 5000 1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 13,300.00 67.39 219.68 6,939.75 6,884.05 -7,292.89 -7,511.52 5,950,374.41 370,624.94 3.14 9,897.06 GYD-GC-MS(5) 13,325.00 67.44 218.72 6,949.35 6,893.65 -7,310.77 -7,526.11 5,950,356.76 370,610.06 3.55 9,919.61 GYD-GC-MS(5) 13,350.00 67.54 217.54 6,958.92 6,903.22 -7,328.94 -7,540.37 5,950,338.83 370,595.51 4.38 9,942.25 GYD-GC-MS(5) 13,375.00 67.25 216.41 6,968.53 6,912.83 -7,347.38 -7,554.25 5,950,320.62 370,581.34 4.33 9,964.97 GYD-GC-MS(5) 13,400.00 66.96 215.39 6,978.26 6,922.56 -7,366.03 -7,567.75 5,950,302.19 370,567.53 3.93 9,987.71 GYD-GC-MS(5) 13,465.21 67.53 212.48 7,003.49 6,947.79 -7,415.92 -7,601.31 5,950,252.86 370,533.17 4.21 10,047.37 MWD+IFR-AK-CAZ-SC(6) 13,560.91 68.34 210.30 7,039.44 6,983.74 -7,491.63 -7,647.50 5,950,177.91 370,485.77 2.27 10,135.77 MWD+IFR-AK-CAZ-SC(6) 13,654.68 69.01 203.92 7,073.57 7,017.87 -7,569.33 -7,687.27 5,950,100.87 370,444.75 6.38 10,223.06 MWD+IFR-AK-CAZ-SC(6) 13,700.47 68.91 199.71 7,090.02 7,034.32 -7,609.00 -7,703.15 5,950,061.47 370,428.23 8.58 10,265.63 MWD+IFR-AK-CAZ-SC(6) 13,748.25 69.13 196.13 7,107.13 7,051.43 -7,651.44 -7,716.87 5,950,019.26 370,413.82 7.01 10,309.69 MWD+IFR-AK-CAZ-SC(6) 13,798.47 69.79 194.58 7,124.75 7,069.05 -7,696.79 -7,729.32 5,949,974.12 370,400.64 3.17 10,355.78 MWD+IFR-AK-CAZ-SC(6) 13,843.43 69.77 191.80 7,140.29 7,084.59 -7,737.86 -7,738.95 5,949,933.22 370,390.35 5.80 10,396.78 MWD+IFR-AK-CAZ-SC(6) 13,892.22 70.19 189.78 7,157.00 7,101.30 -7,782.88 -7,747.53 5,949,888.34 370,381.04 3.98 10,440.84 MWD+IFR-AK-CAZ-SC(6) 13,937.58 71.10 188.49 7,172.03 7,116.33 -7,825.14 -7,754.32 5,949,846.20 370,373.57 3.35 10,481.61 MWD+IFR-AK-CAZ-SC(6) 13,986.39 71.07 186.42 7,187.85 7,132.15 -7,870.92 -7,760.31 5,949,800.53 370,366.84 4.01 10,525.17 MWD+IFR-AK-CAZ-SC(6) 14,032.29 70.92 185.22 7,202.80 7,147.10 -7,914.09 -7,764.71 5,949,757.44 370,361.74 2.49 10,565.69 MWD+IFR-AK-CAZ-SC(6) 14,126.12 71.40 181.77 7,233.11 7,177.41 -8,002.71 -7,770.12 5,949,668.92 370,354.90 3.52 10,647.22 MWD+IFR-AK-CAZ-SC(6) 14,220.43 71.92 178.71 7,262.79 7,207.09 -8,092.22 -7,770.49 5,949,579.44 370,353.07 3.13 10,727.27 MWD+IFR-AK-CAZ-SC(6) 14,315.67 72.54 176.02 7,291.86 7,236.16 -8,182.81 -7,766.32 5,949,488.80 370,355.78 2.77 10,806.24 MWD+IFR-AK-CAZ-SC(6) 14,409.52 74.45 174.84 7,318.53 7,262.83 -8,272.50 -7,759.15 5,949,399.02 370,361.50 2.37 10,883.05 MWD+IFR-AK-CAZ-SC(6) 14,503.54 77.35 176.58 7,341.43 7,285.73 -8,363.42 -7,752.33 5,949,308.01 370,366.84 3.57 10,961.12 MWD+IFR-AK-CAZ-SC(6) 14,598.40 76.68 175.26 7,362.75 7,307.05 -8,455.62 -7,745.76 5,949,215.72 370,371.92 1.53 11,040.44 MWD+IFR-AK-CAZ-SC(6) 14,693.07 75.36 171.48 7,385.62 7,329.92 -8,546.85 -7,735.16 5,949,124.34 370,381.03 4.12 11,117.09 MWD+IFR-AK-CAZ-SC(6) 14,787.08 75.52 167.79 7,409.26 7,353.56 -8,636.34 -7,718.80 5,949,034.60 370,395.95 3.80 11,189.57 MWD+IFR-AK-CAZ-SC(6) 14,881.67 75.70 165.45 7,432.78 7,377.08 -8,725.46 -7,697.59 5,948,945.15 370,415.70 2.40 11,259.55 MWD+IFR-AK-CAZ-SC(6) 14,975.07 77.57 165.52 7,454.36 7,398.66 -8,813.43 -7,674.82 5,948,856.84 370,437.05 2.00 11,327.79 MWD+IFR-AK-CAZ-SC(6) 15,069.85 79.46 163.22 7,473.24 7,417.54 -8,902.87 -7,649.79 5,948,767.01 370,460.62 3.10 11,396.32 MWD+IFR-AK-CAZ-SC(6) 15,132.00 81.16 162.43 7,483.70 7,428.00 -8,961.39 -7,631.70 5,948,708.21 370,477.76 3.01 11,440.39 MWD+IFR-AK-CAZ-SC(6) Kick-off Point-7"x 8-3/4"x 9-7/8" 15,145.00 82.00 163.25 7,485.60 7,429.90 -8,973.68 -7,627.91 5,948,695.86 370,481.35 8.99 11,449.65 INC+TREND(7) 15,164.10 82.33 163.11 7,488.21 7,432.51 -8,991.79 -7,622.43 5,948,677.66 370,486.54 1.87 11,463.34 INC+TREND(7) 15,216.01 90.21 162.73 7,491.58 7,435.88 -9,041.27 -7,607.23 5,948,627.95 370,500.93 15.20 11,500.64 INC+TREND(7) 15,251.68 92.21 162.47 7,490.83 7,435.13 -9,075.30 -7,596.57 5,948,593.76 370,511.04 5.65 11,526.20 INC+TREND(7) 15,343.82 88.77 161.39 7,490.04 7,434.34 -9,162.88 -7,567.99 5,948,505.74 370,538.19 3.91 11,591.47 MWD+IFR-AK-CAZ-SC(8) 15,438.85 86.71 161.62 7,493.79 7,438.09 -9,252.92 -7,537.87 5,948,415.22 370,566.85 2.18 11,658.25 MWD+IFR-AK-CAZ-SC(8) 15,532.67 86.75 165.12 7,499.14 7,443.44 -9,342.66 -7,511.07 5,948,325.07 370,592.19 3.72 11,726.25 MWD+IFR-AK-CAZ-SC(8) 15,628.21 87.02 165.11 7,504.33 7,448.63 -9,434.86 -7,486.56 5,948,232.50 370,615.20 0.28 11,797.48 MWD+IFR-AK-CAZ-SC(8) 15,722.62 86.40 163.81 7,509.75 7,454.05 -9,525.66 -7,461.31 5,948,141.30 370,638.98 1.52 11,867.13 MWD+IFR-AK-CAZ-SC(8) 15,816.83 89.63 162.25 7,513.01 7,457.31 -9,615.70 -7,433.83 5,948,050.83 370,664.99 3.81 11,935.10 MWD+IFR-AK-CAZ-SC(8) 15,911.98 88.50 159.95 7,514.57 7,458.87 -9,705.70 -7,403.02 5,947,960.35 370,694.34 2.69 12,001.52 MWD+IFR-AK-CAZ-SC(8) 16,005.98 88.36 160.14 7,517.14 7,461.44 -9,794.02 -7,370.95 5,947,871.53 370,724.97 0.25 12,065.89 MWD+IFR-AK-CAZ-SC(8) 9/8/2014 1:02:00PM Page 7 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 16,100.28 89.25 160.21 7,519.11 7,463.41 -9,882.72 -7,338.98 5,947,782.34 370,755.50 0.95 12,130.62 MWD+IFR-AK-CAZ-SC(8) 16,194.91 89.18 160.41 7,520.40 7,464.70 -9,971.80 -7,307.10 5,947,692.76 370,785.93 0.22 12,195.75 MWD+IFR-AK-CAZ-SC(8) 16,289.78 90.01 161.46 7,521.08 7,465.38 -10,061.47 -7,276.11 5,947,602.61 370,815.46 1.41 12,261.79 MWD+IFR-AK-CAZ-SC(8) 16,384.30 90.01 162.34 7,521.06 7,465.36 -10,151.31 -7,246.75 5,947,512.31 370,843.36 0.93 12,328.73 MWD+IFR-AK-CAZ-SC(8) 16,479.19 89.97 163.68 7,521.08 7,465.38 -10,242.05 -7,219.02 5,947,421.14 370,869.62 1.41 12,397.21 MWD+IFR-AK-CAZ-SC(8) 16,572.63 89.97 166.42 7,521.12 7,465.42 -10,332.32 -7,194.92 5,947,330.50 370,892.25 2.93 12,466.90 MWD+IFR-AK-CAZ-SC(8) 16,667.87 89.49 170.75 7,521.57 7,465.87 -10,425.66 -7,176.07 5,947,236.88 370,909.58 4.57 12,541.70 MWD+IFR-AK-CAZ-SC(8) 16,761.84 89.32 174.15 7,522.55 7,466.85 -10,518.79 -7,163.73 5,947,143.56 370,920.41 3.62 12,619.26 MWD+IFR-AK-CAZ-SC(8) 16,853.13 89.56 175.20 7,523.44 7,467.74 -10,609.68 -7,155.25 5,947,052.55 370,927.41 1.18 12,696.55 MWD+IFR-AK-CAZ-SC(8) 16,947.97 89.63 178.04 7,524.11 7,468.41 -10,704.35 -7,149.66 5,946,957.82 370,931.47 3.00 12,778.52 MWD+IFR-AK-CAZ-SC(8) 17,045.46 89.75 179.36 7,524.64 7,468.94 -10,801.81 -7,147.45 5,946,860.35 370,932.10 1.36 12,864.50 MWD+IFR-AK-CAZ-SC(8) 17,139.92 88.06 177.02 7,526.45 7,470.75 -10,896.19 -7,144.47 5,946,765.93 370,933.55 3.06 12,947.39 MWD+IFR-AK-CAZ-SC(8) 17,235.28 89.72 177.19 7,528.29 7,472.59 -10,991.41 -7,139.66 5,946,670.66 370,936.83 1.75 13,030.20 MWD+IFR-AK-CAZ-SC(8) 17,330.21 87.23 176.46 7,530.82 7,475.12 -11,086.15 -7,134.40 5,946,575.85 370,940.55 2.73 13,112.39 MWD+IFR-AK-CAZ-SC(8) 17,397.08 88.18 174.35 7,533.50 7,477.80 -11,152.75 -7,129.05 5,946,509.18 370,944.82 3.46 13,169.41 MWD+IFR-AK-CAZ-SC(8) 17,422.94 90.08 173.33 7,533.89 7,478.19 -11,178.45 -7,126.27 5,946,483.43 370,947.18 8.34 13,191.10 MWD+IFR-AK-CAZ-SC(8) 17,468.58 89.04 169.73 7,534.24 7,478.54 -11,223.59 -7,119.55 5,946,438.20 370,953.17 8.21 13,228.35 MWD+IFR-AK-CAZ-SC(8) 17,517.67 88.94 167.77 7,535.11 7,479.41 -11,271.72 -7,109.98 5,946,389.92 370,961.96 4.00 13,266.99 MWD+IFR-AK-CAZ-SC(8) 17,612.55 89.02 164.36 7,536.79 7,481.09 -11,363.78 -7,087.13 5,946,297.51 370,983.31 3.59 13,338.85 MWD+IFR-AK-CAZ-SC(8) I 17,707.55 88.13 162.15 7,539.16 7,483.46 -11,454.72 -7,059.77 5,946,206.15 371,009.19 2.51 13,407.67 MWD+IFR-AK-CAZ-SC(8) 17,802.66 90.10 159.62 7,540.63 7,484.93 -11,544.56 -7,028.64 5,946,115.82 371,038.86 3.37 13,473.81 MWD+IFR-AK-CAZ-SC(8) 17,895.09 89.70 160.02 7,540.79 7,485.09 -11,631.32 -6,996.75 5,946,028.57 371,069.34 0.61 13,536.85 MWD+IFR-AK-CAZ-SC(8) 17,941.65 89.40 162.72 7,541.15 7,485.45 -11,675.43 -6,981.88 5,945,984.22 371,083.49 5.83 13,569.52 MWD+IFR-AK-CAZ-SC(8) 17,990.31 90.69 165.42 7,541.12 7,485.42 -11,722.22 -6,968.53 5,945,937.23 371,096.08 6.15 13,605.25 MWD+IFR-AK-CAZ-SC(8) 18,084.58 90.47 164.95 7,540.16 7,484.46 -11,813.35 -6,944.42 5,945,845.73 371,118.71 0.55 13,675.71 MWD+IFR-AK-CAZ-SC(8) 18,178.65 88.74 166.16 7,540.81 7,485.11 -11,904.44 -6,920.96 5,945,754.28 371,140.69 2.24 13,746.42 MWD+IFR-AK-CAZ-SC(8) 18,273.38 87.73 169.04 7,543.73 7,488.03 -11,996.91 -6,900.63 5,945,661.50 371,159.52 3.22 13,819.77 MWD+IFR-AK-CAZ-SC(8) 18,367.86 88.65 171.18 7,546.71 7,491.01 -12,089.93 -6,884.41 5,945,568.24 371,174.23 2.46 13,895.48 MWD+IFR-AK-CAZ-SC(8) 18,462.73 88.43 172.86 7,549.13 7,493.43 -12,183.85 -6,871.24 5,945,474.13 371,185.87 1.79 13,973.36 MWD+IFR-AK-CAZ-SC(8) 18,557.24 89.40 171.17 7,550.92 7,495.22 -12,277.42 -6,858.12 5,945,380.36 371,197.48 2.06 14,050.95 MWD+IFR-AK-CAZ-SC(8) 18,652.48 89.32 167.37 7,551.98 7,496.28 -12,370.97 -6,840.39 5,945,286.54 371,213.69 3.99 14,126.45 MWD+IFR-AK-CAZ-SC(8) 18,747.71 89.25 165.57 7,553.17 7,497.47 -12,463.55 -6,818.11 5,945,193.63 371,234.46 1.89 14,199.02 MWD+IFR-AK-CAZ-SC(8) 18,841.05 89.95 153.64 7,553.83 7,498.13 -12,550.87 -6,785.64 5,945,105.79 371,265.51 12.80 14,262.32 MWD+IFR-AK-CAZ-SC(8) 18,885.14 89.24 153.90 7,554.14 7,498.44 -12,590.42 -6,766.16 5,945,065.94 371,284.35 1.71 14,288.82 MWD+IFR-AK-CAZ-SC(8) 18,936.58 89.80 147.88 7,554.57 7,498.87 -12,635.34 -6,741.15 5,945,020.62 371,308.63 11.75 14,317.63 MWD+IFR-AK-CAZ-SC(8) 18,981.62 90.20 142.33 7,554.57 7,498.87 -12,672.27 -6,715.39 5,944,983.28 371,333.78 12.35 14,338.97 MWD+IFR-AK-CAZ-SC(8) I 19,029.29 89.30 143.80 7,554.78 7,499.08 -12,710.37 -6,686.75 5,944,944.73 371,361.80 3.62 14,360.05 MWD+IFR-AK-CAZ-SC(8) 19,124.73 90.69 142.60 7,554.79 7,499.09 -12,786.79 -6,629.58 5,944,867.40 371,417.72 1.92 14,402.47 MWD+IFR-AK-CAZ-SC(8) 19,231.81 89.04 145.28 7,555.04 7,499.34 -12,873.34 -6,566.55 5,944,779.84 371,479.33 2.94 14,451.29 MWD+IFR-AK-CAZ-SC(8) 19,293.00 89.04 145.28 7,556.06 7,500.36 -12,923.63 -6,531.71 5,944,729.00 371,513.35 0.00 14,480.45 PROJECTED to TD 9/8/2014 1:02:OOPM Page 8 COMPASS 50004 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4-1/2"x 6-1/8" 9/8/2014 1:02:00PM Page 9 COMPASS 5000.1 Build 65 g 0 > - 7:5000 0 almo+ o o "16 CUi ^ `r >. N pry o. o 0 y ' d �Y o U0 E c o z o- w ,...4, E =— a) m o • o .S., • v m +-� C o 0 w •O o a) 0 0 a) TI 1 .Q 'Q Cu a) v) = 0 o C _� o z E m o O ow V1 :. o a) c Cl) > h ❑ w co o ,_ a) r' T o i c U o "a a) irz ) OC c a) O U o op 0 : 1— � C CD RI a Y ami LL w > y (D0U � a) ° wooao coQ w 0 C in co Cuw 92 o_ a) cC c a)U 2 1 40 56 253. 30 chiumberger Transmittal#: 27JAN15-SP02 Drilling & Measurements DATALpGGED MWD/LWD Log Pr educt Delivery \/2-&2oi M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: CD4-96A PB1 Date Dispatched: 27-Jan-15 Job#: 14AKA0039 Dispatched By: Stephanie Pacillo Well/ Product Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A Scope Resistivity 2"MD x x Scope Resistivity 2"TVD x x Scope Resistivity 5"MD JAN Z015 x x Scope Resistivity 5"ND x x LAS Digital Data N/A Contents on CD x Directional Data 1 Contents on CD Nad27 x x As-Built Survey 1 Contents on CD Nad83 x x EOW CD 1 Contents on CD Data:DLIS/ASCII x Graphics:pdf/tiff x Survey: PDF x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(cslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 ��, Received By: )y" ���� 214056 25330 RECEIVED JAN 2 7 2015 FINAL AOGCC NADConversion Western North Slope CD4 Nanuq Pad CD4-96APB1 Definitive Survey Report NAD 2 7 08 September, 2014 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-96 Well Position +N/-S 0.00 usft Northing: 5,957,544.09 usft Latitude: 70°17 33.155 N +E/-W 0.00 usft Easting: 378,252.95 usft Longitude: 150°59'8.492 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 18.90 usft Wellbore CD4-96APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2013 6/5/2014 18.78 80.77 57,576 Design CD4-96APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,938.76 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 196.28 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.32 1,046.10 CD4-96 Gyro(CD4-96) GYD-GC-SS Gyrodata gyro single shots 11/13/2013 12:01 1,139.67 2,869.84 CD4-96 MWD I(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFRAKCAZSCC 11/13/2013 12:01 2,965.61 3,020.73 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND Inclinometer+known azi trend 2/11/2014 12:00: 1 3,114.99 12,938.76 CD4-96 MWD II(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 12,950.00 13,400.00 CD4-96APB1 Svy1 SLB_NSG+MSHOT( GYD-GC-MS Gyrodata gyrocompassing m/s 6/16/2014 9:15: 13,465.21 19,979.01 CD4-96APB1 Svy2 SLB-MWD-GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2014 10:01 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/1001 (ft) Survey Tool Name 36.80 0.00 0.00 36.80 -18.90 0.00 0.00 5,957,544.09 378,252.95 0.00 0.00 UNDEFINED 75.32 0.12 214.58 75.32 19.62 -0.03 -0.02 5,957,544.06 378,252.93 0.31 0.04 GYD-GC-SS(1) 104.55 0.19 179.56 104.55 , 48.85 -0.11 -0.04 5,957,543.98 378,252.91 0.39 0.11 GYD-GC-SS(1) 114.15 0.14 183.36 114.15 58.45 -0.13 -0.04 5,957,543.95 378,252.91 0.51 0.14 GYD-GC-SS(1) 20"x 42" 144.37 0.04 280.72 144.37 88.67 -0.17 -0.05 5,957,543.92 378,252.89 0.51 0.18 GYD-GC-SS(1) 241.06 0.41 229.08 241.06 185.36 -0.39 -0.35 5,957,543.70 378,252.60 0.40 0.47 GYD-GC-SS(1) 333.50 0.51 232.63 333.50 277.80 -0.86 -0.92 5,957,543.25 378,252.01 0.11 1.08 GYD-GC-SS(1) 423.96 0.76 273.71 423.95 368.25 -1.06 -1.84 5,957,543.06 378.251.09 0.56 1.54 GYD-GC-SS(1) 520.36 1.79 306.49 520.33 464.63 -0.13 -3.69 5,957,544.02 378,249.26 1.27 1.16 GYD-GC-SS(1) 9/8/2014 1:00:48PM Page 2 COMPASS 5000.1 Build 65 Sc hl urn berger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 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 612.19 2.95 333.58 612.08 556.38 2.84 -5.90 5,957,547.03 378,247.10 1 72 -1.08 GYD-GC-SS(1) 703.41 2.13 339.50 703.21 647.51 6.53 -7.53 5,957,550.74 378,245.52 0,94 -4.16 GYD-GC-SS(1) 797.65 2.47 331.34 797.37 741.67 9.96 -9.12 5,957,554.19 378,243.99 0.50 -7.00 GYD-GC-SS(1) 855.62 1.96 316.94 855.30 799.60 11.78 -10.40 5,957,556.03 378,242.75 1.30 -8.39 GYD-GC-SS(1) 950.35 1.65 246.75 949.99 894.29 12.42 -12.76 5,957,556.71 378,240.40 2.21 -8.35 GYD-GC-SS(1) 1,017.27 4.25 216.67 1,016.82 961.12 10.05 -15.12 5,957,554.38 378,237.99 4.39 -5.41 GYD-GC-SS(1) 1,046.10 5.62 215.32 1,045.54 989.84 8.04 -16.58 5,957,552.40 378,236.51 4.77 -3.07 GYD-GC-SS(1) 1,139.67 9.20 213.97 1,138.32 1,082.62 -1.90 -23.41 5,957,542.57 378,229.52 3.83 8.39 MWD+IFR-AK-CAZ-SC(2) 1,233.36 14.14 215.28 1,230.04 1,174.34 -17.47 -34.21 5,957,527.18 378,218.46 5.28 26.36 MWD+IFR-AK-CAZ-SC(2) 1,326.99 19.56 216.77 1,319.62 1,263.92 -39.37 -50.21 5,957,505.54 378,202.11 5.81 51.87 MWD+IFR-AK-CAZ-SC(2) 1,377.22 22.22 214.85 1,366.54 1,310.84 -53.91 -60.67 5,957,491.18 378,191.42 5.47 68.76 MWD+IFR-AK-CAZ-SC(2) 1,422.26 24.40 213.70 1,407.91 1,352.21 -68.64 -70.70 5,957,476.61 378,181.15 4.94 85.71 MWD+IFR-AK-CAZ-SC(2) 1,472.21 26.21 211.32 1,453.06 1,397.36 -86.64 -82.16 5,957,458.79 378,169.40 4.16 106.21 MWD+IFR-AK-CAZ-SC(2) 1,516.77 27.68 209.02 1,492.79 1,437.09 -104.10 -92.30 5,957,441.50 378,158.99 4.04 125.81 MWD+IFR-AK-CAZ-SC(2) 1,567.27 30.11 205.13 1,537.00 1,481.30 -125.83 -103.37 5,957,419.96 378,147.56 6.08 149.77 MWD+IFR-AK-CAZ-SC(2) 1,611.16 33.09 204.16 1,574.38 1,518.68 -146.74 -112.95 5,957,399.21 378,137.65 6.89 172.52 MW0+IFR-AK-CAZ-SC(2) 1,631.32 34.02 203.59 1,591.18 1,535.48 -156.93 -117.46 5,957,389.10 378,132.97 4.87 183.57 MWD+IFR-AK-CAZ-SC(2) 1,705.49 37.52 205.83 1,651.35 1,595.65 -196.28 -135.61 5,957,350.04 378,114.19 5.04 226.44 MWD+IFR-AK-CAZ-SC(2) 1,749.43 39.66 204.96 1,685.69 1,629.99 -221.04 -147.36 5,957,325.48 378,102.04 5.02 253.50 MWD+IFR-AK-CAZ-SC(2) 1,799.40 41.07 205.18 1,723.77 1,668.07 -250.36 -161.07 5,957,296.40 378,087.86 2.84 285.48 MWD+IFR-AK-CAZ-SC(2) 1,893.90 45.79 206.76 1,792.38 1,736.68 -308.72 -189.55 5,957,238.50 378,058.44 5.12 349.49 MWD+IFR-AK-CAZ-SC(2) 1,988.14 46.53 206.88 1,857.65 1,801.95 -369.38 -220.22 5,957,178.35 378,026.80 0.79 416.32 MWD+IFR-AK-CAZ-SC(2) 2,082.27 46.35 206.41 1,922.52 1,866.82 -430.35 -250.81 5,957,117.89 377,995.23 0.41 483.41 MWD+IFR-AK-CAZ-SC(2) 2,177.28 48.36 207.09 1,986.88 1,931.18 -492.75 -282.27 5,957,056.01 377,962.77 2.18 552.13 MWD+IFR-AK-CAZ-SC(2) 2,273.16 53.76 207.18 2,047.12 1,991.42 -559.09 -316.27 5,956,990.24 377,927.70 5.63 625.35 MWD+IFR-AK-CAZ-SC(2) 2,322.18 56.04 208.88 2,075.30 2,019.60 -594.49 -335.12 5,956,955.16 377,908.27 5.45 664.61 MWD+IFR-AK-CAZ-SC(2) 2,365.77 57.89 209.54 2,099.07 2,043.37 -626.38 -352.95 5,956,923.56 377,889.93 4.43 700.22 MWD+IFR-AK-CAZ-SC(2) 2,460.71 60.25 210.00 2,147.86 2,092.16 -697.06 -393.39 5,956,853.54 377,848.35 2.52 779.41 MWD+IFR-AK-CAZ-SC(2) 2,554.60 60.50 211.91 2,194.28 2,138.58 -767.05 -435.37 5,956,784.25 377,805.25 1.79 858.36 MWD+IFR-AK-CAZ-SC(2) 2,649.85 61.88 215.06 2,240.19 2,184.49 -836.64 -481.42 5,956,715.43 377,758.08 3.24 938.07 MWD+IFR-AK-CAZ-SC(2) 2,742.86 63.23 219.26 2,283.07 2,227.37 -902.38 -531.28 5,956,650.50 377,707.17 4.26 1,015.16 MWD+IFR-AK-CAZ-SC(2) 2,837.37 63.96 224.05 2,325.12 2,269.42 -965.60 -587.52 5,956,588.21 377,649.91 4.60 1,091.61 MWD+IFR-AK-CAZ-SC(2) 2,869.84 64.39 225.42 2,339.26 2,283.56 -986.36 -608.09 5,956,567.79 377,629.01 4.02 1,117.30 MWD+IFR-AK-CAZ-SC(2) 2,939.12 64.76 229.43 2,369.02 2,313.32 -1,028.68 -654.16 5,956,526.22 377,582.27 5.25 1,170.84 INC+TREND(3) 133/8"x16" 2,965.61 64.93 230.95 2,380.28 2,324.58 -1,044.03 -672.58 5,956,511.17 377,563.61 5.25 1,190.74 INC+TREND(3) 3,020.73 65.46 228.71 2,403.40 2,347.70 -1,076.30 -710.80 5,956,479.53 377,524.87 3.81 1,232.44 INC+TREND(3) 3,114.99 66.20 228.12 2,442.00 2,386.30 -1,133.38 -775.13 5,956,423.50 377,459.64 0.97 1,305.26 MWD+IFR-AK-CAZ-SC(4) 3,209.60 66.52 229.05 2,479.94 2,424.24 -1,190.71 -840.12 5,956,367.23 377,393.72 0.96 1,378.52 MWD+IFR-AK-CAZ-SC(4) 3,303.50 66.16 228.43 2,517.62 2,461.92 -1,247.43 -904.78 5,956,311.58 377,328.17 0.72 1,451.09 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:00:48PM Page 3 COMPASS 5000 1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8©55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) • Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 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 3,397.99 64.30 228.94 2,557.21 2,501.51 -1,304.08 -969 21 5,956,255.99 377,282.83 2.03 1,523.53 MWD+IFR-AK-CAZ-SC(4) 3,491.63 64.66 228.61 2,597.55 2,541.85 -1,359.76 -1,032.77 5,956,201.34 377,198.38 0.50 1,594.81 MWD+IFR-AK-CAZ-SC(4) 3,586.27 64.39 228.48 2,638.26 2,582.56 -1,416.33 -1,096.80 5,956,145,83 377,133.44 0.31 1,667.06 MWD+IFR-AK-CAZ-SC(4) 3,680.38 64.59 228.30 2,678.79 2,623.09 -1,472.73 -1,160.31 5,956,090.47 377,069.04 0.27 1,739.01 MWD+IFR-AK-CAZ-SC(4) 3,774.89 64.50 228.51 2,719.41 2,663.71 -1,529.38 -1,224.13 5,956,034.86 377,004.32 0.22 1,811.28 MWD+IFR-AK-CAZ-SC(4) 3,869.26 64.53 227.91 2,760.01 2,704.31 -1,586.15 -1,287.64 5,955,979,13 376,939.90 0.57 1,883.58 MWD+IFR-AK-CAZ-SC(4) 3,963.72 64.41 227.14 2,800.72 2,745.02 -1,643.71 -1,350.51 5,955,922.61 376,876.11 0.75 1,956.46 MWD+IFR-AK-CAZ-SC(4) 4,061.51 64.30 226.49 2,843.05 2,787.35 -1,704.04 -1,414.79 5,955,863.33 376,810.87 0.61 2,032.39 MWD+IFR-AK-CAZ-SC(4) 4,159.70 64.61 226.66 2,885.39 2,829.69 -1,764.93 -1,479.13 5,955,803.49 376,745.55 0.35 2,108.89 MWD+IFR-AK-CAZ-SC(4) 4,254.11 64.15 226.96 2,926.21 2,870.51 -1,823.20 -1,541.20 5,955,746.24 376,682.56 0.57 2,182.22 MWD+IFR-AK-CAZ-SC(4) 4,347.74 63.04 226.53 2,967.85 2,912.15 -1,880.66 -1,602.27 5,955,689.78 376,620.56 1.25 2,254.50 MWD+IFR-AK-CAZ-SC(4) 4,442.50 61.89 225.90 3,011.66 2,955.96 -1,938.80 -1,662.94 5,955,632.63 376,558.97 1.35 2,327.32 MWD+IFR-AK-CAZ-SC(4) 4,536.09 60.62 225.68 3,056.66 3,000.96 -1,996.02 -1,721.75 5,955,576.38 376,499.24 1.37 2,398.73 MWD+IFR-AK-CAZ-SC(4) 4,632.01 59.12 225.96 3,104.81 3,049.11 -2,053.83 -1,781.24 5,955.519.54 376,438.83 1.58 2,470.91 MWD+IFR-AK-CAZ-SC(4) 4,727.18 59.45 225.96 3,153.42 3,097.72 -2,110.71 -1,840.06 5,955,463.63 376,379.10 0.35 2,542.00 MWD+IFR-AK-CAZ-SC(4) 4,821.01 59.37 225.92 3,201.17 3,145.47 -2,166.88 -1,898.10 5,955,408.41 376,320.16 0.09 2,612.19 MWD+IFR-AK-CAZ-SC(4) 4,915.29 59.38 227.17 3,249.20 3,193.50 -2,222.68 -1,957.00 5,955,353.58 376,260.38 1.14 2,682.26 MWD+IFR-AK-CAZ-SC(4) 5,010.08 60.25 227.14 3,296.86 3,241.16 -2,278.40 -2,017.07 5,955,298.85 376,199.41 0.92 2,752.59 MWD+IFR-AK-CAZ-SC(4) 5,109.39 61.83 227.50 3,344.94 3,289.24 -2,337.30 -2,080.95 5,955,240.99 376,134.60 1.62 2,827.04 MWD+IFR-AK-CAZ-SC(4) 5,203.58 64.83 227.59 3,387.21 3,331.51 -2,394.10 -2,143.04 5,955,185.20 376,071.60 3.19 2,898.98 MWD+IFR-AK-CAZ-SC(4) 5,299.56 64.66 226.40 3,428.17 3,372.47 -2,453.31 -2,206.52 5,955,127.04 376,007.17 1.14 2,973.61 MWD+IFR-AK-CAZ-SC(4) 1 5,392.87 63.31 226.51 3,469.09 3,413.39 -2,511.08 -2,267.30 5,955,070.27 375,945.47 1.45 3,046.11 MWD+IFR-AK-CAZ-SC(4) 5,486.09 63.57 226.24 3,510.77 3,455.07 -2,568.61 -2,327.66 5,955,013.73 375,884.19 0.38 3,118.25 MWD+IFR-AK-CAZ-SC(4) 5,580.38 63.54 225.13 3,552.76 3,497.06 -2,627.58 -2,388.06 5,954,955.74 375,822.84 1.05 3,191.80 MWD+IFR-AK-CAZ-SC(4) 1 5,674.61 62.82 226.05 3,595.28 3,539.58 -2,686.43 -2,448.13 5,954,897.88 375,761.84 1.16 3,265.13 MWD+IFR-AK-CAZ-SC(4) 5,769.13 62.64 226.64 3,638.59 3,582.89 -2,744.43 -2,508.92 5,954,840.88 375,700.12 0.59 3,337.85 MWD+IFR-AK-CAZ-SC(4) 5,863.51 62.69 226.90 3,681.93 3,626.23 -2,801.85 -2,570.01 5,954,784.46 375,638.12 0.25 3,410.10 MWD+IFR-AK-CAZ-SC(4) 5,958.90 62.77 226.20 3,725.63 3,669.93 -2,860.16 -2,631.56 5,954,727.15 375,575.64 0.66 3,483.33 MWD+IFR-AK-CAZ-SC(4) 6,053.79 62.47 226.20 3,769.27 3,713.57 -2,918.48 -2,692.38 5,954,669.83 375,513.89 0.32 3,556.36 MWD+IFR-AK-CAZ-SC(4) 6,146.64 62.60 227.14 3,812.10 3,756.40 -2,975.01 -2,752.30 5,954,614.28 375,453.06 0.91 3,627.43 MWD+IFR-AK-CAZ-SC(4) 6,240.58 62.50 227.55 3,855.40 3,799.70 -3,031.50 -2813.61 5,954,558.80 375,390.85 0.40 3,698.84 MWD+IFR-AK-CAZ-SC(4) 6,336.26 62.65 228.39 3,899.47 3,843.77 -3,088.36 -2,876.69 5,954,502.98 375,326.86 0.79 3,771.11 MWD+IFR-AK-CAZ-SC(4) 6,430.58 62.80 227.96 3,942.69 3,886.99 -3,144.26 -2,939.17 5,954,448.10 375,263.49 0.44 3,842.29 MWD+IFR-AK-CAZ-SC(4) 6,523.57 62.58 228.74 3,985.36 3,929.66 -3,199.18 -3,000.90 5,954,394.20 375,200.88 0.78 3,912.31 MWD+IFR-AK-CAZ-SC(4) 6,617.74 62.04 229.16 4,029.12 3,973.42 -3,253.94 -3,063.79 5,954,340.47 375,137.12 0.70 3,982.50 MWD+IFR-AK-CAZ-SC(4) 6,712.46 63.21 228.93 4,072.67 4,016.97 -3,309.07 -3,127.31 5,954,286.37 375,072.72 1.25 4,053.24 MWD+IFR-AK-CAZ-SC(4) 6,807.18 64.99 230.03 4,114.04 4,058.34 -3,364.42 -3,192.08 5,954,232.08 375,007.07 2.15 4,124.53 MWD+IFR-AK-CAZ-SC(4) 6,901.57 66.76 229.83 4,152.62 4,096.92 -3,419.87 -3,258.00 5,954,177.71 374,940.26 1.89 4,196.24 MWD+IFR-AK-CAZ-SC(4) 6,995.55 66.41 230.49 4,189.97 4,134.27 -3,475.12 -3,324.22 5,954,123.54 374,873.17 0.74 4,267.85 MWD+IFR-AK-CAZ-SC(4) 7,090.90 64.90 230.38 4,229.27 4,173.57 -3,530.45 -3,391.19 5,954,069,31 374,805.32 1.59 4,339.74 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:00:48PM Page 4 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 7,185.57 66.20 230.38 4,268.46 4,212.76 -3,585.41 -3,457.57 5,954,015.44 374,738.06 1.37 4,411.10 MWD+IFR-AK-CAZ-SC(4) 7,279.26 66.23 230.13 4,306.24 4,250.54 -3,640.22 -3,523.49 5,953,961.71 374,671.27 0.25 4,482.20 MWD+IFR-AK-CAZ-SC(4) 7,372.88 66.19 230.38 4,344.01 4,288.31 -3,695.00 -3,589.36 5,953,908.01 374,604.53 0.25 4,553.24 MWD+IFR-AK-CAZ-SC(4) 7,468.22 66.20 229.97 4,382.49 4,326.79 -3,750.86 -3,656.35 5,953,853.24 374,536.64 0.39 4,625.65 MWD+IFR-AK-CAZ-SC(4) 7,561.95 66.09 229.06 4,420.40 4,364.70 -3,806.52 -3,721.55 5,953,798.66 374,470.56 0.90 4,697.36 MWD+IFR-AK-CAZ-SC(4) 7,656.89 66.15 227.79 4,458.83 4,403.13 -3,864.12 -3,786.49 5,953,742.11 374,404.70 1.22 4,770.86 MWD+IFR-AK-CAZ-SC(4) 7,749.14 65.59 227.45 4,496.54 4,440.84 -3,920.87 -3,848.68 5,953,686.39 374,341.60 0.69 4,842.77 MWD+IFR-AK-CAZ-SC(4) 7,844.14 64.30 227.03 4,536.78 4,481.08 -3,979.30 -3,911.86 5,953,629.00 374,277.48 1.42 4,916.57 MWD+IFR-AK-CAZ-SC(4) 7,938.86 64.08 227.23 4,578.02 4,522.32 -4,037.31 -3,974.36 5,953,572.01 374,214.06 0.30 4,989.78 MWD+IFR-AK-CAZ-SC(4) 8,032.81 64.14 226.83 4,619.04 4,563.34 -4,094.92 -4,036.20 5,953,515.41 374,151.30 0.39 5,062.42 MWD+IFR-AK-CAZ-SC(4) 8,125.50 64.11 227.04 4,659.49 4,603.79 -4,151.87 -4,097.13 5,953,459.46 374,089.46 0.21 5,134.17 MWD+IFR-AK-CAZ-SC(4) 8,222.02 63.80 227.20 4,701.87 4,646.17 -4,210.87 -4,160.68 5,953,401.50 374,024.97 0.35 5,208.63 MWD+IFR-AK-CAZ-SC(4) 8,313.92 63.12 227.26 4,742.93 4,687.23 -4,266.70 -4,221.03 5,953,346.66 373,963.73 0.74 5,279.14 MWD+IFR-AK-CAZ-SC(4) 8,411.28 62.18 227.06 4,787.66 4,731.96 -4,325.50 -4,284.44 5,953,288.90 373,899.38 0.98 5,353.36 MWD+IFR-AK-CAZ-SC(4) 8,503.41 62.08 227.39 4,830.73 4,775.03 -4,380.81 -4,344.22 5,953,234.57 373,838.72 0.33 5,423.22 MWD+IFR-AK-CAZ-SC(4) 8,600.42 62.67 227.20 4,875.71 4,820.01 -4,439.11 -4,407.38 5,953,177.31 373,774.62 0.63 5,496.88 MWD+IFR-AK-CAZ-SC(4) 8,691.17 64.04 227.41 4,916.41 4,860.71 -4,494.11 -4,467.00 5,953,123.29 373,714.13 1.52 5,566.39 MWD+IFR-AK-CAZ-SC(4) 8,790.02 63.59 227.25 4,960.03 4,904.33 -4,554.23 -4,532.22 5,953,064.23 373,647.95 0.48 5,642.39 MWD+IFR-AK-CAZ-SC(4) 8,882.67 62.03 227.12 5,002.36 4,946.66 -4,610.24 -4,592.67 5,953,009.22 373,586.60 1.69 5,713.10 MWD+IFR-AK-CAZ-SC(4) 8,976.21 62.04 227.42 5,046.22 4,990.52 -4,666.30 -4,653.36 5,952,954.15 373,525.02 0.28 5,783.93 MWD+IFR-AK-CAZ-SC(4) 9,071.00 61.95 227.15 5,090.73 5,035.03 -4,723.07 -4,714.85 5,952,898.39 373,462.63 0.27 5,855.67 MWD+IFR-AK-CAZ-SC(4) 9,165.30 62.79 227.13 5,134.47 5,078.77 -4,779.90 -4,776.09 5,952,842.56 373,400.48 0.89 5,927.39 MWD+IFR-AK-CAZ-SC(4) 9,258.78 62.00 227.07 5,177.78 5,122.08 -4,836.28 -4,836.77 5,952,787.17 373,338.90 0.85 5,998.53 MWD+IFR-AK-CAZ-SC(4) 9,353,22 62.03 227.12 5,222.10 5,166.40 -4,893.06 -4,897.86 5,952,731.39 373,276.90 0.06 6,070.16 MWD+IFR-AK-CAZ-SC(4) 9,447.52 62.02 227,58 5,266.33 5,210.63 -4,949.48 -4,959.11 5,952,675.97 373,214.75 0.43 6,141.50 MWD+IFR-AK-CAZ-SC(4) 9,541.95 62.38 227.04 5,310.37 5,254.67 -5,006.12 -5,020.51 5,952,620.34 373,152.45 0.63 6,213.08 MWD+IFR-AK-CAZ-SC(4) 9,636.02 62.29 227.14 5,354.05 5,298.35 -5,062.85 -5,081.53 5,952,564.62 373,090.52 0.13 6,284.64 MWD+IFR-AK-CAZ-SC(4) 9,730.64 62.31 227.38 5,398.03 5,342.33 -5,119.70 -5,143.06 5,952,508.77 373,028.08 0.23 6,356.47 MWD+IFR-AK-CAZ-SC(4) 9,825.32 62.82 227.30 5,441.66 5,385.96 -5,176.65 -5,204.86 5,952,452.84 372,965.38 0.54 6,428.45 MWD+IFR-AK-CAZ-SC(4) 9,919.47 63.85 227.56 5,483.91 5,428.21 -5,233.56 -5,266.82 5,952,396.94 372,902.51 1.12 6,500.46 MWD+IFR-AK-CAZ-SC(4) 10,013.65 63.81 227.33 5,525.44 5,469.74 -5,290.73 -5,329.08 5,952,340.80 372,839.33 0.22 6,572.79 MWD+IFR-AK-CAZ-SC(4) 10,109.47 63.92 226.77 5,567.65 5,511.95 -5,349.34 -5,392.05 5,952,283.22 372,775.43 0.54 6,646.71 MWD+IFR-AK-CAZ-SC(4) 10,202.84 63.88 226.62 5,608.73 5,553.03 -5,406.85 -5,453.06 5,952,226.71 372,713.49 0.15 6,719.02 MWD+IFR-AK-CAZ-SC(4) 10,298.09 63.81 227.01 5,650.72 5,595.02 -5,465.36 -5,515.40 5,952,169.22 372,650.22 0.37 6,792.67 MWD+IFR-AK-CAZ-SC(4) 10,390.13 63.74 227.21 5,691.39 5,635.69 -5,521.55 -5,575.90 5,952,114.02 372,588.83 0.21 6,863.57 MWD+IFR-AK-CAZ-SC(4) 10,483.60 63.96 227.44 5,732.58 5,676.88 -5,578.43 -5,637.58 5,952,058.15 372,526.24 0.32 6,935.46 MWD+IFR-AK-CAZ-SC(4) 10,579.65 63.75 228.62 5,774.91 5,719.21 -5,636.09 -5,701.69 5,952,001.55 372,461.21 1.12 7,008.78 MWD+IFR-AK-CAZ-SC(4) 10,675.73 62.80 229.21 5,818.11 5,762.41 -5,692.48 -5,766.37 5,951,946.21 372,395.63 1.13 7,081.05 MWD+IFR-AK-CAZ-SC(4) 10,768.32 63.34 230.34 5,860.05 5,804.35 -5,745.79 -5,829.39 5,951,893.93 372,331.76 1.23 7,149.89 MWD+IFR-AK-CAZ-SC(4) 10,862.66 63.66 231.38 5,902.15 5,846.45 -5,799.08 -5,894.88 5,951,841.71 372,265.43 1.04 7,219.40 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1 00::48PM Page 5 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8©55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8©55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 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) 0100') (ft) Survey Tool Name 10,957.11 64.49 231.37 5,943.44 5,887.74 -5,852.10 -5,961.24 5,951,789.78 372,198.22 0.88 7,288.91 MWD+IFR-AK-CAZ-SC(4) 11,051.39 66.41 231.89 5,982.61 5,926.91 -5,905.33 -6,028.47 5,951,737.65 372,130.14 2.10 7,358.86 MWD+IFR-AK-CAZ-SC(4) 11,145.65 67.42 232.61 6,019.57 5,963.87 -5,958.42 -6,097.03 5,951,685.69 372,060.73 1.28 7,429.04 MWD+IFR-AK-CAZ-SC(4) 11,240.19 66.98 231.89 6,056.20 6,000.50 -6,011.77 -6,165.94 5,951,633.46 371,990.97 0.84 7,499.57 MWD+IFR-AK-CAZ-SC(4) 11,334.03 66.53 231.07 6,093.24 6,037.54 -6,065.47 -6,233.40 5,951,580.87 371,922.66 0.94 7,570.03 MWD+IFR-AK-CAZ-SC(4) 11,428.50 66.27 229.72 6,131.06 6,075.36 -6,120.65 -6,300.10 5,951,526.77 371,855.08 1.34 7,641.70 MWD+IFR-AK-CAZ-SC(4) 11,522.09 67.92 229.41 6,167.49 6,111.79 -6,176.57 -6,365.72 5,951,471.93 371,788.57 1.79 7,713.77 MWD+IFR-AK-CAZ-SC(4) 11,618.23 68.21 228.84 6,203.40 6,147.70 -6,234.93 -6,433.15 5,951,414.68 371,720.21 0.63 7,788.70 MWD+IFR-AK-CAZ-SC(4) 11,709.22 66.54 228.38 6,238.40 6,182.70 -6,290.45 -6,496.16 5,951,360.18 371,656.32 1.89 7,859.67 MWD+IFR-AK-CAZ-SC(4) i 11,806.82 64.65 227.67 6,278.73 6,223.03 -6,349.89 -6,562.23 5,951,301.83 371,589.29 2.05 7,935.25 MWD+IFR-AK-CAZ-SC(4) 11,902.08 64.98 226.79 6,319.27 6,263.57 -6,408.43 -6,625.51 5,951,244.33 371,525.08 0.90 8,009.18 MWD+IFR-AK-CAZ-SC(4) 11,995.01 64.86 225.87 6,358.66 6,302.96 -6,466.55 -6,686.39 5,951,187.21 371,463.27 0.91 8,082.04 MWD+IFR-AK-CAZ-SC(4) 12,089.38 64.07 225.87 6,399.34 6,343.64 -6,525.84 -6,747.51 5,951,128.92 371,401.20 0.84 8,156.09 MWD+1FR-AK-CAZ-SC(4) 12,183.80 62.22 225.46 6,441.99 6,386.29 -6,584.70 -6,807.76 5,951,071.05 371,3.40.01 2.00 8,229.49 MWD+IFR-AK-CAZ-SC(4) 12,278.58 62.36 224.48 6,486.06 6,430.36 -6,644.06 -6,867.06 5,951,012.66 371,279.76 0.93 8,303.10 MWD+IFR-AK-CAZ-SC(4) 12,372.96 63.01 224.46 6,529.37 6,473.67 -6,703.91 -6,925.81 5,950,953.78 371,220.06 0.69 8,377.01 MWD+IFR-AK-CAZ-SC(4) 12,466.15 63.04 224.54 6,571.64 6,515.94 -6,763.14 -6,984.02 5,950,895.50 371,160.90 0.08 8,450.19 MWD+IFR-AK-CAZ-SC(4) 12,560.81 62.61 224.86 6,614.87 6,559.17 -6,823.00 -7,043.25 5,950,836.61 371,100.71 0.54 8,524.26 MWD+IFR-AK-CAZ-SC(4) 12,655.36 61.95 225.25 6,658.85 6,603.15 -6,882.13 -7,102.49 5,950,778.46 371,040.53 0.79 8,597.63 MWD+IFR-AK-CAZ-SC(4) 12,750.08 62.27 226.26 6,703.16 6,647.46 -6,940.54 -7,162.46 5,950,721.03 370,979.63 1.00 8,670.51 MWD+IFR-AK-CAZ-SC(4) 12,843.46 63.21 226.42 6,745.93 6,690.23 -6,997.84 -7,222.51 5,950,664.71 370,918.66 1.02 8,742.36 MWD+IFR-AK-CAZ-SC(4) 12,938.76 64.15 226.31 6,788.19 6,732.49 -7,056.79 -7,284.34 5,950,606.78 370,855.89 0.99 8,816.27 MWD+IFR-AK-CAZ-SC(4) 12,938.81 64.15 226.31 6,788.21 6,732.51 -7,056.82 -7,284.37 5,950,606.75 370,855.86 0.00 8,816.31 GYD-GC-MS(5) 9-5/8"x 12-114" 12,950.00 63.54 226.00 6,793.14 6,737.44 -7,063.78 -7,291.61 5,950,599.91 370,848.51 5.99 8,825.02 GYD-GC-MS(5) 12,975.00 64.18 224.82 6,804.15 6,748.45 -7,079.53 -7,307.60 5,950,584.41 370,832.27 4.95 8,844.63 GYD-GC-MS(5) 13,000.00 63.89 225.34 6,815.10 6,759.40 -7,095.40 -7,323.51 5,950,568.80 370,816.10 2.20 8,864.32 GYD-GC-MS(5) 13,025.00 64.17 225.27 8,826.05 6,770.35 -7,111.21 -7,339.49 5,950,553.26 370,799.87 1.15 8,883.98 GYD-GC-MS(5) 13,050.00 64.25 225.40 6,836.92 6,781.22 -7,127.03 -7,355.50 5,950,537.70 370,783.61 0.57 8,903.65 GYD-GC-MS(5) 13,075.00 64.20 225.59 6,847.80 6,792.10 -7,142.82 -7,371.55 5,950,522.18 370,767.30 0.71 8,923.30 GYD-GC-MS(5) 13,100.00 64.13 225.38 6,858.69 6,802.99 -7,158.59 -7,387.60 5,950,506.67 370,751.01 0.81 8,942.95 GYD-GC-MS(5) 13,125.00 64.65 224.61 6,869.50 6,813.80 -7,174.53 -7,403.54 5,950,490.99 370,734.81 3.47 8,962.72 GYD-GC-MS(5) i 13,150.00 65.19 223.99 6,880.09 6,824.39 -7,190.74 -7,419.35 5,950,475.04 370,718.74 3.12 8,982.71 GYD-GC-MS(5) 13,175.00 65.92 223.54 6,890.44 6,834.74 -7,207.18 -7,435.09 5,950,458.86 370,702.74 3.35 9,002.90 GYD-GC-MS(5) 13,200.00 66.20 222.89 6,900.58 6,844.88 -7,223.83 -7,450.74 5,950,442.47 370,686.82 2.63 9,023.27 GYD-GC-MS(5) 13,225.00 66.64 222.23 6,910.58 6,854.88 -7,240.70 -7,466.24 5,950,425.85 370,671.06 2.99 9,043.82 GYD-GC-MS(5) 13,250.00 66.97 221.37 6,920.43 6,864.73 -7,257.83 -7,481.55 5,950,408.97 370,655.47 3.43 9,064.55 GYD-GC-MS(5) 13,275.00 67.36 220.53 6,930.13 6,874.43 -7,275.24 -7,496.65 5,950,391.81 370,640.09 3.47 9,085.49 GYD-GC-MS(5) 13,300.00 67.39 219.68 8,939.75 6,884.05 -7,292.89 -7,511.52 5,950,374.41 370,624.94 3.14 9,106.60 GYD-GC-MS(5) 13,325.00 67.44 218.72 6,949.35 6,893.65 -7,310.77 -7,526.11 5,950,356.76 370,610.06 3.55 9,127.86 GYD-GC-MS(5) 9/8/2014 1:00:48PM Page 6 COMPASS 5000 1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N1-8 +E/-W Northing Easting DLS Section (usft) (") (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,350.00 67.54 217.54 6,958.92 6,903.22 -7,328.94 -7,540.37 5,950,338.83 370,595.51 4.38 9,149.30 GYD-GC-MS(5) 13,375.00 67.25 216.41 6,968.53 6,912.83 -7,347.38 -7,554.25 5,950,320.62 370,581.34 4.33 9,170.89 GYD-GC-MS(5) 13,400.00 66.96 215.39 6,978.26 6,922.56 -7,366.03 -7,567.75 5,950,302.19 370,567.53 3.93 9,192.58 GYD-GC-MS(5) 13,465.21 67.53 212.48 7,003.49 6,947.79 -7,415.92 -7,601.31 5,950,252.86 370,533.17 4.21 9,249.88 MWD+IFR-AK-CAZ-SC(6) 13,560.91 68.34 210.30 7,039.44 6,983.74 -7,491.63 -7,647.50 5,950,177.91 370,485.77 2.27 9,335.50 MWD+IFR-AK-CAZ-SC(6) 13,654.68 69.01 203.92 7,073.57 7,017.87 -7,569.33 -7,687.27 5,950,100.87 370,444.75 6.38 9,421.24 MWD+1FR-AK-CAZ-SC(6) ', 13,700.47 68.91 199.71 7,090.02 7,034.32 -7,609.00 -7,703.15 5,950,061.47 370,428.23 8.58 9,463.77 MWD+IFR-AK-CAZ-SC(6) 13,748.25 69.13 196.13 7,107.13 7,051.43 -7,651.44 -7,716.87 5,950,019.26 370,413.82 7.01 9,508.35 MWD+IFR-AK-CAZ-SC(6) 13,798.47 69.79 194.58 7,124.75 7,069.05 -7,696.79 -7,729.32 5,949,974.12 370,400.64 3.17 9,555.37 MWD+IFR-AK-CAZ-SC(6) 13,843.43 69.77 191.80 7,140.29 7,084.59 -7,737.86 -7,738.95 5,949,933.22 370,390.35 5.80 9,597.49 MWD+IFR-AK-CAZ-SC(6) 13,892.22 70.19 189.78 7,157.00 7,101.30 -7,782.88 -7,747.53 5,949,888.34 370,381.04 3.98 9,643.12 MWD+IFR-AK-CAZ-SC(6) 13,937.58 71.10 188.49 7,172.03 7,116.33 -7,825.14 -7,754.32 5,949,846.20 370,373.57 3.35 9,685.58 MWD+IFR-AK-CAZ-SC(6) 13,986.39 71.07 186.42 7,187.85 7,132.15 -7,870.92 -7,760.31 5,949,800.53 370,366.84 4.01 9,731.21 MWD+IFR-AK-CAZ-SC(6) 14,032.29 70.92 185.22 7,202.80 7,147.10 -7,914.09 -7,764.71 5,949,757.44 370,361.74 2.49 9,773.88 MWD+IFR-AK-CAZ-SC(6) 14,126.12 71.40 181.77 7,233.11 7,177.41 -8,002.71 -7,770.12 5,949,668.92 370,354.90 3.52 9,860.47 MWD+IFR-AK-CAZ-SC(6) 14,220.43 71.92 178.71 7,262.79 7,207.09 -8,092.22 -7,770.49 5,949,579.44 370,353.07 3.13 9,946.48 MWD+IFR-AK-CAZ-SC(6) 14,315.67 72.54 176.02 7,291.86 7,236.16 -8,182.81 -7,766.32 5,949,488.80 370,355.78 2.77 10,032.27 MWD+IFR-AK-CAZ-SC(6) 14,409.52 74.45 174.84 7,318.53 7,262.83 -8,272.50 -7,759.15 5,949,399.02 370,361.50 2.37 10,116.35 MWD+IFR-AK-CAZ-SC(6) 14,503.54 77.35 176.58 7,341.43 7,285.73 -8,363.42 -7,752.33 5,949,308.01 370,366.84 3.57 10,201.71 MWD+IFR-AK-CAZ-SC(6) 14,598.40 76.68 175.26 7,362.75 7,307.05 -8,455.62 -7,745.76 5,949,215.72 370,371.92 1.53 10,288.37 MWD+IFR-AK-CAZ-SC(6) 14,693.07 75.36 171.48 7,385.62 7,329.92 -8,546.85 -7,735.16 5,949,124.34 370,381.03 4.12 10,372.97 MWD+IFR-AK-CAZ-SC(6) 14,787.08 75.52 167.79 7,409.26 7,353.56 -8,636.34 -7,718.80 5,949,034.60 370,395.95 3.80 10,454.28 MWD+IFR-AK-CAZ-SC(6) 14,881.67 75.70 165.45 7,432.78 7,377.08 -8,725.46 -7,697.59 5,948,945.15 370,415.70 2.40 10,533.88 MWD+IFR-AK-CAZ-SC(6) 14,975.07 77.57 165.52 7,454.36 7,398.66 -8,813.43 -7,674.82 5,948,856.84 370,437.05 2.00 10,611.93 MWD+IFR-AK-CAZ-SC(6) 15,069.85 79.46 163.22 7,473.24 7,417.54 -8,902.87 -7,649.79 5,948,767.01 370,460.62 3.10 10,690.76 MWD+IFR-AK-CAZ-SC(6) 15,165.32 82.07 162.01 7,488.56 7,432.86 -8,992.78 -7,621.64 5,948,676.66 370,487.32 3.01 10,769.18 MWD+IFR-AK-CAZ-SC(6) 15,220.00 83.69 160.33 7,495.33 7,439.63 -9,044.13 -7,604.12 5,948,625.04 370,503.99 4.25 10,813.56 MWD+IFR-AK-CAZ-SC(6) 7"x 8-3/4"x 9-7/8" 15,253.21 84.68 159.32 7,498.70 7,443.00 -9,075.15 -7,592.73 5,948,593.85 370,514.88 4.25 10,840.13 MWD+IFR-AK-CAZ-SC(6) 15,346.63 88.84 158.23 7,503.98 7,448.28 -9,162.07 -7,558.97 5,948,506.40 370,547.23 4.60 10,914.10 MWD+IFR-AK-CAZ-SC(6) 15,443.97 90.93 157.28 7,504.17 7,448.47 -9,252.16 -7,522.12 5,948,415.73 370,582.61 2.36 10,990.24 MWD+IFR-AK-CAZ-SC(6) 15,535.50 91.85 156.00 7,501.95 7,446.25 -9,336.16 -7,485.84 5,948,331.16 370,617.52 1.72 11,060.70 MWD+IFR-AK-CAZ-SC(6) 15,629.09 90.93 154.19 7,499.68 7,443.98 -9,421.01 -7,446.44 5,948,245.68 370,655.54 2.17 11,131.10 MWD+IFR-AK-CAZ-SC(6) 15,722.40 87.91 151.97 7,500.63 7,444.93 -9,504.19 -7,404.21 5,948,161.84 370,696.41 4.02 11,199.10 MWD+IFR-AK-CAZ-SC(6) 15,818.35 87.95 150.39 7,504.09 7,448.39 -9,588.20 -7,357.99 5,948,077.10 370,741.27 1.65 11,266.78 MWD+IFR-AK-CAZ-SC(6) 15,913.45 89.01 154.49 7,506.62 7,450.92 -9,672.46 -7,314.01 5,947,992.14 370,783.87 4.45 11,335.33 MWD+IFR-AK-CAZ-SC(6) 16,007.04 89.04 158.54 7,508.21 7,452.51 -9,758.27 -7,276.73 5,947,905.75 370,819.75 4.33 11,407.24 MWD+IFR-AK-CAZ-SC(6) 16,102.56 89.04 157.36 7,509.81 7,454.11 -9,846.79 -7,240.87 5,947,816.67 370,854.17 1.24 11,482.15 MWD+IFR-AK-CAZ-SC(6) 16,196.54 89.21 161.09 7,511.25 7,455.55 -9,934.63 -7,207.55 5,947,728.31 370,886.06 3.97 11,557.13 MWD+IFR-AK-CAZ-SC(6) 16,291.51 89.87 166.58 7,512.01 7,456.31 -10,025.81 -7,181.12 5,947,636.72 370,911.01 5.82 11,637.23 MWD+IFR-AK-CAZ-SC(6) 9/8/2014 1:00.48PM Page 7 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) 0100) (ft) Survey Tool Name 16,340.66 90.07 165.02 7,512.03 7,456.33 -10,073.46 -7,169.06 5,947,588.89 370,922.29 3.20 11,679.59 MWD+IFR-AK-CAZ-SC(6) 16,386.38 89.97 165.08 7,512.02 7,456.32 -10,117,63 -7,157.27 5,947,544.54 370,933.37 0.26 11,718.68 MWD+IFR-AK-CAZ-SC(6) 16,481,48 89.35 164.73 7,512.58 7,456.88 -10,209.45 -7,132.50 5,947,452.34 370,956.64 0.75 11,799.87 MWD+IFR-AK-CAZ-SC(6) 16,574.62 89.56 167.57 7,513.47 7,457.77 -10,299.86 -7,110.21 5,947,361.58 370,977.46 3.06 11,880.41 MWD+IFR-AK-CAZ-SC(6) 16,669.94 89.11 171.80 7,514.58 7,458.88 -10,393.62 -7,093.15 5,947,267.57 370,993.00 4.46 11,965.62 MWD+IFR-AK-CAZ-SC(6) 16,762.10 89.18 171.60 7,515.95 7,460.25 -10,484.80 -7,079.85 5,947,176.19 371,004.83 0.23 12,049.41 MWD+IFR-AK-CAZ-SC(6) 16,857.81 89.21 175.28 7,517.30 7,461.60 -10,579.86 -7,068.92 5,947,080.97 371,014.22 3.84 12,137.59 MWD+IFR-AK-CAZ-SC(6) 16,951.97 89.42 177.21 7,518.42 7,462.72 -10,673.80 -7,062.75 5,946,986.95 371,018.86 2.06 12,226.04 MWD+IFR-AK-CAZ-SC(6) 17,047.65 89.11 177.80 7,519.65 7,463.95 -10,769.39 -7,058.58 5,946,891.32 371,021.48 0.70 12,316.62 MWD+IFR-AK-CAZ-SC(6) 17,143.93 88.94 177.76 7,521.29 7,465.59 -10,865.58 -7,054.86 5,946,795.09 371,023.65 0.18 12,407.91 MWD+IFR-AK-CAZ-SC(6) 17,236.54 88.87 177.34 7,523.06 7,467.36 -10,958.09 -7,050.90 5,946,702.53 371,026.10 0.46 12,495.59 MWD+IFR-AK-CAZ-SC(6) 17,331.29 88.29 171.92 7,525.41 7,469.71 -11,052.36 -7,042.04 5,946,608.14 371,033.44 5.75 12,583.60 MWD+IFR-AK-CAZ-SC(6) 17,384.06 88.60 170.67 7,526.84 7,471.14 -11,104.50 -7,034.05 5,946,555.88 371,040.57 2.44 12,631.41 MWD+IFR-AK-CAZ-SC(6) 17,425.03 87.84 170.25 7,528.11 7,472.41 -11,144.88 -7,027.27 5,946,515.40 371,046.71 2.12 12,668.27 MWD+IFR-AK-CAZ-SC(6) 17,520.53 87.88 169.04 7,531.68 7,475.98 -11,238.76 -7,010.11 5,946,421.26 371,062.34 1.27 12,753.57 MWD+IFR-AK-CAZ-SC(6) 17,615.23 88.29 167.62 7,534.84 7,479.14 -11,331.45 -6,990.97 5,946,328.28 371,079.97 1.56 12,837.17 MWD+IFR-AK-CAZ-SC(6) 17,710.36 88.70 165.60 7,537.34 7,481.64 -11,423.95 -6,968.95 5,946,235.44 371,100.49 2.17 12,919.79 MWD+IFR-AK-CAZ-SC(6) 17,805.59 90.38 163.45 7,538.11 7,482.41 -11,515.72 -6,943.54 5,946,143.28 371,124.41 2.87 13,000.75 MWD+IFR-AK-CAZ-SC(6) 17,899.60 90.62 163.49 7,537.29 7,481.59 -11,605.84 -6,916.79 5,946,052.75 371,149.69 0.26 13,079.76 MWD+IFR-AK-CAZ-SC(6) 17,995.02 90.31 163.37 7,536.51 7,480.81 -11,697.30 -6,889.58 5,945,960.87 371,175.41 0.35 13,159.91 MWD+IFR-AK-CAZ-SC(6) 18,089.34 90.00 163.26 7,536.26 7,480.56 -11,787.64 -6,862.50 5,945,870.10 371,201.02 0.35 13,239.04 MWD+IFR-AK-CAZ-SC(6) 18,183.54 88.94 163.34 7,537.13 7,481.43 -11,877.87 -6,835.44 5,945,779.46 371,226.63 1.13 13,318.05 MWD+IFR-AK-CAZ-SC(6) 18,278.42 89.04 163.72 7,538.80 7,483.10 -11,968.84 -6,808.54 5,945,688.07 371,252.04 0.41 13,397.83 MWD+IFR-AK-CAZ-SC(6) 18,370.51 88.67 165.63 7,540.64 7,484.94 -12,057.63 -6,784.21 5,945,598.91 371,274.93 2.11 13,476.24 MWD+IFR-AK-CAZ-SC(6) 18,466.12 88.46 166.42 7,543.04 7,487.34 -12,150.38 -6,761.12 5,945,505.80 371,296.51 0.85 13,558.80 MWD+IFR-AK-CAZ-SC(6) 18,558.52 89.15 165.46 7,544.96 7,489.26 -12,239.99 -6,738.68 5,945,415.85 371,317.49 1.28 13,638.52 MWD+IFR-AK-CAZ-SC(6) 18,655.04 89.21 163.26 7,546.34 7,490.64 -12,332.92 -6,712.67 5,945,322.51 371,342.00 2.28 13,720.43 MWD+IFR-AK-CAZ-SC(6) 18,748.80 88.94 160.95 7,547.86 7,492.16 -12,422.13 -6,683.86 5,945,232.86 371,369.35 2.48 13,797.98 MWD+IFR-AK-CAZ-SC(6) 18,842.94 89.56 159.24 7,549.09 7,493.39 -12,510.64 -6,651.81 5,945,143.86 371,399.96 1.93 13,873.95 MWD+IFR-AK-CAZ-SC(6) 18,938.53 89.63 157.55 7,549.77 7,494.07 -12,599,50 -6,616.62 5,945,054.44 371,433.71 1.77 13,949.38 MWD+IFR-AK-CAZ-SC(6) 19,033.04 89.56 155.91 7,550.43 7,494.73 -12,686.32 -6,579.28 5,944,967.03 371,469.63 1.74 14,022.25 MWD+IFR-AK-CAZ-SC(6) 19,127.59 89.59 153.15 7,551.14 7,495.44 -12,771.67 -6,538.63 5,944,881.04 371,508.89 2.92 14,092.77 MWD+IFR-AK-CAZ-SC(6) 19,221.99 90.04 151.01 7,551.44 7,495.74 -12,855.08 -6,494.43 5,944,796.94 371,551.73 2.32 14,160.44 MWD+IFR-AK-CAZ-SC(6) 19,314.38 89.93 149.73 7,551.46 7,495.76 -12,935.38 -6,448.75 5,944,715.91 371,596.10 1.39 14,224.72 MWD+IFR-AK-CAZ-SC(6) 19,391.69 90.52 149.52 7,551.16 7,495.46 -13,002.08 -6,409.66 5,944,648.59 371,634.10 0.81 14,277.78 MWD+IFR-AK-CAZ-SC(6) 19,458.89 89.56 149.22 7,551.11 7,495.41 -13,059.90 -6,375.42 5,944,590.23 371,667.40 1.50 14,323.68 MWD+IFR-AK-CAZ-SC(6) 19,504.04 90.17 148.64 7,551.22 7,495.52 -13,098.58 -6,352.12 5,944,551.19 371,690.06 1.86 14,354.26 MWD+IFR-AK-CAZ-SC(6) 19,597.81 89.11 148.22 7,551.81 7,496.11 -13,178.47 -6,303.03 5,944,470.52 371,737.85 1.22 14,417.18 MWD+IFR-AK-CAZ-SC(6) 19,691.36 89.62 149.30 7,552.85 7,497.15 -13,258.45 -6,254.52 5,944,389.77 371,785.06 1.28 14,480.35 MWD+IFR-AK-CAZ-SC(6) 19,786.40 89.97 151.07 7,553.19 7,497.49 -13,340.90 -6,207.27 5,944,306.57 371,830.97 1.90 14,546.25 MWD+IFR-AK-CAZ-SC(6) 9/8/2014 1:00:48PM Page 8 COMPASS 5000.1 Build 65 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope ND Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azl ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 19,882.04 89.25 152.39 7,553.84 7,498.14 -13,425.13 -6,161.97 5,944,221.63 371,874.89 1.57 14,614.40 MWD+IFR-AK-CAZ-SC(6) 19,979.01 87.29 152.58 7,556.76 7,501.06 -13,511.09 -6,117.20 5,944,134.96 371,918.26 2.03 14,684.35 MWD+IFR-AK-CAZ-SC(6) 20,050.00 87.29 152.58 7,560.12 7,504.42 -13,574.03 -6,084.54 5,944,071.50 371,949.89 0.00 14,735.61 PROJECTED to TD 9/8/2014 1:00.48PM Page 9 COMPASS 5000.1 Build 65 • .I.i :^ o a o CO O a z T = 0 0 N 0 ` O N in en 0ro a o rn C M O 00 g a o CO •2' v. ^O O w t E o p1 15 N s z Z �i o 63_ 0 .- D acs 0:' ,O _ M • O 0 C= . cu O ,:i C • d40 %ft • vi > t cY1 . E = w t . O y v O : V• CD >+ 0 w v C o O XI 0 W a CO C N O O 0) C �_ C Z E al o O +r • V1 w O a) C N co • 0 73 N O L C Q U C CO U0 'V 3 w o ❑ al o L ° m ' r LL• > w >= 2u) 00cn t. a aoa a w > ccQ > w 0 C CD N CU P2 0 a_ a) CC C 0 RECEIVED STATE OF ALASKA SEF 25 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT Nspgm la Well Status: Oil ❑ . Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ lb Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ . Exploratory ❑ GINJ Cl WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp,Susp., Z4kik 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. ` orAband.: August,25,2014 214-056/314-428 3.Address 6.Date Spudded 13.API Number P.O. Box 100360,Anchorage,AK 99510-0360 June 14,2014 51103-20673-01 4a.Location of Well(Governmental Section): 7 Date TD Reached: 14.Well Name and Number: Surface: 2863'FNL,4954'FEL,Sec. 19,T11 N, R5E, UM August 14,2014 CD4-96A - Top of Productive Horizon: 8.KB(ft above MSL): 55.6'RKB 15.Field/Pool(s): 1269'FNL,2344'FEL,Sec.35,T11 N, R4E, UM GL(ft above MSL): 18.9'AMSL Colville River Field Total Depth: 9 Plug Back Depth(MD+TVD). 5231'FNL, 1244'FEL,Sec.35,T11 N, R4E, UM 19244'MD/7555'TVD Alpine Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10 Total Depth(MD+TVD): 16.Property Designation: 384209,388077, Surface: x-378253 y- 5957544 Zone-4 19293'MD/7556'TVD ' ADL 386902,3842`11,387209,388905,390337 TPI: x-370478 y- 5948708 Zone-4 11.SSSV Depth(MD+ND) 17.Land Use Permit: Total Depth: x-371513 y- 5944729 Zone-4 2111'MD/1942'TVD Tobin 932351,932357,300618 18.Directional Survey: Yes Q . 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) 1525'MD/1500'ND 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 15132'MD/7484'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 37' 114' 37' 1 114' 42" 12 yds 13.375" 68# L-80 36' 2939' 36' 2369' 16" 1375 sx AS Lite,336 sx Class G 9.625" 40# L-80 1566' 13260' 1536' 6924' 12.25" 1230 sx Class G,220 sx Qannik blend 7" 26# L-80 34' 12776' 34' 6716' 9.625" tieback 7" 26&29# L-80/TN110 12765' 15220' 6710' 7499' 8 75 x 9 875 799 sx Class G ✓ 4.5" 12.6# C-110/L-80 14952' 19293' 7450' 7556' 6.125" liner with frac sleeves 24.Open to production or injection? Yes ❑ No Cl If Yes,list each 25. TUBING RECORD Interval open(MD+ND of Top&Bottom;Perforation Size and Number) SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5" 14999' 14952'MD/7450'ND not perfed �,�` 16704'MD/7522'ND,17109'MD/7526'ND +1150i14.,r: ',;i 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC �s A I Was hydraulic fracturing used during completion? Yes❑ No Q DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 15150' 17 bbls Class G 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) waiting on further well work l Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Test Period--> Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press psi 24-Hour Rate-> 28 CORE DATA Conventional Core(s)Acquired'? Yes ❑ No ❑ • Sidewall Cores Acquired'? Yes ❑ No ❑✓ 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 RBEMS OCT - 2 2014iC Form 10-407 Revised 10/2012 Tr! )!f 2 1 L S CONTINUED ON REVERSE 1'I(3 14 11S— Submit original only 29. GEOLOGIC MARKERS(List all formations and mai .icountered) 30 FORMATION TESTS NAME MD TVD Well tested? ❑ Yes E✓ 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 1525' 1500' needed,and submit detailed test information per 20 AAC 25 071 HRZ fm 13098' 6858' Kalubik fm 13757' 7110' Lower Kalubik 13870' 7149' Kuparuk C 14092' 7222' LCU 14108' 7227' Alpine C 15154' 7487' N/A CD4-96A PB1 total depth 20050' 7560' Formation at total depth: Alpine C 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey,cement detail sheets 32 I hereby certify that the foregoing is true and correct to the best of my knowledge Contact J.G.Samuel)@ 265-6309 Email John.G.Samuell@conocophillips.com -TO Printed Name G.L.Alvord Title Alaska Drilling Manager Signature ,• '� •"lv"'oQ Phone 265-6120 Date ?(Z'[A "- t — 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 WNS PROD CD4-96A Conor i'hill1ps ellAttdbutes Max Angle 4iYID TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(HKB) 501032067301 ALPINE PROD 9221 15,251.68 19,293.0 °." Comment H2S(ppm) Date Annotation End Date KB-Grd(H) -Rig Release Date HORIZONTAL-CD4-96A,8/302014 1.40.01 PM 36.60 12/16/2013 Verb al schemata(actual) Annotation Depth(HKB) End Date Annotation Last Mod By End Date -- -- ---- ---- ------ Rev Reason:GLV C/O hipshkf 8/30/2014 Hanger;31 4- ;':):'.w. casing strings `; i 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(HKB) Set Depth(ND)...Wt/Len 11...Grade Top Thread CONDUCTOR 20 19.124 36.6 114.0 114.0 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) Set Depth(HKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread I I� t SURFACE 133/8 12.415 36.6 2,939.0 2,368.9 68.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread h .4. INTERMEDIATE 95/8 8.835 1,565.8 13,260.0 6,924.6 40.00 L-80 BTC-M (T`ss R Casing Description OD(in) ID(in) Top(RK6) Set Depth(HKB) Set Depth(TVD)...Wt/Len 11...Grade Top Thread 111 1}� Intermediate7"tie-back 7 6276 33.8 12,776.4 6,715.3 26.00 L80 BTCM '4,.';' i�5 Casing Description OD(in) ID(in) Top(HKB) Set Depth(HKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread XO Reaming(Tubing).113.01 e 5 - `t., Intermediate 7"Liner 7 6.276 12,765.4 15,220.0 7,491.9 26.00 L80 Ten Blue CONDUCTOR,36.6-114.0 .41 i Liner Details r. Nominal ID 4` i. Top(HKB) Top(TVD)(HKB) Top Incl(°) Item Des Com (in) i i 12,789.2 6,721.2 62.67 Nipple(RS) RS Pack-off Seal Nipple 6.200 43 12,792.0 6,722.5 62.69 Hanger Flex-Lock Liner Hanger 6.220 x. - Casing Description OD(in) ID(in) -Top(HKB) Set Depth(HKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SSSV;2,111.0 ('. " _ V 4-1/2"Liner 4 12 3.958 14,952.3 19,293.0 7,557.7 12.60 C-110 H521 r Liner Details Nominal ID I; Top(HKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 14,972.3 7,454.1 77.52 Nipple-RS Baker 5"RS Nipple Hyd 521 Box x Box 4.250 SURFACE;36.6-2,939.0 14,9752 7,454.7 77.57 Hanger Baker 5"x 7"Flex-Lock Liner Hanger Hyd 521 Pin x 4.370 Pin Mandrel;5,303.9 I 14,984.3 7,456.6 77.75 SBE(Seal Seal Bore 4"ID,5"Hyd 521 Box x 4 1/2"Hyd 521 4.000 Bore Box Extension) Mandrel,10,3260 15,897.5 7,514.5 88.67 Sliding Sleeve Camco 4 12"Sliding Sleeve,Hyd 521 Box x Pin 2.813 2.813""X"profile 16,703.8 7,522.2 89.42 Swell Packer Swell Packer(Tam),FSC-34,Hybrid Activated,4.5", 3.958 12.6,L80 mtermediale7"oe-bo..ne a _ 17,108.5 7,525.9 88.63 Swell Packer Swell Packer(Tam),FSC-34,Hybrid Activated,4.5", 3.958 "� 12.6,L80 17,801.7 7,541.1 90.05 FRAC Sleeve,Frac,4 1/2",Ball Act,2.125"(2.073"ID) 2.073 e Sleeve/Port •��• - 18,582.7 7,551.8 8937 FRAC Sleeve,Frac,4 1/2",Ball Act,2.063"(2.010"ID) 2.010 x l I 1.'e Sleeve/Port t;13 I 19,237.0 7,555.8 88.97 FRAC 4 1/2"Pressure Sleeve-3401 psi shear pressure 3.860 Sleeve/Port INTERMEDIATE,1,565.8- 19,243.7 7,556.0 88.75 Valve 4 1/2"Wellbore Isolation Valve,.75"Ball seat for 1" 0.000 13,2600 Ball,1088 psi Mandrel;13,838.1 Tubing Strings i -` Tubing Description String Ma...ID(in) Top(HKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection 3.5"Upper 312 2.992 0.0 14,999.2 7,459.8 930 L-80 EUE Completion Completion Details Gauge/Pump Sensor;14,872.8 % Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind(°) Item Des Corn (in) 7 31.4 Hanger Hanger,elastomer 3.900 Nipple-DB.XN.D5.D, -, •'i 2,111.0 1,942.2 46.96 SSSV 3-1/2",Camco TRMAXX-5E SSSV w/2.813'"X"profile 2.812 14,9198 r. - 14,872.8 7,430.9 75.68 Gauge/Pump 3-1/2",SLB Solid Gauge Mandrel 2.913 Sensor * 14,919.8 7,4423 76.46 Nipple-DB, 3-1/2""X"nipple w/2.813"profile 2.813 Seal Assembly:14,952.7 ;,r I�t XN,DS,D t f 2 ,. 14,952.7 7,449.8 77.12 Seal Assembly 3-1/2",Baker,GBH-22 Seal Assy(39.2'to 5.0"OD 2.980 t1ri locator) fi Mandrel Inserts St m I on C Intermediate 7"Uner;12,765.4- No Top(TVD) Valve Latch Port Size TRO Runo 15,220.0 Top(HKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date 3 5,303.9 3,429.9 Camco KBMG 5.39 GAS LIFT GLV BK 0.188 2,013.0 8/30/2014 2 10,326.0 5,663.0 Camco KBMG 5.39 GAS LIFT GLV BK 0.188 1,976.0 8/30/2014 11 13,838.11 7,138.8!Camco 1KBMG I 5.39'GAS LIFT 10V IBK 1 0.2501 0.018/30/2014 0 lit El El 7C` • 4-12"Liner,14,952.3-19,293 0 - ConocoPhillips Time Log & Summary Weliview Web Reporting Report Well Name: CD4-96 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 6/1/2014 8:00:00 AM Rig Release: Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 35/29/2014 24 hr Summary Pipe shed on CD4 pad. Disconnect lines between modulesMove pits and motor complex, skid rig floor back, raise feet in cellar and raise wind walls. Disconnect pit and motor complexes. Move Sub off of well. Stage pit and motor complexes for move. 09:00 12:00 3.00 0 0 MIRU MOVE MOB X PJSM-Disconnect service lines at the Interconnect, under Rig floor, check flare lines. Move Ball Mill away from the well at 0930 hrs. NOTE: Rig Sub base on generator power at 1000 hrs, Pits and Motor complexes on generator power at 1200 hrs. 12:00 18:00 6.00 0 0 MIRU MOVE MOB X Continue to disconnect service lines between pits and sub. Disconnect HI-LINE cable, Blow down steam and water. Disconnect lines between Pits and Motors. Move Pits and Motor complexes away from rig and well. Skid rig floor, install storm clamps, raise feet in cellar. Raise windwalls. 18:00 00:00 6.00 0 0 MIRU MOVE MOB X Disconnect Pit complex from Motor complex. Move Sub off of well and stage on CD1 pad. Move Pix complex off of mats and stage behind Sub. 05/30/2014 Move ball mill to CD4. Spot and RU Ball mill. RU Ball mill to injection line and manifold. PJSM. Pressure test lines,squeeze cemented perfs. RD cementers. Move,spot and connect Motor and Pit complexes on CD4 pad. Move Rig off of CD1-03A well and position on runway tarmac. Remove cellar wall and work on rig. RU slickline and tag TOC. RD slickline. RU and set BPV. Move Rig sub from CD1 to CD4. 00:00 04:30 4.50 0 0 MIRU MOVE MOB X Move ball mill to CD4,set up and RU ball mill to perform cement job, Move and position Motor complex and Pits at the end of CD1 pad. Move remaining materials from around CD1-03A well. 04:30 06:30 2.00 0 0 MIRU MOVE MOB X Continue to RU and spot Ball mill. RU ball mill to injection line. Take on water and diesel. PJSM. Walk the lines for final inspection. Pad Operator pressured up line and open SSV and SSSV. Move Motors and Pits down the runway to CD2-CD4 road junction. Page 1 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:00 1.50 0 0 MIRU MOVE MOB X PJSM, on cement squeeze, Pump 5 bbls seawater,test lines to 4500 psi, perform injectivity test at 3 bpm, 3320 psi for 10 bbls, mix and pump 13 bbls(1.16 Yield)(63 sks)15.8 ppg class g cement at 2.2 bpm, 3000 psi,shut down,flush cement from lines,drop foam ball, kick out and displace with 101 bbls seawater at 3 bpm, 3700 psi,followed by 16 bbls diesel at 3 bpm, 3800 psi. CIP at 0810 Hrs. ETOC @ 13309'md. Squeezed 2 bbls into perfs. Move Motors and Pits down CD4 road. Remove cellar wind walls from Rig sub. 08:00 09:00 1.00 0 0 MIRU MOVE MOB X Continue to move Motors and Pits down CD4 road. Motors and Pits on CD4 pad at 0900 hrs. 09:00 12:00 3.00 0 0 MIRU MOVE MOB X PJSM. Turn, spot and connect Motors and Pits. Continue to change out cellar walls on Rig sub. 12:00 15:30 3.50 0 0 MIRU MOVE MOB X PJSM. Continue to work on rig until airport runway not needed for scheduled flights. Change out Off Driller side cellar wind walls on sub. Steam clean Motor and Pit complex. Change out cuttings Drag chain in Pits. Work on both Mud pumps. 15:30 19:00 3.50 0 0 MIRU MOVE MOB X PJSM with new crew. Move Sub from CD1 to CD1 runway tarmac. Continue to change out Drag chain in Pits and working on both Mud pumps. RU slickline on CD4-96A well. RIH and tag up on TOC and 13,167'. RD slickline. RU FMC lubricator,set BPV. NOTE: Witnessing of tagging TOC- waived by Jeff Jones of AOGCC 19:00 00:00 5.00 0 0 MIRU MOVE MOB X PJSM. Move Rig sub from CD1 to CD4. Continue to change out Drag chain in Pits. 35/31/2014 Move mats as needed to move to CD4 pad. Set matting boards on pad and put Herculite under entire rig plus complexes. Line up Sub and move near well. ND BOPE, remove adapter flange, speed head, pedestal and Dutch riser. 00:00 08:00 8.00 0 0 MIRU MOVE MOB X PJSM. Continue to move Rig sub from CD1 to CD4. Continue to change out Drag chain in Pits.Work on MP#1 -change gear oil, MP#2- change out chains. Page 2 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 12:00 4.00 0 0 MIRU MOVE MOB X Park sub near CD5 construction pad. Move rig mats on the road to finish move to CD4 pad. Continue to work on MP#2 chains and mud suction lines in the Pits. 12:00 12:15 0.25 0 0 MIRU MOVE SFTY X PJSM for continue rig move. 12:15 16:30 4.25 0 0 MIRU MOVE MOB X Move Rig sub to CD4 pad. Continue to replace MP#2 chains. Continue to work on mud suction lines in the Pits. 16:30 21:15 4.75 0 0 MIRU MOVE MOB X Move Pits and Motors complex back. Set Herculite under entire rig and complexes area. Set matting boards for rig on Herculite. Position Pits and Motors 21:15 21:30 0.25 0 0 MIRU MOVE SFTY X PJSM for spotting rig. 21:30 22:45 1.25 0 0 MIRU MOVE MOB X Move Sub, line up with well, move next to well. 22:45 23:00 0.25 0 0 MIRU MOVE SFTY X PJSM for ND BOPE 23:00 00:00 1.00 0 0 MIRU MOVE RURD X ND BOP accumulator line, adapter flange,Alpine speed head, pedestal and Dutch riser. 36/01/2014 Finish RU MPD Rotating head, spot and level rig over well. Hook up service line Interconnect. RU, install outer annulus valves,test gas alarms. 00:00 04:00 4.00 0 0 MIRU MOVE RURD X Continue to ND BOPE,Alpine speed head, pedestal and Dutch riser, Stand and Choke line, remove Blind Ram accumulator control lines, change out#2 Charge pump in centrifugal room. Install chain guard on MP#2. Stage MPD equipment in rig cellar, hydraulic pump unit, PLC, choke manifold and flowmeter near wellhead. 04:00 07:30 3.50 0 0 MIRU MOVE RURD X NU MPD spool and RCD Rotating head on top of annular preventer. Set BOP stack on pedestal. Continue to work on MP#2. Continue work in Pits, removing old suction lines. Install belt guard covers on#2 charge pump. 07:30 07:45 0.25 0 0 MIRU MOVE SFTY X PJSM on spotting Rig over well. 07:45 11:30 3.75 0 0 MIRU MOVE MOB X Spot sub over CD4-96A well and level rig. Electrician work on 208V breaker panel, continue work on MP#2 add chain oil. Continue work in Pits on suction lines. Rig sub spotted over well at 1130 hrs. NOTS: Rig accepted on Daywork at 0800 hrs 11:30 12:00 0.50 0 0 MIRU MOVE MOB X PJSM. Lower rig support feet. Lower and secure back wind walls. Page 3of77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 12:30 0.50 0 0 MIRU MOVE SFTY X Perform walk-around inspection of rig and all equipment. PJSM on skidding rig floor out over well. 12:30 14:00 1.50 0 0 MIRU MOVE RURD X Remove rig floor securing ears. Skid rig floor out over well. Lay and secure grating on rig roof. 14:00 14:15 0.25 0 0 MIRU MOVE SFTY X PJSM on positioning Pits and Motors. 14:15 15:00 0.75 0 0 MIRU MOVE MOB X Position Pits and Motor modules next to rig and shim to level. 15:00 19:00 4.00 0 0 MIRU MOVE RURD X Hook up service lines and Interconnect between modules. Hook up high line power lines to rig and Ball Mill. Secure all landings. Hook up Air,water and steam lines. NOTE: Rig and modules on High line power at 2000 hrs. 19:00 00:00 5.00 0 0 MIRU MOVE RURD X Install secondary annulus valves on OA/IA. RU lines for testing and displacement. Test Gas alarms. Clean rig. Hook up drain lines. 06/02/2014 Take on seawater. Set FMC lubricator and test. Pull BPV. RU to pressure test. Test Tbg and Cmt plug, bleed down pressure, pressure test OA, bleed down, shear out and displace diesel to Tiger tank, flow chk, install BPV, ND tree NU BOP/MPD. Install Riser and take measurements for modifications. 00:00 01:00 1.00 0 0 MIRU MOVE RURD X Work on remaining pre-spud check list items. 01:00 01:45 0.75 0 0 MIRU WHDBO MPSP X PU FMC lubricator to rig floor. RU on tree.Test lubricator to 1,000 psi and chart on recorder-good Load pits with 250 bbl of 8.38 ppg seawater (high meltwater content). 01:45 02:15 0.50 0 0 MIRU WHDBO MPSP X Pull BPV(350 psi on tbg). LD lubricator. 02:15 02:45 0.50 0 0 MIRU WELCTL RURD X PJSM. RU hardline to tree, 1502, valves, hoses and slings. 02:45 03:15 0.50 0 0 MIRU MOVE RURD X Finish work on pre-spud check list items. 03:15 03:45 0.50 0 0 MIRU MOVE SFTY X Hold Pre-spud safety meeting with crew. 03:45 05:00 1.25 0 0 MIRU WELCTL PRTS X Pressure test mud line to 3,500 psi- good. Pressure test hard line to tree to 2,900 psi-good. Pressure test tubing and cement plug to 2,000 psi, hold and record for 30 min-good. Bleed off pressure to Tote. NOTE:Witnessing of testing cement plug waived by John Crisp of the AOGCC 05:00 05:30 0.50 0 0 MIRU WELCTL PRTS X Pressure test IA to 2,000 psi, hold and record for 10 min-good. Bleed off pressure to Tiger tank. 05:30 06:00 0.50 0 0 MIRU WELCTL OWFF X Flow chk IA for 30 min-static. Page 4 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 0 0 MIRU WELCTL PRTS X Pressure test OA and liner top pkr to 2,000 psi, hold and record for 15 min -good. Bleed off pressure to Tiger tank. 07:00 07:30 0.50 0 0 MIRU WELCTL OWFF X Flow chk OA for 30 min-good. Remove chunks of ice from derrick. Prep tools for NU of BOPE. 07:30 09:30 2.00 0 0 MIRU WELCTL SFTY X Continue to remove chunks of ice from derrick. Blow down lines and RU on IA in cellar. 09:30 12:00 2.50 0 0 MIRU WELCTL KLWL X Pump down IA and pressure up to shear open the SOV with 3,000 psi- no good, bleed off pressure. Pressure up to 3,300 psi and shear out SOV. Line up to displace well down tbg with 8.38 ppg SW. Pumped Safe-surfoll detergent spacer at 3 bpm, 920 psi. Pressure increased to 3,000 psi, after 9 bbl was pumped. Shut down. Line up and pump 29 bbl down I/A with 3-5 BPM and 720- 2,670 psi.After 38 total bbl pumped, had Surf spacer back(from tbg). Continue to pump additional 262 bbl of 8.38 ppg seawater. 12:00 14:00 2.00 0 0 MIRU WELCTL KLWL X Continue to displace with 8.38 ppg seawater down I/A, at 5 BPM and 2,620 psi. Total pumped was 700 bbl. Blow down lines to Tiger tank. 14:00 14:30 0.50 0 0 MIRU WELCTL OWFF X Flow chk well for 30 min-static. 14:30 15:00 0.50 0 0 MIRU WHDBO MPSP X RD hard lines to tree. Set BPV. 15:00 15:45 0.75 0 0 MIRU WHDBO PRTS X Test BPV in the direction of flow to 1,000 psi for 10 min. Blow down and RD lines. 15:45 16:00 0.25 0 0 MIRU WHDBO SFTY X PJSM on ND tree. 16:00 17:15 1.25 0 0 MIRU WHDBO NUND X Remove drain lines, hook up Bridge crane,drain adapter void. ND tree and adapter flange. 17:15 17:30 0.25 0 0 MIRU WHDBO SFTY X PJSM on NU BOPE. 17:30 00:00 6.50 0 0 MIRU WHDBO NUND X NU BOPs. Install Riser and get measurements for modification. LD Riser and send to shop for welder to work on. Install Choke hose. 06/03/2014 Continue to RU MPD equip while adding 7.5"of length to Riser and re-install. RU test equip. Test BOPE. RD test equip, PU landing Jt B screw into tbg hanger, pull 3-1/2"tbg free from seal assembly, CBU, POOH and LD tbg 00:00 06:00 6.00 0 0 MIRU WHDBO NUND X Continue to NU BOPE. Continue RU MPD equip-RCD, return valve, relief and isolation valves, choke skid, return lines and flow meter. Welder continue to modify flow Riser in shop.. Page 5 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:00 3.00 0 0 MIRU WHDBO NUND X Continue to NU BOPE. Continue RU MPD flow meter in cellar. PU and install Riser and NU. Drain hole fill lines, connect flow line. Tighten choke line under the rig floor. 09:00 12:00 3.00 0 0 MIRU WHDBO NUND X Torque up adapter flange bolts and RCD spool bolts with Sweeny hydraulic wrench. Clean spill prevention pan under rig floor, prep test pump for BOPE test. Clean rig after NU. 12:00 12:45 0.75 0 0 MIRU WHDBO NUND X Torque studs on spacer spool, hook up MPD line in cellar, center stack 12:45 13:00 0.25 0 0 MIRU WHDBO SFTY X PJSM on testing BOPE 13:00 14:00 1.00 0 0 MIRU WHDBO RURD X Re-charge accumulator system, function test rams,fill stack, RU test equip. 14:00 17:30 3.50 0 0 MIRU WHDBO EQRP XT Fix leaks in riser, replace rig gasket on top of RCD. Change out studs on riser 17:30 18:30 1.00 0 0 MIRU WHDBO RURD X Continue ro RU test equip Set test joint and plug. Fill surface lines and work the air out of the system. 18:30 00:00 5.50 0 0 MIRU WHDBO BOPE X Test BOP annular to 250/2500 psi with 3-1/2"and 4-1/2"test joints, Test Upper rams, Choke valves 1 -16, Dart/FOSV,4" Demco Kill line valve, HCR and Manual choke/kill valves,Auto'Lower[BOP,to 250 low 3500 high w/ 3.5'and 4.5-test jts. Test lower pipe rams&blind rams to 250&3500 psi for 5 mins.-Tested with 3.5"and 4.5"test joints. Performed accumulator recovery test -200 psi in 40 secs.full pressure (3,100 psi)in 215 secs with 4X 2,100 psi on accumulator bottles. Function tested BOPE from the remote panel. -Jeff Jones of the AOGCC waived witnessing of test. 06/04/2014 Finish testing BOPE. RD test equip. PU landing Jt B and screw into tbg hanger, pull free from seal assembly, CBU. RU spooling equipment and tbg handling equipment. Pull hanger to floor and LD. POOH laying down 3-1/2" tbg. 00:00 02:00 2.00 0 0 MIRU WHDBOBOPE X Continue to test BOPE-Blind rams to 250/3,500 psi high/low on chart recorder. Perform Poor Boy gas buster flush. Test Super and Manual chokes to 1,100 psi and record on chart recorder. Blow down lines and RD test equip. Blow down TD. 02:00 02:15 0.25 0 0 MIRU WHDBO RURD X RU Clam shell under rig floor.. 02:15 03:00 0.75 0 0 MIRU WHDBO RURD X Pull Blanking plug and BPV. PU and install Mouse hole. Page 6of77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:30 0.50 0 13,086 SLOT RPCOM RURD X PJSM. MU Landing Jt B to Tubing Hngr and screw in. Screw into LJ with TD. BOLDS.Verify no pressure under the tbg Hngr-0 psi. PU and un-sting tbg from seal assembly with 137K lb. Space out to 13,086' md. 03:30 04:30 1.00 13,086 13,086 SLOT RPCOM CIRC X CBU staging pumps up from 4 BPM to 8 BPM, 380-1,460 psi. RU control line spooling unit, power tongs and tbg handling equip. Had small volume gas at CBU with 1,125 units. Mud wt even at CBU with 8.38 ppg• 04:30 05:00 0.50 13,086 13,086 SLOT RPCOM OWFF X Flow chk-static. Blow down TD. 05:00 09:30 4.50 13,086 10,960 SLOT RPCOM PULL X PJSM. Disconnect control line from tbg hanger. POOH, LD 2 jts of 4-1/2"tbg under the hanger, continue to LD 3-1/2" EUE, 8rd, 9.3 lb/ft L-80 tubing, spooling up 1/4"SS steel control line. NOTE: recovered 4 steel bands and 66 Cannon clamps(all accounted for). 09:30 09:45 0.25 13,086 10,960 SLOT RPCOM PULL X LD SSSV, RD spooling unit. 09:45 12:00 2.25 10,960 8,901 SLOT RPCOM PULL X Continue to LD 3-1/2" EUE, 8rd, 9.3 lb/ft L-80 tubing from 10,960'to 8,901'and(130 Jts) PU= 110K, SO= 90K lb. 12:00 21:30 9.50 8,901 0 SLOT RPCOM PULL X Continue to LD 3-1/2" EUE, 8rd, 9.3 lb/ft L-80 tubing from 8,901'to 1,479' and(233 Jts), continue to LD 3-1/2", H563,9.3 lb/ft, L-80 tbg to seal assembly(46 jts). 21:30 22:30 1.00 0 0 SLOT RPCOM RURD X LD Tbg equip, Clear and clean rig floor 22:30 22:45 0.25 0 0 SLOT RPCOM SFTY X PJSM on changeout of rams 22:45 00:00 1.25 0 0 SLOT RPCOM BOPE X Change out top pipe rams to 4-1/2"x 7"VBRs. Change out TD saver sub to DS-50. 06/05/2014 Change out upper pipe rams to 4.5 x 7"VBRs, pressure test. Pressure test MPD system. Back out LDS, PU spear assembly, RIH and spear 7"csg. CBU,displace out frz protect diesel to Tiger tank, flow chk, POOH laying down and inspecting 7"csg. 00:00 08:30 8.50 0 SLOT WHDBO BOPE X Test BOPE Annular 250/2,500psi, UPR and LPR 250/3,500psi with 5" test joint.Annular 250/2,500psi and UPR with 7"test joint. Pressure test MPD head and choke skid to 250/1,000psi. Good Pull test plug. 08:30 09:30 1.00 SLOT RPCOM PULL X Make up Pack-off pulling tool. Verify 0 psi on OA. BOLDS and pull 7"Pack off with blocks. 13k to pull pack-off Page 7 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:15 1.75 SLOT RPCOM PULL X PJSM on unlanding casing and circulating. Pick up Spear assembly and make up to Top Drive. Engage Spear, close annular and fill pipe. Pull seals free stripping through the annular at 275k. Well"U"tubed to the string with 170psi on the pipe. 11:15 13:30 2.25 SLOT RPCOM CIRC X Circulate sea water down 7"taking returns out to the Kill tank. Circulate 576bb1s until clean returns. 5bbl/min 600psi 13:30 14:00 0.50 SLOT RPCOM OWFF X Check well for flow-Good Conduct PJSM on laying down 7" casing. 14:00 14:30 0.50 SLOT RPCOM PULL X Pull hanger to rig floor. Release casing spear and LD. 14:30 00:00 9.50 SLOT RPCOM PULL X POOH with 7",Tenaris,26 lb/ft, BTC-M casing from 13,000'to 6,865' (145 of 310 jts). 36/06/2014 Continue to pull and LD 7"csg. RD csg equip. PU scraper/mills BHA and single in the hole to 10,908'md. 00:00 08:00 8.00 6,865 0 SLOT RPCOM PULL X Continue to POOH with 7",Tenaris, 26 lb/ft, BTC-M casing from 6,865'to surface 312 jts total. 08:00 09:15 1.25 0 0 SLOT WHPST RURD T PJSM. RD csg equipment. Clear and clean the rig floor. RU 5"DP elevators, PU scraper and watermelon mills to rig floor. 09:15 09:45 0.50 0 0 SLOT WHPST OTHR T Set 12.375"ID wear ring. PJSM on PU BHA. • 09:45 12:00 2.25 0 270 SLOT WHPST PULD T MU Scraper/mills-BHA#2 to 270'. 12:00 12:15 0.25 0 539 SLOT WHPST PULD T Finish MU Scraper/mills-BHA#2 to 539'. 12:15 21:00 8.75 539 8,549 SLOT WHPST PULD T Single in hole with 141 jts of 5"NC50 and 114 jts of 5"DS50 DP from 539' to 8,549'md. 21:00 21:45 0.75 8,549 8,549 SLOT WHPST PULD T PU RCD sealing element assembly and pulling tool to the rig floor. 21:45 00:00 2.25 8,549 10,908 SLOT WHPST PULD T Continue to single in hole with 63 jts of 5", DS50 DP from 8,549'to 10,908'md. PU= 170K, SO= 130K lb. 06/07/2014 Continue to RIH with scraper/mill BHA to 13,070'. Cut and Slip drill line, POOH 12 stds, install Rotating head element and test. POOH adding Super-sliders to drill string. 00:00 02:30 2.50 10,908 13,012 SLOT WHPST PULD T Continue to single in hole with 5", DS50 DP from 10,908'to 13,012'md. PU=305K, SO= 158K lb. 02:30 02:45 0.25 13,012 13,059 SLOT WHPST CIRC T Wash down with 5 BPM, 160 psi from 13,012'to 13,059'.Tag up on 7" csg stub and set down with 5K to confirm. 02:45 04:30 1.75 13,059 12,983 SLOT WHPST CIRC T CBU at 800 gpm,2,210 psi. Flow chk-static. Stand back one stand to 12,983'md. Page 8 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 07:00 2.50 12,983 12,983 SLOT WHPST SLPC T Slip and cut 75'of drill line. Inspect and service TD. Inspect deadman and pump up sensor. Perform full block weight calibration. 07:00 07:30 0.50 12,983 12,983 SLOT WHPST RURD T Pick up Super-sliders and tools to rig floor. 07:30 09:15 1.75 12,983 12,135 SLOT WHPST TRIP T Trip out of the hole with 9 stands of 5"drill pipe from 12,983'to 12,135' Up wt 320k 09:15 18:30 9.25 12,135 11,757 SLOT WHPST RURD T PJSM with MI Swaco MPD hands,Rig crews,WWT hand. Discuss procedures on installing rotating head, making connections& tripping with MPD. Install rotating head element on 5" Double and stab into RCD head. Close clamp(31sec)and pull test up. Good Open clamp(27sec)and pull element out on bare pipe. Set element in head and close clamp (25sec) Establish circulation down drill pipe and taking returns through MPD choke. Stage pumps up to 650gpm at 1500psi choke at 99%open, choke pressure 34psi with 8.4 sea water. Conduct foot print test staging pumps up going through both A&B chokes. Practice coming up and down on the pumps catching pressure when pumps are off. Start at 100psi and work up to 500psi. Catch 540psi of pressure and run pipe in the hole in 1'increments recording annulus pressure. 1-535 2-540 3-550 4-560 5-570 Bleed off stand pipe pressure and ensure float is holding-Good. Trip out of the hole with 3 stands pumping 3bpm holding 500psi pulling 1500ft/min. Dynamic choke control functioned well. Install WWT super sliders on stand and work through RCD with no issues holding 500psi of annular pressure. Remove rotating head element and allow second crew to stab rotating head and remove same. Page9of77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 19:00 0.50 11,757 11,757 SLOT WHPST RURD T Blow down Kill line and MPD equip. LD RCD sealing element. 19:00 00:00 5.00 11,757 10,153 SLOT WHPST TRIP T POOH from 11,757'to 10,153' installing Super-sliders,2 per joint. 06/08/2014 Continue to POOH adding Super-sliders to drill string. LD BHA, PU CIBP. RIH with CIBP on DP to 12,955' and set. Pull+30K and release from CIBP. Pressure test CIBP and csg to 2,500 psi and hold for 30 min- good. Displace well to milling fluid. 00:00 02:00 2.00 10,153 9,170 SLOT WHPST TRIP T POOH from 10,153'to 9,170' installing Super-sliders,2 per joint. 02:00 04:45 2.75 9,170 7,270 SLOT WHPST TRIP T POOH from 9,170'to 7,270' installing Super-sliders, 1 per joint. 04:45 08:00 3.25 7,270 539 SLOT WHPST TRIP T POOH from 7,270'to and stand back in derrick 08:00 08:15 0.25 539 539 SLOT WHPST OWFF T Flow check well at HWDP-Good 08:15 10:00 1.75 539 0 SLOT WHPST TRIP T Rack back 5 stands of HWDP and lay down Scraper assembly. Large amounts of Schmoo on scraper, mills and jars. 10:00 11:00 1.00 0 0 SLOT WHPST RURD T Clean and clear rig floor. Remove Baker tools. 11:00 12:00 1.00 0 472 SLOT WHPST TRIP T Make up Baker 9 5/8" N1 Cast Iron Bridge Plug. Part#H400-21-6322 Ser#104132647 Hydraulic Set. Run in hole with 5 stands of HWDP to 472.55. 12:00 20:15 8.25 472 12,921 SLOT WHPST TRIP T Trip in the hole with Baker 9 5/8" CIBP at 3600ft/hr. Slow down at 9 5/8"liner lap at 1,566'. No problems. Continue to RIH to 12,920.5' md. Calc Displ= 114.9 bbl+ 11.4 bbls for Sliders /Actual= 129 bbl 20:15 20:30 0.25 12,921 12,955 SLOT WHPST MPSP T Drop 1-3/8"setting ball. Space out and locate on depth at 12,955'. PU= 265K, SO= 173K lb. 20:30 21:45 1.25 12,955 12,917 SLOT WHPST MPSP T Pump ball down with 3 BPM, 70 psi for 1,125 stks(half the DP volume. Reduce rate to 1.5-2.0 BPM with 10-20 psi. Setting ball landed at 1,596 stks, increase pressure to 800 psi and hold for 5 min. Bleed off pressure to 200 psi and PU slowly to release from CIBP. Released at PU= 295K Ib, +30K over. Set back down with 4K Ib,2x to confirm set and on depth-good. Rack back stand to 12,917'. PU=265K, SO= 173K 21:45 22:00 0.25 12,917 12,917 SLOT WHPST SFTY T PJSM for testing CIBP. 22:00 23:15 1.25 12,917 12,917 SLOT WHPST PRTS T RU and work air out of system. Close rams, pressure up CIBP, 9-5/8"casing to 2,500 psi, hold for 30 min and chart(total 10 bbl pumped)-good test. Blow down lines, RD test equip. L Page 10 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:15 23:30 0.25 12,917 12,917 SLOT WHPST SFTY T PJSM on displacement and Grizzly bears on pad. 23:30 00:00 0.50 12,917 12,950 SLOT WHPST CIRC T PU single to locate 5'above CIBP. Displace well from seawater to 10.5 ppg milling fluid at 7 BPM,230 psi ,with 24 bbl Hi-vis pill ahead. 06/09/2014 Finish displacing well to milling fluid. POOH. PU/MU whipstock and mills, one trip system. RIH with whipstock, shallow test MWD, continue RIH to 4,155'md. 00:00 02:15 2.25 12,917 12,917 SLOT RPCOM CIRC T Continue to displace well from seawater to 10.5 ppg milling fluid at 7 BPM,230 psi with 24 bbl Hi-vis pill ahead. 02:15 02:45 0.50 12,917 12,822 SLOT RPCOM OWFF T LD single Jt. Flow-chk-static. Stand back one stand to 12,822'. 02:45 03:15 0.50 12,822 12,822 SLOT RPCOM SFTY T PJSM for installing RCD sealing element. 03:15 04:45 1.50 12,822 12,822 SLOT RPCOM PRTS T Test MPD equip at 296 psi to re-calibrate system-choke with 10.5 ppg mud. Test MPD at full drilling rate pressure(static)of 497 psi. Test successful. 04:45 05:15 0.50 12,822 12,822 SLOT RPCOM PULD T Pull RCD seal element and LD. 05:15 05:45 0.50 12,822 12,822 SLOT WHPST OTHR T Pump dry job. SPRs at 12,922', 10.5 ppg MW MP1 30 psi 4.4 bbl/min MP1 40 psi 4.8 bbl/min MP2 30 psi 4.4 bbl/min MP2 40 psi 4.8 bbl/min 05:45 12:00 6.25 12,822 4,143 SLOT WHPST TRIP T POOH from 12,822'to 4,143'on Trip tank. PU= 143K, S0= 110K lb 12:00 13:30 1.50 4,143 472 SLOT WHPST TRIP T POOH from 4,143'to 472'on Trip tank. 13:30 13:45 0.25 4,143 472 SLOT WHPST SFTY T Flow check at BHA-static. POOH on TT to CIBP running tool and inspect-good. 13:45 15:45 2.00 472 0 SLOT WHPST PULD T Clear and clean rig floor. LD CIBP running tools, PU handling equip for new BHA. 15:45 18:45 3.00 0 819 SLOT WHPST PULD T PJSM. PU/MU 9-5/8" Btm Trip Anchor and Gen II Whipstock, lower string mill, upper string mill,flex collars, 15 jts of 5"HWDP,2x string magnets 18:45 19:30 0.75 819 1,479 SLOT WHPST TRIP T RIH from 819'to 1,479'md. PU= 115K, S0= 112K lb. 19:30 20:30 1.00 819 1,479 SLOT WHPST TRIP T Shallow pulse test MWD with 450-525 gpm and 420-530 psi. Confirmed data transmitting. 20:30 00:00 3.50 1,479 4,155 SLOT WHPST TRIP T Continue to RIH to 3,260',fill pipe, pump at 650 gpm, 1,120 psi and take chk shot survey. Confirm able to decode data properly.-okay. Continue RIH to 4,155' Page 11 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/10/2014 24 hr Summary Continue to RIH with whipstock, set and shear off. Mill window and 3'of formation to 12,958'(TOW-12,935'/ BOW-12,955') 00:00 10:30 10.50 4,155 0 SLOT WHPST TRIP T Continue toTrip in the hole with the Whipstock and mill assembly at 1,600 ft/min to 12,697'(fill pipe evry 20 stds) Calc Disp= 128.12 bbls/Act Disp= 121 bbls 10:30 13:00 2.50 12,697 12,935 SLOT WHPST WPST T Kelly up and wash down f/12,700'to 12,935'645 gpm 2180 psi orientating whipstock to-60°-Cycle pumps and collect surveys to ensure good data. Upwt275k Dn wt 170 k Set down on bridge plug and screws sheared at18 k. Pick up and no over pull. Set back down 35 k and see second shear. Pick up and pull 10 k over 285 k. Set back down and shear brass connecting bolt with 38 k. Upwt270k Dnwt165k 13:00 00:00 11.00 12,935 12,958 SLOT WHPST MILL T Mill window f/12,935'to 12,958' w/450-500 gpm @ 1120-1450 psi &w/80- 100 rpm @ 9-10 k trq, 2- 18 k wob. Top of window 12,935'/Bottom of !window 12,955' 36/11/2014 Cont.to Mill window&new formation to 12,975'-Circ&cond mud for FIT/LOT-Perform LOT to 16.6 ppg- POOH 5 stands-Slip&cut drill line-POOH to 669'-Cleaning metal from in-line magnets 00:00 01:30 1.50 12,958 12,958 SLOT WHPST MILL T Pick up and shut pumps off and screen down due to greasing on the shaker screens. 01:30 04:45 3.25 12,958 12,977 SLOT WHPST MILL T Continue to mill window&20'new formation to 12,977'w/500 psi @ 1520 psi&w/110rpm @ 11.5-12k ,trq 04:45 05:15 0.50 12,977 12,861 SLOT WHPST TRIP T Trip out of the hole from 12,975'to 12,861' Rack back stand#130 and lay down single that was picked up for milling. 05:15 06:45 1.50 12,861 12,861 SLOT WHPST CIRC T Circulate and condition hole. Reciprocating pipe. 504gpm 1600psi Total of 1,177bbls circulated Confirm 10.5ppg in and out Page 12 of 77 rTime Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 08:30 1.75 12,861 12,861 SLOT WHPST'LOT T PJSM on conducting FIT/LOT. Purge air from Kill and cement lines. Close upper pipe rams. Pump down the drill string and cement line at 6bpm for a total of 13.4bbls pumped. Formation breaking down at 2,170psi for a EMW LOT of 16.6ppg. 12,975' MD 6,808'TVD Bleed back 6bbls Open Pipe rams. 08:30 09:00 0.50 12,861 12,861 INTRM2 DRILL OWFF T Check well for flow. Blow down surface lines. 09:00 10:00 1.00 12,861 12,375 INTRM2 DRILL TRIP T Trip out of the hole 5 stands from 12,861'to 12,375'. Calculated displacement 3.6bbls Actual displacement 4.2bbls Pull pipe at 1,100 ft/hr 10:00 11:30 1.50 12,375 12,375 INTRM2 DRILL SLPC T Cut&Slip drill line. Monitor hole on trip tank. 11:30 12:00 0.50 12,375 12,375 INTRM2 DRILL CIRC T Pump dry job 30bbls 11.5ppg 12:00 22:15 10.25 12,375 795 INTRM2 DRILL TRIP T Trip out of the hole from 12,375 to Following tripping speed schedule TD to 11000 1100 fUhr 11000 to 9000 1350 ft/hr 9000 to 7000 1850 ft/hr 7000 to 5000 2750 ft/hr 5000 to Surface 5500 ft/hr 22:15 22:30 0.25 795 795 INTRM2 DRILL OWFF T OWFF(static)-PJSM w/M-I swaco &Baker on L/D string magnets 22:30 00:00 1.50 795 669 INTRM2 DRILL BOPE T POOH f/795'to 669'while cleaning metal from in-line magnets- (SIMEOPS-Test choke manifold 250/3500 psi&chart for 5 min- Valves 1-16, Needle Valve, Manual& Super Choke, Draw Down on Choke to 1100 psi) 36/12/2014 Cont.to clean string magnets-Rack back HWDP&NMFC's-L/D mills-Flush stack, pull wear ring,& install test plug-Test B.O.P.'s-test orbit valve&rotating head-Pull test plug&set wear ring-Monitor well while work on Koomey(Repair Barksdale Valves) 00:00 01:30 1.50 669 669 INTRM2 DRILL PULD P Cont.to clean string magnets 01:30 02:30 1.00 669 85 INTRM2 DRILL TRIP T POOH&rack back HWDP& NMFC's 02:30 03:15 0.75 85 0 INTRM2 DRILL PULD T L/D mills&milling BHA as per Baker rep. 03:15 05:00 1.75 0 0 INTRM2 WHDBO RURD T Flush stack w/12 bpm @ 150 psi- Pull wear ring&install test plug Page 13of77 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 05:00 11:15 6.25 0 0 INTRM2 WHDBO BOPE T test B.O.P.'s-(Test w/5"&7"test jts, Test Annular to 250/2500,psi& chart for 5 min,Test upper 4-1/2"x 7"VBR's&lower 3-1/2"x 6"VBR's to 250/3500 psi&chart for 5 min, Test blind rams,4"kill Demco, HCR choke&manual choke, Manual& Auto IBOP, Dart&FSOV to 250/3500 psi&chart for 5 min)- Wittiness waived by AOGCC Johnny Hill 11:15 13:15 2.00 0 0 INTRM2 WHDBO BOPE T PJSM-Test Orbit valve&rotating head to 250 psi for 5 min& 1000 psi for 15 min-Perform Koomey test, 38 sec to first 200 psi, &202 sec to full system pressure-4 bottles @ 2200 psi (Observed fluid leaking by Barksdale valves on Koomey-Trouble shoot Koomey) 13:15 13:45 0.50 0 0 INTRM2 WHDBO RURD T PJSM-Pull test plug&install wear ring-B/D lines 13:45 00:00 10.25 0 0 INTRM2 DRILL RGRP T Monitor well with blind rams shut (static)-Work on Koomey Barksdale valves-SIMOPS service crown light 06/13/2014 Cont.to repair Koomey-Draw down test on Koomey-M/U Mud Motor BHA-RIH to 1,578'&shallow hole test 00:00 19:00 19.00 0 0 INTRM2 DRILL RGRP T Monitor well with blind rams shut (static)-Work on Koomey Barksdale valves-SIMOPS-P/U 5" DP from pipe shed&rack back in derrick via mouse hole-Adjust brakes on draw works-Set block height 19:00 19:30 0.50 0 0 INTRM2 WHDBO BOPE T P/U 1 std 5' DP&RIH-Perform Koomey test(Int 200 psi 35 sec& full system psi 186 sec-4 bottles @ 2000 psi) 19:30 22:15 2.75 0 639 INTRM2 DRILL PULD T PJSM-M/U 8-3/4"mud motor BHA to 639' 22:15 00:00 1.75 639 1,578 INTRM2 DRILL TRIP T RIH f/639'to 1,578'w/5"DP from derrick&shallow hole test directional tools 06/14/2014 Cont.to RIH to 12,518'&install RCD element&func test MPD-Cont.to RIH to top of window @ 12,935' - Orientate thru window-Displace to new LSND on the fly-Drill f/12,977'to 13,087' 00:00 13:15 13.25 1,578 12,552 INTRM2 DRILL TRIP T Cont.to RIH f/1,578'to 12,552'as per trip schedule-Fill puipe every 20 stds 13:15 13:45 0.50 12,552 12,552 INTRM2 DRILL RURD T PJSM-Install RCD element 13:45 15:30 1.75 12,552 12,552 INTRM2 DRILL OTHR T Test RCD&@ balance chokes with various rates&choke positions- (55o gpm @ 2180 psi w/#2 choke closed)-SPR's 15:30 16:15 0.75 12,552 12,896 INTRM2 DRILL TRIP T RIH f/12,552'to 12,896' Page 14 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 17:00 0.75 12,896 12,896 INTRM2 DRILL CIRC T PJSM-Pump 40 bbl high vis spacer &chase with new LSND&pump to bit 17:00 18:00 1.00 12,896 12,977 INTRM2 DRILL WASH T Orientate directional tools&wash in hole f/12,896'to 12,977'w/440-480 psi @ 1900-2090 psi-(No pumps& No rotation through window f/12,935' to 12,961') 18:00 00:00 6.00 12,977 13,087 INTRM2 DRILL DDRL T Directionaly drill kick off f/12,977'to 13,087'/6,901'TVD,ADT=3.63 hrs /Slide= 1.91 hrs 550 gpm @ 2330 psi, ECD= 11.63 ppg 30 rpm @14 DT/12 OBT PU wt 250 k, SO wt 160 k, ROT wt _ 165k 06/15/2014 Cont.to drill to TD of 13,160'-POOH to top of window-Wt up to 11.0 ppg-POOH&L/D BHA#5(Remove RCD @ 2000')-Clear&clean floor-M/U RSS BHA#6 00:00 05:15 5.25 13,087 13,160 INTRM2 DRILL DDRL T Directionaly drill kick off f/13,087'to TD of 13,160'/6,883'TVD,ADT= 2.46 hrs/Slide=0.95 hrs 550 gpm @ 2450 psi, ECD= 11.42 ppg 30 rpm @14 DT/12 OBT PU wt 250 k, SO wt 160 k, ROT wt 165 k 05:15 05:45 0.50 13,160 13,084 INTRM2 DRILL CIRC T Circ&cond mud/hole for 15 min w/550 gpm @ 2310 psi-orient high side&rack back 1 std f/13,160'to 13,084' 05:45 06:30 0.75 13,084 12,896 INTRM2 DRILL TRIP T Line up MPD thru kill line w/3 bpm& POOH w/300-350 psi f/13,084'to 12,896' 06:30 08:30 2.00 12,896 12,896 INTRM2 DRILL CIRC T Line back up on drill string-Circulate &wt up mud system to 11.0 ppg w/550 gpm @ 2280 psi-Reduce flow to 400 gpm @ 1500 psi&30 rpm @ _ 12 k trq 08:30 08:45 0.25 12,896 12,896 INTRM2 DRILL OWFF T OWFF-(static) 08:45 09:45 1.00 12,896 12,896 INTRM2 DRILL RURD T PJSM-C/O RCD element 09:45 10:30 0.75 12,896 12,896 INTRM2 DRILL CIRC T Pump Slug(Dry Job)-37 bbls 15.0 ppg -Wait for fluid to drop 10:30 18:30 8.00 12,896 2,049 INTRM2 DRILL TRIP T POOH w/MPD @ balance f/12,896' to 2,049'w/125-160 gpm @ 230 psi 18:30 19:30 1.00 2,049 2,049 INTRM2 DRILL RURD T F/C-(static)-PJSM-Remove RCD _ element-UD element-B/D kill line 19:30 21:00 1.50 2,049 177 INTRM2 DRILL TRIP T POOH on elevators on TT f/2,049'to 177'-Rack back HWDP&jars-F/C @ HWDP(static) 21:00 23:00 2.00 177 0 INTRM2 DRILL PULD T PJSM-L/D BHA#5 as per SLB Calc Hole Fill= 117 bbls/Act Hole Fill= 118 bbls Page 15 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:00 00:00 1.00 0 0 INTRM2 DRILL PULD T Clear&clean floor-Remove BHA tools from floor via beaver slide-Prep to P/U BHA#6 06/16/2014 Cont.to M/U BHA#6-RIH to 1,500'&shallow hole test-Cont.to RIH to 12,800'-Slip&Cut drill line- Service Rig 00:00 01:30 1.50 0 0 INTRM2 DRILL PULD T MWD prep BHA tools 01:30 02:00 0.50 0 0 INTRM2 DRILL SVRG T Service top drive-Add oil&grease IBOP 02:00 04:00 2.00 0 609 INTRM2 DRILL PULD T M/U BHA#6 as per SLB to 609'- (8-3/4" PDC bit,Xceed,Arc, Telescope, Rhino Reamer) 04:00 05:00 1.00 609 1,548 INTRM2 DRILL TRIP T RIH w/BHA#6 f/609'to 1,548'as per MPD surge ECD schedule 05:00 06:00 1.00 1,548 1,548 INTRM2 DRILL CIRC T Shallow hole test MWD tools w/550 gpm @ 990 psi-Function Rhino Reamer(Closed w/650 gpm, 1400 psi, 3672 TRPM/Open w/650 gpm, 1280 psi, 3477 TRPM) 06:00 15:15 9.25 1,548 8,147 INTRM2 DRILL TRIP T RIH w/BHA#6 f/1,548'to 8,147'as per MPD surge ECD schedule-Fill pipe every 20 stds 15:15 16:45 1.50 8,147 8,147 INTRM2 DRILL OTHR T PJSM-Shuffle drill pipe in derrick to reposition WWT super sliders- Adjust pipe tally 16:45 22:30 5.75 8,147 12,865 INTRM2 DRILL TRIP T RIH w/BHA#6 f/8,147'to 12,865'as per MPD surge ECD schedule-Fill pipe every 20 stds Calc Disp 121.1 bbls/Act Disp 132.1 bbls 22:30 23:30 1.00 12,865 12,865 INTRM2 DRILL SLPC T PJSM-Slip&cut drill line 23:30 00:00 0.50 12,865 12,865 INTRM2 DRILL SVRG T Service rig&top drive 06/17/2014 Install RCD-Cut mud wt to 10.5 ppg-RIH to 13,160'(Open Reamer @ 13,122')-Drill Ahead to 13,620'-R/U Gyro-Pump down Gyro to 550' 00:00 00:45 0.75 12,865 12,865 INTRM2 DRILL RURD T Install RCD Element 00:45 03:30 2.75 12,865 12,865 INTRM2 DRILL CIRC T Prep pits for taking on fluid- Circulate&cut mud wt f/11.0 to 10.5 ppg-Flow rates varied f/400-540 gpm to maximize circulating time& attempt to keep ECD's<11.8 ppg (Max ECD observed 12.05 ppg) 03:30 04:00 0.50 12,865 13,148 INTRM2 DRILL TRIP T RIH with no pumps&no rotary f/12,865'to 13,148' 04:00 05:00 1.00 13,148 13,122 INTRM2 DRILL DHEQ T Downlink to MWD-Cycle Rhino Reamer&verify functioning properly- Pump out of hole f/13,148'to 13,122' Closed-650 gpm,2650 psi, TRPM 3516 Open-650 gpm, 2400 psi,TRPM 3008 Page 16 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 05:45 0.75 13,122 13,160 INTRM2 DRILL REAM T Open Rhino Reamer-Ream in hole opening hole to 9-7/8"f/13,122'to 13,160'w/650 gpm @ 2400 psi& w/60 rpm @ 12- 13 k trq (9-7/8"hole @ 13,021') 05:45 17:15 11.50 13,160 13,620 INTRM2 DRILL DDRL T Directionaly drill w/MPD f/13,160'to 13,620'/7,058'TVD,ADT=8.08 hrs 620 gpm @ 2380 psi, ECD= 11.9 PP9 120 rpm @ 16.5 DT/14 OBT PU wt 270 k, SO wt 165 k, ROT wt 190 k 17:15 19:00 1.75 13,620 13,620 INTRM2 DRILL CIRC T Function Rhino Reamer closed& circ B/U w/620 gpm @ 2500 psi& w/100 rpm @ 11 k trq 19:00 22:30 3.50 13,620 13,620 INTRM2 DRILL SRVY T B/D top drive-Line up to circ thru kill line @ 3 bpm w/500 psi back pressure-PJSM-R/U HES E-line- R/U goose neck&greese head- M/U Gyro to E-line 22:30 00:00 1.50 13,620 13,620 INTRM2 DRILL SRVY T Pressure test grease head to 1000 psi-RIH w/E-line to 550'(Gyro not able to gravity fall&pumped Gyro down @ 1 -3 bpm w/800 psi on SPP &350-500 psi back pressure to equal 11.8 BHP) 06/18/2014 Cont. to pump down Gyro&check shot MWD surveys-POOH w/Gyro&R/D E-line-Resume drilling ahead f/13,620'to 14,280" 00:00 05:30 5.50 13,620 13,620 INTRM2 DRILL SRVY T Cont.to pump down Gyro w/3-5 bpm @ 760-870 psi-Line up on kill line w/3 bpm&POOH w/Gyro(@ Balance 500 psi) 05:30 06:45 1.25 13,620 13,620 INTRM2 DRILL SRVY T PJSM-R/D Gyro tools&R/D E-line 06:45 07:15 0.50 13,620 13,620 INTRM2 DRILL SRVY T Remove FOSV&test mud lines to 3500 psi(good test) 07:15 08:00 0.75 13,620 13,620 INTRM2 DRILL DHEQ T Circulate&pump up ESD&ECD data-Downlink to directional tools- Cycle pumps to open Rhino Reamer 08:00 21:45 13.75 13,620 14,123 INTRM2 DRILL DDRL T Directionaly drill w/MPD f/13,620'to 14,123'/7,231'TVD,ADT=7.98 hrs 650 gpm @ 2600 psi, ECD= 11.89 Pp9 120 rpm @ 19 DT/15.5 OBT PU wt 280 k, SO wt 162 k, ROT wt 197k 21:45 00:00 2.25 14,123 14,280 INTRM2 DRILL DDRL P Directionaly drill w/MPD f113,620'to 14,280'/7,279'TVD,ADT= 1.54 hrs 650 gpm @ 2690 psi, ECD= 11.93 PP9 120 rpm @19.5 DT/16 OBT PUwt285k, SOwt160k, ROT wt 198 k Page 17 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/19/2014 24 hr Summary Drill ahead to TD of 15,224'/7,493'TVD-Circulate out gas(2329 max units) 00:00 12:00 12.00 14,280 14,815 INTRM2 DRILL DDRL P Directionaly drill w/MPD f/14,280'to 14,815'/7,413'TVD,ADT=7.58 hrs 650 gpm @ 2790 psi, ECD= 11.84 PPg 120 rpm @ 20 DT/16.5 OBT PU wt 290 k, SO wt 150 k, ROT wt 200k 12:00 23:15 11.25 14,815 15,224 INTRM2 DRILL DDRL P Directionaly drill w/MPD f/14,815'to TD of 15,224'/7,493'TVD,ADT= 7.02 hrs 650 gpm @ 27200 psi, ECD= 11.88 PPg 120 rpm @ 20.5 DT/17 OBT PU wt 290 k, SO wt 135 k, ROT wt 205 k 23:15 00:00 0.75 15,224 15,224 INTRM2 CASING CIRC P Circ out gas w/650 gpm @ 2720 psi &w/120 rpm @ 20.5 k trq-Max gas 2329 units 06/20/2014 Pump up final survey&close Rhino Reamer-Circ 2 B/U&wt up to 10.7 ppg-Strip OOH to 12,865'-Wt up to 11.6 ppg-F/C-Pump dry job-Rabbit 6 stds in derrick-Strip OOH f/12,865'to 9,373' 00:00 00:30 0.50 15,224 15,224 INTRM2 CASING DHEQ P Cycle Rhino Reamer closed- Downlink to Xceed to neutral position. 00:30 07:30 7.00 15,224 15,224 INTRM2 CASING CIRC P Circulate 2 B/U w/650 gpm @ 2950 psi w/120 rpm @ 20.5 k trq- Increase mud wt f/10.2 ppg to 10.7 ppg over 3 circulations following MPD weight up schedule to mainatin 11.8-11.9 ppg ECD Intial 650 gpm @ 2870 psi& 120 rpm @ 19 k trq Final 475 gpm @ 1770 psi&80 rpm @ 17 k trq 07:30 08:15 0.75 15,224 15,224 INTRM2 CASING RURD P SPR's-Line up on kill line to hold back pressure as per @ balance w/3 bpm @ 420 psi 08:15 11:15 3.00 15,224 12,865 INTRM2 CASING TRIP P POOH on elevators f/15,224'to 12,865'w/3 bpm -@ Balance holding 580-600 psi while pulling& 400 psi while in slips to maintain 11.8-11.9 ppg BHP Page 18 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 18:45 7.50 12,865 12,865 INTRM2 CASING CIRC P Line up on drill string&break circ w/400 gpm @ 1400 psi-@ Balance open up choke-Pump up MWD ECD/ESD data-Weight up f/10.7 ppg to 11.6 ppg following MPD weight up schedule to mainatin 11.8 - 11.9 ppg ECD Intial 500 gpm @ 1660 psi&30 rpm @ 11 k trq Final 100 gpm @ 870 psi&no rotation 18:45 19:30 0.75 12,865 12,865 INTRM2 CASING OWFF P Line up on kill line to hold back pressure as per @ balance w/3 bpm @ 130 psi-F/C for 30 min(no gain/no loss) 19:30 19:45 0.25 12,865 12,865 INTRM2 CASING CIRC P Line up down drill string&pump 34 bbl 15 ppg dry job w/100 gpm 19:45 21:00 1.25 12,865 12,865 INTRM2 CASING CIRC P Line up on kill line-Let dry job fall& balance out-Rabbit 6 stds f/derrick w/2.9"rabbit(stds 131 - 136 needed for liner run)-Drop 2.75"hollow rabbit down drill string 21:00 00:00 3.00 12,865 9,373 INTRM2 CASING TRIP P POOH on elevators f/12,865'to 9,373'w/3 bpm -@ Balance holding 250-280 psi while pulling& 100 psi while in slips to maintain 11.8-11.9 ppg BHP 06/21/2014 Cont.to Strip OOH to 1000'- Remove RCD element-F/C-POOH on TT-L/D BHA#6-R/U to run 7"liner- M/U liner&RIH to 2,466'-Circ liner volume-Cont.to RIH liner on 5"DP to 4,159" 00:00 06:00 6.00 9,373 1,076 INTRM2 CASING TRIP P POOH on elevators f/9,373'to 1,076' w/3 bpm -@ Balance holding 280- 200 psi while pulling& 100 psi while in slips to maintain 11.8- 11.9 ppg BHP 06:00 07:15 1.25 1,076 1,076 INTRM2 CASING RURD P PJSM-@ Balance open chokes- Bleed off psi&drain riser-M/U RCD element retrieval tool&pull RCD element 07:15 07:45 0.50 1,076 1,076 INTRM2 CASING OWFF P OWFF-(static) 07:45 09:15 1.50 1,076 141 INTRM2 CASING TRIP P POOH on elevators on TT f/1,076'to 141'-F/C @ HWDP-(static) 09:15 11:15 2.00 141 0 INTRM2 CASING PULD P L/D BHA#6 as per SLB Calc Fill= 125.88 bbls/Act Fill= 141.5 bbls 11:15 14:00 2.75 0 0 INTRM2 CASING PULD P Clear BHA tools from rig floor-Clean rig floor-P/U tools to run 7"liner- R/U to run 7"liner-Monitor well on TT-(no gain/no loss) Page 19 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 20:15 6.25 0 2,466 INTRM2 CASING RNCS P PJSM-M/U 7"liner as per detail& RIH to 2,466'-Chk floats(good)-Fill every 10 jts-(Liner Detail; 8.25" Baker EZ Ream Shoe,XO,2 jts 7" 29#TN 110 H563 w/insert floats, 1 jt 7"29#TN 110 H563 w/insert collar,7 jts 7"29#TN 110 H563,XO,47 jts 7" 26#L80 Tenaris Blue, Flex Lock Hanger, RS Pack Off, HRD ZXP Packer w/Seal Bore Extension) 20:15 21:00 0.75 2,466 2,466 INTRM2 CASING RURD P C/O elevators&M/U liner hanger 21:00 21:45 0.75 2,466 2,466 INTRM2 CASING CIRC P Circ liner volume-Stage flow from 0.5 bpm to 4 bpm @ 40 psi over 5 min-SIMOPS, Baker mix PAL mix &wait on PAL mix f/30 min-L/D casing equipment 21:45 00:00 2.25 2,466 4,159 INTRM2 CASING RUNL P RIH f/2,466'to 4,159'w/5"DP from derrick-Fill pipe w/fill up hose every 10 stds 06/22/2014 Cont.to RIH w/7"liner on DP f/4,159'to 12,930'(TOW)-Fill pipe&establish rotating parameters-Run liner in open hole f/12,930'to 14,390' 00:00 17:30 17.50 4,159 12,933 INTRM2 CASING RUNL P Cont.to RIH w/7"liner on 5"DP from derrick f/4,159'to 12,933'-Fill pipe every 10 stds w/fill up hose 17:30 18:00 0.50 12,933 12,933 INTRM2 CASING RUNL P @ 12,933'(TOW@ 12,935')fill pipe &establish rotating parameters ROT wt 200 k 12 rpm @ 12 k trq/30 rpm @ 13 k trq SO wt160k 18:00 00:00 6.00 12,933 14,390 INTRM2 CASING RUNL P Cont.to RIH w/7"liner on 5"DP from derrick f/12,933'-(Rotated w/30 rpm @ 13 k trq through high DLS f/13,615 to 13,685'& 13,828'to 13,873')- Cont.to rotate liner to bottom w/30 rpm @ 13-15 k trq, 6- 10 wob f/13,982'to 14,390' 06/23/2014 Cont.to RIH liner to set depth of 15,220'-R/U cement head&circ&cond mud for cement job-Cement as per plan w/100%returns-Test lenr/packer to 1000 psi(good)-Displace to sea water 00:00 05:30 5.50 14,390 15,194 INTRM2 CASING RUNL P Cont.to rotate liner to bottom w/30- 40rpm@13- 15ktrq, 6-10wob f/14,390'to 15,194' 05:30 05:45 0.25 15,194 15,194 INTRM2 CASING RURD P R/U Baker rotating cement head& cement hoses Page 20 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 06:30 0.75 15,194 15,220 INTRM2 CASING RUNL P Cont. to rotate liner to bottom w/20 rpm @ 15 k trq, 6- 10 wob f/15,194' to 15,224'-Tag bottom w/3 k on wt indicator-P/U&space out to liner set depth of 15,220' P/U wt 290 k, SO wt 150 k, ROT wt 195 k Cal Disp 120.5 bbls/Act Disp 114 bbls 06:30 16:00 9.50 15,220 15,220 INTRM2 CEMEN-CIRC P Circ&cond mud for cement job cutting mud wt to 11.0 as per circ schedule(Initially break circ @ .5 bpm&stage up to 1.9 bpm-Initial circ psi 540 &final circ psi 640)- Circulated an open hole volume prior to rotating&reciprocating pipe& while cutting mud wt to 11.0 ppg& increase flow rate to 5 bpm-(Initial circ psi @ 1.9 bpm=660 psi&final circ psi @ 5 bpm =640 psi w/11.0 ppg mud)-Rotated& reciprocated pipe in 30 min intervals for 5 min 16:00 18:30 2.50 15,220 15,220 INTRM2 CEMEN-CMNT P PJSM for cement job-Dowell pump 5 bbls CW100&psi test to 4500 psi (good)-Dowell pump 45 bbls CW100 (50 bbls total), 50 bbls 12.5 ppg mud push, 165 bbls 15.8 ppg(799 Sks) (1.16 Yield)Qannik blend cement, kick out dart with 20 bbls H2O-Rig displace with 11.0 ppg LSND f/rig& bump plug w/2772 stks- Final circ psi @ 3 bpm =850 psi & increase to 1220 psi &hold for 5 min-CIP @ 18:26 hrs-Periodically reciprocated &rotated pipe during cement job w/100%returns 18:30 18:45 0.25 15,220 15,220 INTRM2 CEMEN PACK P Pressure up 2800 psi to shear&set liner hanger(SO to 60 k &confirm hanger set)-Pressure up to 4000 psi to release from hanger-Bleed of psi &check floats-(Rood)-Confirm released from liner&expose dog- SO f/155 k to 100 k&sheer @ 115 Down wt to set liner top packer (good) Shoe @ 15,220'/TOL @ 12,765.40' 18:45 19:30 0.75 15,220 15,220 INTRM2 CEMEN-PACK P R/D cement hose&cement head- Confirm packer set-(Rotate w/20 rpm @ 13 k trq, ROT wt 217 k @ set w/70 k Dwn wt to confirm-Line up on top dive&psi to 850 psi POOH until pressure bleed off to 350 psi- Stage flow rate to 10 bpm&clear cement from top of liner Page 21 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 21:00 1.50 15,220 15,220 INTRM2 CEMEN-CIRC P Circ B/U w/14 bpm @ 1700 psi- Reciprocate pipe-+/- 10 bbls cement back to surface 21:00 21:30 0.50 15,220 15,220 INTRM2 CEMEN-PRTS P Line up on kill line&test packer& liner to 1000 psi&chart for 10 min (good)-D/D kill line-PJSM for displace to sea water 21:30 00:00 2.50 15,220 15,220 INTRM2 CEMEN CIRC P L/D single jt-Pump 34 bbls high vis spacer&displace to sea water w/9 bpm @ 1180 psi 36/24/2014 Cont.to circ&displace to sea water-POOH while laying down 5"DP-LID liner running tools-RIH remaining 5"DP in derrick&POOH L./D same. RU 7"Csg tools and run tie-back. 00:00 00:15 0.25 12,754 12,754 INTRM2 CEMEN-DISP P Continue to displace to 8.3 ppg sea water w/9 bpm © 1180 psi until shakers clean, PU=290K, SO= 160K 00:15 01:00 0.75 12,754 12,754 INTRM2 CEMEN OWFF P Flow chk for 30 min-static. Blow down TD. 01:00 05:00 4.00 12,754 9,008 INTRM2 CEMEN"PULD P POOH on Trip tank laying down 5" DP from 12,754'to 9,008'(40 stds). 05:00 05:30 0.50 12,754 9,008 INTRM2 CEMEN SVRG P Lubricate rig, IR and draworks.Work on hydraulic line under rig floor. 05:30 06:00 0.50 9,008 9,008 INTRM2 CEMEN'SVRG T Continue to work on hydraulic line under rig floor. 06:00 06:15 0.25 9,008 9,008 INTRM2 CEMEN-SFTY P PJSM on POOH 06:15 12:00 5.75 9,008 3,536 INTRM2 CEMEN-PULD P Continue POOH on Trip tank laying down 5"DP from 9,008'to 3,536'(99 stds). 12:00 14:45 2.75 3,536 0 INTRM2 CEMEN-PULD P Continue POOH on Trip tank laying down 5"DP from 3,536'to surface (36 stds). 14:45 15:30 0.75 3,536 0 INTRM2 CEMEN-PULD P Inspect, breakout and LD liner running tool. Close blind rams 15:30 17:45 2.25 0 2,600 INTRM2 CEMEN TRIP P RIH with 5" HWDP(5 stds)and 5" DP(23 stds). from derrick to 2,600' md. LD drilling jars. 17:45 18:45 1.00 2,600 2,600 INTRM2 CEMEN-PULD P PJSM. Slip and cut 60'of drill line. 18:45 19:15 0.50 2,600 2,600 INTRM2 CEMEN-SVRG P Service TD and draworks. 19:15 21:45 2.50 2,600 0 INTRM2 CEMEN-PULD P POOH laying down 5"DP and 5 stds of 5"HWDP 21:45 22:15 0.50 0 0 INTRM2 CEMEN-RURD P Drain stack, PJSM. MU running tool and pull WB. 22:15 22:45 0.50 0 0 INTRM2 CEMEN-RURD P PU Landing Jt and 7"Csg Hngr. Make dry run with Hngr and mark Landing Jt. 22:45 00:00 1.25 0 0 INTRM2 CEMEN RURD P RU casing equipment for 7"tie-back -350 ton Slips, 250 ton Side door elevators, false floor (for SDL runs) and double stack power tongs. 36/25/2014 Continue to run 7"tie-back casing, Sting in and locate in seal assembly. Press test annulus to 1,000 psi, un-stin and reverse in with seawater and diesel frz protect. land csg,set pack-off and test to 5,000 psi. 00:00 00:30 0.50 0 0 INTRM2 CEMEN-RURD P Continue to RU casing equipment for 7"tie-back- false floor (for SDL runs)and double stack power tongs. Page 22 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 00:45 0.25 0 0 INTRM2 CEMEN-SFTY IP PJSM for running 7"casing tie-back. 00:45 12:00 11.25 0 9,583 INTRM2 CEMEN-RNCS P RIH with Tie-back seal assembly with locator sub, 295 jts of 7",26 lb/ft, L-80, BTC-M, R3 casing with torque rings installed. MU TQ= 14,000 ft-lb with Jet Lube Run N Seal thread dope to 9,583'(225 jts total). 12:00 15:15 3.25 9,583 12,724 INTRM2 CEMEN RNCS P Continue to RIH with 7"csg Tie-back from 9,583'to 12,724'(294 jts total). 15:15 15:45 0.50 12,724 12,724 INTRM2 CEMEN RURD P RU circulating swedge, swing and valve. Remove casing spiders. 15:45 16:30 0.75 12,724 12,780 INTRM2 CEMEN'RNCS P Wash down at 2.5 bbl/min, 20 psi. PU=310K, SO= 158K. Slack off as pressure increased from 20-40 psi. Shut down pumps and bleed off press and locate NO-Go at 12,780' md. 16:30 17:00 0.50 12,724 12,780 INTRM2 CEMEN PRTS P Pressure test annulus to 1,000 psi and hold for 10 min-good. RD test equip. 17:00 17:45 0.75 12,780 12,657 INTRM2 CEMEN RURD P RD swedge and LD 3 Jts of 7" casing. 17:45 18:45 1.00 12,780 12,742 INTRM2 CEMEN-HOSO P PU/MU 7.82'and 7.80'space out pups, PU jt#295, MU 7"csg hanger and Landing Jt, install circ swedge. 18:45 19:00 0.25 12,742 12,760 INTRM2 CEMEN-CIRC P Position seal assembly above liner top, at 12, 760' md. Break circ to confirm seals are not engaged. 19:00 19:30 0.50 12,760 12,760 INTRM2 CEMEN-RURD P Line up manifold and lines to reverse circulate down annulus. Close Annular preventer and reduce closing pressure to 500 psi. Hold PJSM for displacement and freeze protecting annulus. 19:30 22:00 2.50 12,760 12,760 INTRM2 CEMEN DISP P Pressure test lines to 2,500 psi. Use rig pumps to displace annulus with 308 bbl of seawater at 4 bpm, 390 psi. Switch to cement pump and pump 170 bbl of diesel freeze protect at 4 bpm and 576 psi. Shut down pumps. 22:00 22:15 0.25 12,760 12,776 INTRM2 CEMEN HOSO P Strip thru Annular and land casing on hanger at 12, 776'md. 22:15 23:00 0.75 12,776 12,776 INTRM2 CEMEN OTHR P Bleed off pressure, open Annular preventer,drain stack, flush lines to tote. 23:00 00:00 1.00 12,776 12,776 INTRM2 CEMEN-WWSP P PU test joint and MU 7"pack-off. Set packoff, RILDS and test to 5,000 psi for 10 min-good. 06/26/2014 RU and test annulus to 2,500 psi and chart. PU/MU 4" DP and rack back(53 stds). RU test equipment and test BOPs wit 3-1/2",4"and 4-1/2"test joints. .Test IBOP in TD, continue to PU 4" DP. Test witnessed by Mr Chuck Scheve of the AOGCC 00:00 02:45 2.75 12,776 0 INTRM2 CEMEN'PRTS P RU and test 7"x 9-5/8"x 13-3/8"OA to 2,500 psi and chart on recorder for 30 min-good. RD test equip. Page 23 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:45 03:00 0.25 0 0 INTRM2 CEMEN-SFTY P PJSM on PU and rack back 4"DP. Monitor well on Trip tank-zero gain/ loss. 03:00 09:00 6.00 0 0 INTRM2 CEMEN-PULD P PU and rack back 54 stands of 4", 14 lb/ft,XT-39, S-135 DP. Monitor well on Trip tank-zero gain/loss. 09:00 11:30 2.50 0 0 INTRM2 WHDBO RURD P PJSM. Change out Upper Pipe Rams from 4.5"x 7"to 3.5"x 6"VBRs. Change out TD Saver sub from 4.5" DS-50 to 4".XT-39. PU 3.5"FOSV and Dart valves via the Otter slide. _ Monitor well on TT-zero-gain/loss. 11:30 12:00 0.50 0 0 INTRM2 WHDBO RURD P RU test and recording equipment for BOPE test. Drain stack, set test plug and 4"test joint. Fill stack, Choke/Kill lines and Choke manifold with water. 12:00 13:15 1.25 0 0 INTRM2 WHDBO RURD P Continue RU test and recording equipment for BOPE test,fill lines with water and work air out of system. 13:15 19:30 6.25 0 0 INTRM2 WHDBO BOPE P Test BOPE with 4"test jt-Annular to 250/2500 and chart for 5 min. Test choke manifold valves 1 -16, upper pipe rams(3.5"x 6"), lower pipe rams 3-1/2"x 6"VBRs, needle valve, auto IBOP, HCR Choke and Kill, 4" dart and FOSV, 3.5"dart and FOSV valves, Blind rams to 250/3,500 psi and chart for 5 min ea. Test with 3.5"test jt-Annular to 250/2500 and chart for 5 min.Test, upper pipe rams(3.5"x 6"), lower pipe rams 3-1/2"x 6"VBRs to 250/3,500 psi and chart for 5 min ea. Test with 4.5" test jt-Annular to 250/2500 and chart for 5 min. Test, upper pipe rams(3.5" x 6"), lower pipe rams 3-1/2"x 6" VBRs to 250/3,500 psi and chart for 5 min ea. Test rig gas alarms- Accumulator test, 3,000 psi, 1,400 psi in 38 sec, 194 sec to full system pressure.4 bottles nitrogen at 2,000 psi. Perform Drawdown test on Super and manual choke. Test Rig gas alarms. All tests were good. Test witnessed by Mr. Chuck Scheve of the AOGCC. 19:30 20:00 0.50 0 0 INTRM2 WHDBO RURD P RD test equip. Pull test plug, drain stack and set wear ring. 20:00 20:30 0.50 0 0 INTRM2 WHDBO RURD P Blow down Choke manifold, Choke and Kill lines and TD. 20:30 21:00 0.50 0 0 INTRM2 WHDBO RURD P RU and test Lower(manual) IBOP to 250/3,500 psi for 5 min each. Page24of77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 22:30 1.50 0 I 0 INTRM2 CEMEN-PULD P Blow down TD. PU and rack back 11 stands of 4", 14 lb/ft,XT-39, S-135 DP. Monitor well on Trip tank- zero gain/loss. 22:30 23:00 0.50 0 0 INTRM2 CEMEN-SVRG P Service TD, IR and Draworks. 23:00 00:00 1.00 0 0 INTRM2 CEMEN PULD P PU and rack back 8 stands of 4", 14 lb/ft,XT-39, S-135 DP. Monitor well on Trip tank-zero gain/loss. 06/27/2014 Finish PU 4" DP, MU PowerDrive BHA and single in hole with 3-1/2"DP. 00:00 01:45 1.75 0 0 INTRM2 CEMEN PULD P PU and rack back 15 stands of 4", 14 lb/ft,XT-39, S-135 DP(88 stds of 4"DP-total). Monitor well on Trip tank-zero gain/loss. 01:45 02:15 0.50 0 0 INTRM2 CEMEN RURD P RU bell guide on TD, RU pipe skate roller, PU MWD/LWD tools to rig floor. 02:15 05:00 2.75 0 289 INTRM2 CEMEN PULD P PJSM. MU PowerDrive BHA#7 to 289' 05:00 07:00 2.00 289 1,525 INTRM2 CEMEN PULD P Single in, picking up 3-1/2", 13.3 lb/ft, S-135,XT-38 DP to 1,525'md. PU=S0=80K lb. 07:00 08:00 1.00 1,525 1,525 INTRM2 CEMEN DHEQ P Shallow pulse test MWD with 160 gpm and 780 psi-good test. Test Circ sub-drop 1.75"steel activation ball and pump down at 2 bpm until on seat. Pressure up to 1,610 psi and shear open.After open pump at 160 gpm with 60 psi. Drop 1.75" de-activation ball and pump down with 2 bpm until on seat. Increase pressure and shear circ sub closed with 1,620 psi. Circulate at 160 gpm and 780 psi-good test. 08:00 12:00 4.00 1,525 4,854 INTRM2 CEMEN PULD P Single in, picking up 3-1/2", 13.3 lb/ft, S-135,XT-38 DP from 1,525'to 4,854'md. PU= 110, SO=92K lb. Note: OA=0 psi 12:00 15:30 3.50 4,854 7,422 INTRM2 CEMEN PULD P Single in, picking up 3-1/2" DP from 4,854'to 7,422'md. 15:30 15:45 0.25 7,442 7,422 INTRM2 CEMEN RURD P LD MPD tools and equip 15:45 00:00 8.25 7,422 14,554 INTRM2 CEMEN'PULD P Single in, picking up 3-1/2" DP from 7,422'to 14,554'md. PU=190K, SO=215K,TQ off=7-8K Kick While Trip Drill-CRT:210 sec OA=0 psi SPRs at 14,554'md, 2355 hrs MP#2 15=420, 25=810 psi 06/28/2014 Finish RIH and tag TOC.Test casing to 3,500 psi, slip and cut DL, open circ sub and displace well to MOBM, close circ sub,test MPD equip, drill out shoe track and 20', perform LOT, re-install MPD element,drill ahead 6-1/8"production hole. Page 25 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 14,554 14,939 INTRM2 CEMEN'PULD P Change out elevators from 3-1/2"to 4". Install XO and RIH from 14,554 to 14,939'md. 00:30 01:45 1.25 14,939 15,109 INTRM2 CEMEN"WASH P Wash and ream from 14,939 to 15,109'md, 160 gpm, 1,720 psi,30 rpm and 7-8K TQ. Tag up on TOC with 20K lb. PU= 190K, S0= 110K, ROT= 150K. SPRs at 15,109'md, 0053 hrs MP#2 15=450, 25=810 psi 01:45 02:00 0.25 15,109 15,032 INTRM2 CEMEN-CIRC P Pump OOH to15,032'with 160 gpm and 1720 psi, 7.5K TQ.. Rack back one std. 02:00 03:30 1.50 15,032 15,032 INTRM2 CEMEN-PRTS P RU test equipment. Test 7"casing to 3,500 psi, hold and chart for 30 min-good test. Blow down lines and RD test equip. Drop 1.75"steel activation ball and allow to free fall to top of Circ sub. 03:30 03:45 0.25 15,032 15,032 INTRM2 CEMEN-SFTY P PJSM on Cut and Slip DL. 03:45 05:15 1.50 15,032 15,032 INTRM2 CEMEN'SLPC P Slip and cut 53'of drill line. Service TD,draworks, Iron roughneck, adjust brakes. Work on Mud pump#2,TD and draworks. 05:15 05:30 0.25 15,032 15,032 INTRM2 CEMEN-CIRCP Pump at 2 bpm and pressure up to 1,600 psi and open Circ sub. Stage _ pump up to 160 gpm and 1,110 psi 05:30 05:45 0.25 15,032 15,032 INTRM2 CEMEN'SFTY P PJSM on displacing well to 9.4 ppg MOBM. 05:45 06:00 0.25 15,032 15,108 INTRM2 CEMEN-CIRC P Reciprocate pipe and circulate at 212 gpm, 1,840 psi, 30 rpm, 8K TQ. 06:00 07:45 1.75 15,108 15,108 INTRM2 CEMEN-DISP P Displace well from seawater to 9.4 ppg, MOBM. Pump 38 bbl Hi-Vis MOBM spacer at 212 gpm, 1,800 psi. Continue pumping until clean MOBM returned to pits, staging pumps up from 212 to 294 gpm, 1,800-3,840 psi. Reduce pump rate and C&C with 160 gpm, 1,250 psi. 07:45 08:00 0.25 15,108 15,001 INTRM2 CEMEN-CIRCP POOH to 15,001'. Drop 1.75" de-activation ball and allow to free fall to top of Circ sub. 08:00 09:15 1.25 15,001 15,001 INTRM2 CEMEN RURD P PJSM. RU XOs and MPD sealing element set/retrieve tool in mouse hole with element for 4"DP installed. RIH and set 5K lb down on RCD head. Clamp in element and pull test to 20K-good. Page 26 of 77 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:15 10:00 0.75 15,001 15,001 INTRM2 CEMEN-CIRC P Pump deactivation ball down with 2 bpm, 350 psi.When ball on seat, pressure up to 1,300 psi and close Circ sub. Establish MPD baseline/fingerprint-pumping with160 gpm, 2,040 psi. Stage pups up to 195 gpm, 2,960-3,040 psi and calibrate MPD chokes. (MPD held 176-123 back pressure with pumps on, 510-393 psi back pressure with pumps off). 10:00 11:00 1.00 15,001 15,001 INTRM2 CEMEN"CIRC P Perform Dynamic Equalization procedure,equalizing pressure between wellbore and Annular preventer after element c/o with 350 psi. 11:00 11:30 0.50 15,001 15,097 INTRM2 CEMEN TRIP P RIH to 15,097'. Blow down Kill line. 11:30 11:45 0.25 15,001 15,097 INTRM2 CEMEN SFTY P SPRs at 15,097'and MP#1 15=420, 25=820 psi 11:45 12:00 0.25 15,097 15,109 INTRM2 CEMEN-WASHP Wash and ream to 15,109'with 160 gpm, 2,060 psi,40 rpm, 7K TQ. 12:00 12:30 0.50 15,109 15,207 INTRM2 CEMEN-DRLG P Clean out shoe track to 15,207'with 160 gpm, 2,100 psi, 60 rpm, 7-8K TQ, 3-5K WOB 12:30 16:45 4.25 15,207 15,225 INTRM2 CEMEN DRLG P Drill out cement shoe trackto15,225' with 160 gpm,2,100 psi, 70 rpm, 7-8K TQ, 3-10K WOB 16:45 17:00 0.25 15,225 15,244 INTRM2 CEMEN-DRLG P Drill out rathole and 20'of new formation to 15,244'and with 160 gpm, 2,100 psi, 70 rpm, 7-8K TQ, 3-10K WOB. 17:00 18:45 1.75 15,244 15,244 INTRM2 CEMEN-CIRC P C&C mud for LOT while reciprocating pipe. Circ at 195 gpm, 3,000 psi, 70 rpm, 7-8K TQ 18:45 19:15 0.50 15,244 15,244 INTRM2 CEMEN-OWFF P Flow chk well-static. PJSM for LOT 19:15 20:15 1.00 15,244 15,244 INTRM2 CEMEN-LOT P RU test equip. Perform LOT with 9.4 ppg MOBM to 14.9 ppg EMW. Blow down line and RD test equip. 20:15 21:15 1.00 15,244 15,244 INTRM2 CEMEN-RURD P PU MPD element and running tool and set in RCD head. POOH and LD running tool. 21:15 23:30 2.25 15,244 15,365 PROD1 DRILL DDRL P Drill ahead from 15,244'to 15,365' and with 195 gpm, 2,980 psi, 80 rpm and 7-8K TQ, holding 50 psi back pressure at connections. Total footage= 121'. Intermittent surface signal decoding errors. PU=295K, S0= 125K, ROT= 149K, TQ on/off=9K/7K ft-lb ADT= 1.9 hrs,TVD=7,505' 23:30 00:00 0.50 15,244 15,365 PROD1 DRILL CIRC T Pump with 195 gpm, 2,980 psi,80 rpm and 7K TQ while diagnosing surface signal decoding problems. Page 27 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/29/2014 24 hr Summary Drill ahead 6-1/8"production hole. Footage= 1,326' 00:00 00:15 0.25 15,365 15,365 PROD1 DRILL CIRC T Continue to pump with 195 gpm, 2,980 psi, 80 rpm and 7K TQ while diagnosing surface signal decoding problems. 00:15 00:30 0.25 15,365 15,391 PROD1 DRILL DDRL T Drill from 15,365'to 15,391'. 00:30 00:45 0.25 15,391 15,391 PROD1 DRILL CIRC T Continue to pump with 195 gpm, 2,980 psi,80 rpm and 7K TQ while troubleshooting signal decoding problems. 00:45 01:15 0.50 15,391 15,391 PROD1 DRILL DLOG T Re-log hole section from 15,360'to 15,391'at 100'-150'/hr with 190 gpm, 2,990 psi, 80 rpm, 7K TQ. 01:15 07:45 6.50 15,391 15,767 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/15,391'to 15,767'and ECD-10.49 ppg,WOB 10/12 K, RPM 80-110, GPM 190,2,940 psi String wt-PU 205 SO 105 ROT 145 Torque on/off btm.- 10/9.5K ft-lbs 07:45 08:30 0.75 15,767 15,620 PROD1 DRILL REAM P Backream thru dogleg/shale section with 110 rpm, 9-8.5K TQ, 190 gpm, 2,930 psi 08:30 09:15 0.75 15,620 15,767 PROD1 DRILL REAM P Ream back down thru dogleg/shale sect with 110 rpm, 8.5K TQ, 170 gpm,2,500 psi. C&C mud. 09:15 12:00 2.75 15,767 15,966 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/15,767'to 15,966'md,TVD=7,506' ECD- 10.55 ppg,WOB 8/10 K, RPM 110-120, GPM 190, 2,980 psi String wt-PU 205 SO 105 ROT 145 Torque on/off btm.-10/9.5K ft-lbs ADT=6.86 hr SPRs at 15,789'md, 1030 hrs MP#1 15=910, 25= 1,060 psi MP#2 15=960, 25= 1,100 psi Note: OA=750 psi @ 1030 hrs 12:00 00:00 12.00 15,966 16,691 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/15,966'to 16,661'md, TVD=7,514' ECD- 10.57 ppg,WOB 5/12 K, RPM 110, GPM 190, 3,000 psi String wt-PU 215 SO 103 ROT 150 Torque on/off btm.-11.5/11.6K ft-lbs ADT=8.31 hr SPRs at 16,640'md, 2300 hrs MP#1 15=910, 25= 1,190 psi MP#2 15=910, 25= 1,160 psi Note: OA=920 psi @ 2345 hrs Page 28 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 36/30/2014 24 hr Summary Drill ahead 6-1/8"production hole to 17,150'. Trouble shoot down linking to MWD tools. Drill ahead to 17,207'md. Footage=516' Note: Crossed fault at+/-17,147'and (faulted down into the"B"sand). 00:00 07:15 7.25 16,691 17,029 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/16,691'to 17,029'md,TVD=7,519' 07:15 10:00 2.75 17,029 17,029 PROD1 DRILL DRLG T Attempt to downlink to MWD-no good. Trouble shoot downlinks to RSS tools with 190 gpm,2,980 psi, 100 rpm, 9K TQ. ECD= 10.57- 10.40 ppg. Observed pit gain while downlinking, back pressure dropped below breathing pressure. 10:00 12:00 2.00 17,029 17,113 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/17,029'to 17,113'md,TVD=7,520' ECD-10.47 ppg,WOB 10/15 K, RPM 120, GPM 190,2,950 psi String wt-PU 210 SO 108 ROT 150 Torque on/off btm-11.0/9.5K ft-lb ADT=8.31 hr SPRs at 16,640'md, 2300 hrs MP#1 15= 920, 25= 1,160 psi MP#2 15= 1,010, 25= 1,180 psi Note: OA=970 psi @ 1145 hrs Kick While Drlg drill @ 1120 hrs 12:00 13:15 1.25 17,113 17,150 PROD1 DRILL DDRL P Drill 6-1/8' hole with RSS-Periscope f/17,113'to 17,150'md, TVD=7,520' ECD- 10.46 ppg,WOB 10/15 K, RPM 120, GPM 190, 3,000 psi 13:15 15:00 1.75 17,150 17,150 PROD1 DRILL CIRC T Circ gas out of well(Max gas= 9,000+units),with 190 gpm,2,930 psi, 120 rpm, 8.8K TQ. 15:00 15:30 0.50 17,150 17,150 PROD1 DRILL CIRC P Shut down pumps.Trap 10.2 EMW, pressure dropping,drop EMW to breathing pressure of 9.95 EMW. Same as has been. 15:30 22:45 7.25 17,150 17,150 PROD1 DRILL CIRC T Attempt to downlink to MWD-no good. Trouble shoot downlinks to RSS tools with 190 gpm,2,930 psi, 120 rpm, 8.8K TQ. Made multiple attempts with increasing differential flow,downhole. Page 29 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:45 00:00 1.25 17,150 17,207 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/17,150'to 17,207'md, TVD=7,522' ADT= 1.08 hr ECD- 10.54 ppg WOB 5/16K RPM 90-120, GPM 195,2,960 psi TOTAL TOUR LOSSES=23 bbl Strng wt-PU 208 SO 105 ROT 150 Torque on/off btm.- 10.5/9.5K ft-lb SPRs at 16,640'md, 2400 hrs MP#1 15= 920, 25= 1,150 psi MP#2 15= 1,000, 25= 1,170 psi Note: OA= 1,070 psi @ 2345 hrs Held Kick While Drig-table top drill @ 2320 hrs 07/01/2014 Drill ahead 6-1/8"production hole to 17,759'md. Attempt to downlink to RSS tools-no good. Increase MW from 9.2 to 9.4 ppg, circ out excess gas and C&C mud with 3X bottoms up. 00:00 01:00 1.00 17,207 17,207 PROD1 DRILL CIRC T Circ gas out of well(Max gas=8,040 units),with 190 gpm,2,970 psi, 900 rpm,8.5K TQ. Swap pumps and downlink to RSS tool-good 01:00 01:30 0.50 17,207 17,207 PROD1 DRILL OWFF T Perform Dynamic flow check using MPD equipment and Pit#5. Open chokes with 190 gpm in and 206 gpm out at 2,950 psi, 10.35 ECD and 121.5 bbl at start, in pit#5. At the end of test pumping at 191 gpm in and 209 gpm out with 2,930 psi, 10.28 ECD and 128.5 bbl in pit#5. Gained 4 bbl in first 15 min and decreased to 3 bbl total for second 15 minutes, indicating hole was breathing back. 01:30 12:00 10.50 17,207 17,585 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/17,207'to 17,585'md,TVD=7,534' ECD-10.62 ppg,WOB 8/12 K, RPM 120, GPM 190, 3,040 psi String wt-PU 210 SO 100 ROT 145 Torque on/off btm-10.5/9.5K ft-lb ADT=4.16 hr SPRs at 17,585'md, 1115 hrs MP#1 15= 960, 25= 1,190 psi MP#2 15= 940, 25= 1,190 psi Note: OA= 1,100 psi @ 0700 hrs, bled to 850 psi Page 30 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 17:00 5.00 17,585 17,759 PROD1 DRILL DDRL P Drill 6-1/8' hole with RSS-Periscope f/17,585'to 17,759'md, TVD=7,539' ECD- 10.48 ppg,WOB 5/15 K, RPM 90-120, GPM 190,2,980 psi String wt-PU 210 SO 100 ROT 145 Torque on/off btm-10.5/9.0K ft-lb ADT= 1.84 hr SPRs at 17,759'md, 2400 hrs MP#1 15= 800, 25= 1,130 psi MP#2 15= 800, 25= 1,320 psi Note: OA=900 psi @ 2230 hrs 17:00 20:00 3.00 17,759 17,759 PROD1 DRILL CIRC T Attempt to downlink to MWD with 130-190 gpm, 2,000-2,980 psi, 40-120 rpm, 7-10.5K TQ-no good. 20:00 00:00 4.00 17,759 17,759 PROD1 DRILL CIRC T Increase MW of MOBM from 9.2 to 9.4 ppg. During weight up, circ gas out of well (Max gas=9,988 units), with 190 gpm, 2,950 psi, 90 rpm, 9K TO. Total losses for tour= 16 bbl 07/02/2014 Finish C&C mud. Downlinking worked better with conditioned mud, Drill ahead to 18,275' 00:00 01:30 1.50 17,759 17,759 PROD1 DRILL CIRC T C&C mud increasing MW for trip, with 190 gpm, 2,910 psi, 90 rpm, 9.5-10.0K TQ. Attempt to downlink 3x-good. Confer with town and prep to resume drilling. 01:30 04:00 2.50 17,759 17,720 PROD1 DRILL CIRC T C&C mud,decreasing MW back to 9.4 ppg,with 190 gpm,2,910 psi, 90 rpm, 9.5-10.0K TQ. Made 6 of 7 needed downlinks while C&C mud to set up toolface for drilling. Final downlink was done with a 20 minute downlink. 04:00 04:30 0.50 17,720 17,759 PROD1 DRILL REAM P Wash and ream back to btm with 190 gpm, 3,180 psi, 120 rpm, 9.5K TQ. Packing off at 17,739'and 17,741'with erratic torque to 12K and pressure to 3,270 psi. 04:30 05:15 0.75 17,759 17,774 PROD1 DRILL DDRL P Drill stand down from 17,759 to 17,774 while hole trying to pack off. 05:15 06:00 0.75 17,774 17,774 PROD1 DRILL CIRC P C&C with 120 rpm, 9.5-10.0K TQ, 190-140 gpm,2,990-1,870 psi waiting for MWin=MWout to make connection with MPD equip. Work pipe while circulating. Page 31 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:30 2.50 17,774 17,774 PROD1 DRILL CIRC T Hole pack-off at 17,774-38'with TQ increasing to 13K ft-lb from 10.5K, pressure up to 3,200 psi from 2,990 psi,with 190 gpm. Reduce flowrate and work pipe up/down and pressure dropped from 2,070 to 1,870 psi. Stage flowrate up to 190 gpm and 3,000 psi, 120 rpm, 9.5- 10K TQ and reciprocate pipe from 17,720 to 17,680'. 08:30 09:45 1.25 17,774 17,720 PROD1 DRILL CIRC T Ream thru tight spots from 17,720' to 17,774'with 120 rpm, 9-14K TQ, 190-140 gpm, 3,000- 1,870 psi. Had multiple pack-offs(+/-150 psi)from 17,736'to 17,720'. 09:45 10:00 0.25 17,720 17,774 PROD1 DRILL CIRC P C&C mud with 190 gpm, 3,000 psi, 90 rpm, 9-10K TQ. Downlink-good. Wash and ream to btm. 10:00 12:00 2.00 17,774 17,830 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/17,774'to 17,830'md, TVD=7,540' ECD-10.75 ppg,WOB 10/12 K, RPM 120, GPM 190, 3,040 psi String wt-PU 218 SO 99 ROT 150 Torque on/off btm- 11.0/9.5K ft-lb ADT=2.66 hr SPRs at 17,774'md, 0545 hrs MP#1 15= 850, 25= 1,070 psi MP#2 15= 830, 25= 1,090 psi Note: OA=890 psi @ 0815 hr Tour losses= 110 bbl 12:00 00:00 12.00 17,830 18,275 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/17,830'to 18,275'md, TVD=7,539' ECD-10.75 ppg,WOB 10/12 K, RPM 120, GPM 190, 3,040 psi String wt-PU 225 SO 100 ROT 150 Torque on/off btm-11.0/9.0K ft-lb ADT=4.94 hr SPRs at 18,154'md, 2115 hrs MP#1 15= 920, 25= 1,170 psi MP#2 15= 930, 25= 1,360 psi Note: OA=870 psi @ 1130 hr Tour losses=62 bbl 07/03/2014 Drill ahead 6-1/8"production hole to 19,286' Footage= 1,011' Page 32 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 18,275 18,626 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/18,275'to 18,626'md,TVD=7,546' ECD- 10.79 ppg,WOB 8/18 K, RPM 120, GPM 188, 2,970 psi String wt-PU 215 SO 102 ROT 150 Torque on/off btm-10.5/9.0K ft-lb ADT=4.55 hr SPRs at 18,154'md, 2115 hrs MP#1 15= 920, 25= 1,160 psi MP#2 15= 920, 25= 1,200 psi Note: OA=885 psi @ 0945 hr Tour losses=36 bbl 12:00 00:00 12.00 18,626 19,286 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/18,626'to 19,286'md,TVD=7,552' ECD-10.90 ppg,WOB 6/18 K, RPM 100-120, GPM 192, 3,200 psi String wt-PU 215 SO 102 ROT 150 Torque on/off btm-11.5/9.0K ft-lb ADT=7.34 hr SPRs at 19,192'md, 2230 hrs MP#1 15= 940, 25= 1,290 psi MP#2 15= 920, 25= 1,170 psi Tour losses=46 bbl 37/04/2014 Drill ahead 6-1/8"production hole to 19,947' Footage=661' MWD quit responding, lost 200 psi in pump pressure.Trouble shoot and attempt to restart MWD. CBU to trip for new BHA. 00:00 12:00 12.00 19,286 19,733 PROD1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/19,286'to 19,733' md, TVD=7,553' ECD-11.15 ppg,WOB 8/14 K, RPM 120, GPM 192, 3,250 psi String wt-PU 210 SO 97 ROT 150 Torque on/off btm-11.5/9.0K ft-lb ADT=6.46 hr Note: Increasing MW to 9.5 ppg, so no SPRs taken. Tour losses=56 bbl Page 33 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 21:30 9.50 19,773 19,947 PROD1 1 DRILL DDRL P Drill 6-1/8'hole with RSS-Periscope f/19,773'to 19,947'md, TVD=7,553' ECD- 11.11 ppg,WOB 8/18 K, RPM 120, GPM 192, 3,200 psi String wt-PU 220 SO 95 ROT 148 Torque on/off btm-11.5/9.5K ft-lb ADT=5.72 hr SPRs at 19,750'md, 1300 hrs MP#1 15= 790, 25= 1,170 psi MP#2 15= 970, 25= 1,170 psi Note: OA=940 psi @ 2345 hr Tour losses=58 bbl 21:30 00:00 2.50 19,947 19,947 PROD1 DRILL CIRC T C&C mud,trouble shooting MWD, with 160-190 gpm, 2,500-3,150 psi, 90-120 rpm, 9.5K TQ. No response from tools. Note:Tools turned back on at 00:30 hours, after recycling the pumps multiple times. 07/05/2014 Finish CBU and trouble shooting BHA. MWD restarted. Drill ahead 6-1/8"hole. Lost communication to RSS and LWD.Work pipe past tight spots near TD, BROOH. Lost all power to rig, restart. CBU and check for gas. BROOH with tight spots at 19,720 and 18,235-30. 00:00 01:45 1.75 19,947 19,947 PROD1 DRILL CIRC T No signal from MWD. Cycle pump, ttrouble shoot MWD,with 160-190 gpm,2,500-3,150 psi, 90-120 rpm, 9.5K TQ. Pump low vis sweep and perform anti-jamming procedure. Regained MWD signal but not Periscope and Powerdrive(LWD and RSS). Decided not enough data to drill ahead. Recyled pump to take a survey at TD and regained full communication. 01:45 06:30 4.75 19,947 20,050 PROD1 DRILL DDRL P Drill one stand down f/19,947'to 20,050'and and lost all communication with tools, except the MWD. TVD=7,560', ECD- 11.0 ppg,WOB 7K, RPM 120, GPM 200,3,440 psi String wt-PU 220 SO 95 ROT 148 Torque on/off btm-11.5/9.5K ft-lb ADT= 1.77 hr Tour losses=44 bbl Page 34 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 14:00 7.50 20,050 19,960 PROD1 DRILL REAM T Work tight hole from 20,040 to 19,960' Rotate 90 rpm and circulate 190gpm 3,260psi pack-off events when back reaming from 19,980 to 19,960 Circulate 3 B/U while attempting to clean up bottom of the hole. 14:00 15:00 1.00 19,960 19,960 PROD1 DRILL OWFF T Perform a Dynamic flow check with 9.5ppg mud in hole: Hold 350 psi for 10 minutes no gains or losses Hold 300 psi for 10 minutes no gains or losses Hold 250 psi for 10 minutes no gains or losses 15:00 16:30 1.50 19,960 19,474 PROD1 DRILL REAM T Begin back reaming from 19,960 to 19,379 out of the hole at 120 rpm 190 gpm 3200 ps ati 600 ft/hr. No pack off events. Monitor gains and losses isolated to pit#5 16:30 17:00 0.50 19,474 19,474 PROD1 DRILL RGRP T Lost all power when main breaker feeding rig tripped due to a short in SCR#1. Isolated MPD chokes to trap pressure.After regaining power initiated circulation to bring ECD's back up. Total pump down time approx. 5 minutes. 17:00 19:00 2.00 19,474 19,474 PROD1 DRILL CIRC T Precautionary CBU due to lost MPD back pressure at 190 gpm, 2,960 psi,90 rpm, 9.5K Max gas=7,790 units 19:00 00:00 5.00 19,474 18,248 PROD1 DRILL REAM T Begin back reaming from 19,474 to 18,248 out of the hole at 90 rpm 150 gpm 1,990 psi, 90 rpm, 9-10.5K TQ, pulling at 600 ft/hr and 150'/hr thru tight spots. (Hole packing off from 18,270'to 18,230') Monitor gains and losses isolated to pit#5 Tour losses=50 bbl 07/06/2014 BROOH working thru tight spots. Increase MW from 9.5 to 9.8 ppg. BROOH to inside shoe, CBU 3X,wash down to 15,500' 00:00 02:15 2.25 18,248 18,230 PROD1 DRILL REAM T Continue back reaming from 18,248 to 18,230 out of the hole at 120 rpm 190 gpm 3,000 psi at 600 ft/hr. No pack off events. Monitor gains and losses, isolated to pit#5 Page 35 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 08:30 6.25 18,230 17,683 PROD1 DRILL REAM T Hole packing off from 18,230 to 17,730 90 rpm 150 gpm 1,980 psi, 90 rpm, 9-10.5K TO, pulling at 150'/hr thru tight spots. Rotary stalled out, lost returns,worked down and up until able to pass with full rotary rpm, pump rate and returns. Hole section is transition into Alpine "B"section and out Monitor gains and losses, isolated to pit#5 Losses while working tight spots= 50 bbl 08:30 11:30 3.00 17,683 17,683 PROD1 DRILL CIRC T Weight up system at 17,683'to 9.8ppg. Rotate pipe at 120rpm 8.8k tq pump 190gpm on the upstroke and 150gpm on the down stroke. 50%siltstone coming over the shakers. 11:30 12:00 0.50 17,683 17,490 PROD1 DRILL REAM T Continue back reaming from 17,683' to 17,490' 120rpm 8.8k tq 190gpm @ 2960psi 600ft/hr Slow down to 150gpm 90rpm and 150ft/hr through upper shale section 17,140'to 17,200'No Problems. Continue to ream Continue back reaming from 17,140' to 15,220' 120rpm 8.8k tq 190gpm @ 2960psi 800ft/hr No problems going through shale section from 15,642'to 15,731' 12:00 19:30 7.50 17,490 15,220 PROD1 DRILL REAM T Continue back reaming from 17,490' to 15,220'(inside 7"shoe) 120 rpm, 8.8K TO, 190 gpm with 2,960 psi, pull rate-600 ft/hr Work thru tight spots: 17,198- 17,140,with 150 gpm,2,200 psi, 90 rpm, 8K TQ-ok 19:30 00:00 4.50 15,220 15,220 PROD1 DRILL CIRC T CBU 3X with 190 gpm,2,800 psi, 90 rpm, 9K TQ Losses during Tour=70 bbl Cumulative BHA Krevs= 1344.5(on +off btm) 37/07/2014 Finish displacing to 10.8 ppg MOBM, flow chk, unable to move pipe free. Displace hole back to 9.8 ppg and then 9.4 ppg MW holding back pressure with MPD equipment. Well indicated a small flow, CBU and verified well static. Page 36 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:15 1.25 15,220 15,506 PROD1 DRILL WASH T Wash in hole w/o rotary from 15,220' to 15,506'with 150 gpm, 1,850 psi, SO with pumps on= 110K 01:15 07:15 6.00 15,506 15,443 PROD1 DRILL CIRC T Displace hole above 15,506'with 10.8 ppg MOBM 'mudcap". Displace following the weight up schedule with 190-40 gpm, 2,550-375 psi, 90-30 rpm 8.2K TQ, maintaining ECD O/A Pressure=0 psi at 0545 hrs 07:15 10:15 3.00 15,443 15,443 PROD1 DRILL OWFF T Attempt to monitor well at 15,443'. Attempt to rotate and stalled out the rotary while pumping at 0-3.4 bbl/min, 1,750 psi. Maintained circulation throughout. Decrease pump rate to 1 BPM, 500 psi and continue to jar and attempt to free pipe pulling to 285K lb and SO to 70K. (Block Wt=60K) 10:15 12:00 1.75 15,443 15,443 PROD1 DRILL CIRC T Displace 10.8 ppg MOBM from hole with 9.8 ppg MOBM while continuing to work stuck pipe with 1 BPM, 780 psi Total losses for tour=84 bbl 12:00 18:00 6.00 15,443 15,443 PROD1 DRILL CIRC T Continue to attempt to pipe free with S0=70K and PU to 210-350K, setting jars off with 295-310K. Pull up to 350K without success.Add 10K torque to string and work pipe while continue to displace to 9.8 ppg MOBM with 1 -4.5 GPM, 780-2,790 psi 18:00 22:00 4.00 15,443 15,443 PROD1 DRILL CIRC T Displace 9.8 ppg MOBM from hole with 9.4 ppg MOBM while continuing to work stuck pipe with 4.5 BPM, 2,790 psi, PU=250K, S0=70K 22:00 23:15 1.25 15,443 15,443 PROD1 DRILL OWFF T Shut down pumps holding 355 psi back pressure with MPD equip. Reduce back pressure in stages to 265 psi showing a slight flow with MPD meters and pressure increase to 324 psi. MPD equipment showed 2 bbl gain, pitwatcher had a 1.5 bbl gain. CBU to check for gas. 23:15 00:00 0.75 15,443 15,443 PROD1 DRILL CIRC T CBU with 4.6 BPM,2,770 psi. Total losses for tour= 140 bbl 07/08/2014 Cont.to work stuck pipe-Cut mud wt to 9.2 ppg-Cont.to work stuck pipe-Circ out gas-Weighting up from 9.2ppg to 10.8 ppg 00:00 01:30 1.50 15,443 15,443 PROD1 DRILL CIRC T Continue to circulate B/U w/190 gpm @ 2790 psi while holding 125 psi back pressure-9.4 ppg mud wt(260 units gas on B/U) Page 37 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:15 0.75 15,443 15,443 PROD1 DRILL JAR T Circulate and work pipe,jars hitting at 275k then pull to 350k. Hit down to 70k-No movement- Work pump rate f/190 gpm to 150 gpm and adjust back pressure while f/125psi to Opsi 02:15 04:45 2.50 15,443 15,443 PROD1 DRILL CIRC T Circulate B/U w/190 gpm @ 2600 psi while holding 125 psi back pressure- 9.4 ppg mud wt(3,030 units gas on B/U)-Slight gains observed in pits 04:45 07:15 2.50 15,443 15,443 PROD1 DRILL CIRC T Pump 15 bbls of LVT w/190 gpm @ 2690 psi w/@ balance holding 195 psi back pressure&spot outside of bit-Apply 10 wraps in string&set @ 70k-Soak LVT pill w/@ balance holding 355 psi back pressure 07:15 07:45 0.50 15,443 15,443 PROD1 DRILL JAR T Jaron stuck pipe w/300-350k max- @ balance holding 400 psi 07:45 09:30 1.75 15,443 15,443 PROD1 DRILL CIRC T Circulate B/U w/190 gpm @ 2690 psi while holding 125 psi back pressure- (Slight gas while circulating&no increase on B/U) 09:30 10:00 0.50 15,443 15,443 PROD1 DRILL JAR T L/D single jt&bleed off @ balance back pressure-Attempt to free stuck pipe w/300-360k max& attempt to rotate w/no success- gained 7 bbls&shut in w/@ balnce 10:00 12:00 2.00 15,443 15,443 PROD1 DRILL CIRC T Circulate B/U w/190 gpm @ 2760 psi while holding 125 psi back pressure- (7,600 units gas on B/U) 12:00 19:00 7.00 15,443 15,443 PROD1 DRILL JAR T Attempt to free stuck pipe w/290- 350k max&w/192 gpm @ 2740 psi while @ balance holding 195 psi- Attempt to rotate&work torque into string w/23 wraps&torque stalling @ 11 -12 k trq max-Performed periodic derrick inspections due to jarring operations. 19:00 22:30 3.50 15,443 15,443 PROD1 DRILL CIRC T Circulate B/U w/190 gpm @ 2780 psi to circ out gas-(8,500 units gas on B/U)-(SIMOPS-Perform derrick inspection, adjust brakes&service rig) 22:30 00:00 1.50 15,443 15,443 PROD1 DRILL CIRC T L/D single jt&displace well f/9.2ppg to 10.8ppg as per weight up/back pressure schedule. 07/09/2014 Cont.to Weight up to 10.8 ppg-R/U E-Line&RIH to back off HWDP-POOH w/E-Line(shots fired/did not back off)-R/D E-Line&trouble shoot trctor&fire head-Circ @ 2 bpm 00:00 08:00 8.00 15,443 15,443 PROD1 DRILL CIRC T Continue to weight up hole to 10.8ppg from a 9.2ppg using circulating schedule. Pump total of 9563 strokes to get 10.8ppg out of the hole. 08:00 08:30 0.50 15,443 15,443 PROD1 DRILL FISH T Work pipe and establish parameters for back off with new mud weight in the hole. 6 rotations to 9k with 210k pulled Page 38 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 11:30 3.00 15,443 15,443 PROD1 DRILL ELNE T PJSM Rig up e-line and entry guide on top of the top drive. Pressure test assembly to 1,000psi, No Leaks. Make up Tractor, CCL, and 480gn/ft string shot. 11:30 17:00 5.50 15,443 15,443 PROD1 DRILL ELNE T RIH to 14,000'and tractor down to 15,217' Correlelate and locate middle of 4" HWDP joints at 15,186'. 17:00 17:15 0.25 15,443 15,443 PROD1 DRILL ELNE T Work in 16 1/4 wraps to the left and achieve 8klbs left hand torque down hole. Work pipe from 210k down to 110k. Apply wraps to the left at 150k 17:15 17:45 0.50 15,443 15,443 PROD1 DRILL ELNE T Re-correlate logging up. Place center of 5 480 gn/ft string shot at 15,186' Initiated string shot firing sequence and as the voltage went up communication with the CCL, Safe sub and String shot firing head was lost. Conduct diagnostic test to no avail. Pull up the hole with e-line to 14,900'. 17:45 18:00 0.25 15,443 15,443 PROD1 DRILL ELNE T Attempt to see if pipe is free. Put 3/4 more wrap to the left in(Total of 17) and torque out at 8k. Release torque and work pipe and get all 17 back. Does not appear to be backed off. 18:00 20:45 2.75 15,443 15,443 PROD1 DRILL ELNE T POOH w/E-Line-Repositioned upper shiv to super tugger to minimize friction on goose neck&pack off 20:45 22:00 1.25 15,443 15,443 PROD1 DRILL ELNE T PJSM on R/D E-Line-Raise top drive&bring string shots to floor (shots fired)-R/D E-Line 22:00 00:00 2.00 15,443 15,443 PROD1 DRILL CIRC T Circulate w/2 bpm @ 870 psi& condition mud to 10.8 ppg-Trouble shoot E-Line safe head,tractor& firing pin 07/10/2014 Cont.to trouble shoot E-Line-M/U RCT& RIH to 1st jt 3-1/2"DP @ 15,134'&cut DP(No Indication of cut)- POOH w/E-Line-M/U new cutter&RIH to 15,134'&cut DP(No Indication of cut)-POOH w/E-Line&R/D E-Line 00:00 06:00 6.00 15,443 15,443 PROD1 DRILL ELNE T Repair e-line tractor. Make up 1760 XP999 RCT cutter tool string with#5 anchor arms. Circulate 2 B/U while making up the tool string. Rate 84gpm 936psi Page 39 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 11:00 5.00 15,443 15,443 PROD1 DRILL ELNE T Run#2 RIH with Tractor and RCT cutter. Begin to pump down at 6,800' Stage pumps up from 1/2bbl/min to 2bbl/min make it with pumping down to 15,006'. Tractor from 15,006'to 15,200' Log up and correlate. Place RCT cutter at 15,134'top portion of the bottom joint of 3 1/2" Drill pipe. Pull 270k on weight indicator.60k over. Fire shot. No indications on surface that the pipe was cut. E-line stated that they saw their tool move. Distance from CCL to Cutter 26.1' offset 11:00 13:00 2.00 15,443 15,443 PROD1 DRILL ELNE T Pull out of the hole with the RCT. Verified on surface that the cutter fired correctly. CCL on the way out indicated no pipe movement. Consult with town and decide to make another cutter run. 13:00 15:30 2.50 15,443 15,443 PROD1 DRILL ELNE T Run diagnostics on the tractor and check out good. Make up next 1750 XP999 RCT cutter with#4 anchor arms. Circulate 84gpm 1,241psi while checking tool string. 15:30 23:00 7.50 15,443 15,443 PROD1 DRILL ELNE T Run#3 RIH with Tractor and 2nd RCT cutter. Pump down at 1 bpm @ 800 psi/2 bpm© 1000 psi to 15,000'-Shut down pumps&cont in hole with tractor to+/- 15,200'when E-Line RCT became stuck in jars-Work pipe&work E-Line RCT free-Put drill string in tension @ 250k- Correlate logs&space out RCT on depth @ 15,134'&make second cut (No indication of good cut on rig floor) -POOH w/E-Line 23:00 00:00 1.00 15,443 15,443 PROD1 DRILL ELNE T PJSM-R/D E-Line&equipment 07/11/2014 R/D E-Line&equipment-Cont.to jar on stuck pipe-R/U E-line&RIH w/string shot to 15,156'-Fire back offshot-POOH w/E-Line&R/D same-Release DP from fish&confirm free-Circ B/U 00:00 01:00 1.00 15,443 15,443 PROD1 DRILL ELNE T PJSM-R/D E-line equipment& goose neck adaptor-L/D tools-P/U single jt DP-Test top drvie to 3500 psi Page 40 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 06:30 5.50 15,443 15,443 PROD1 DRILL FISH T Attempt to free pipe at cut point w/2 bpm @ 2080 psi-Work pipe w/350k up&70k down-Applied 10 RH turns w/7 k trq-Perform periodic derrick inspection(No items found to be compromised)-Baker rep establish base torque&drag parameters for back off(18 wraps to left©8 k trq) 06:30 08:30 2.00 15,443 15,443 PROD1 DRILL SLPC T Slip and cut 60'of drill line. 08:30 11:00 2.50 15,443 15,443 PROD1 DRILL CIRC T Circulate w/2 bpm @ 2000 psi&wait on E-line 11:00 22:15 11.25 15,443 15,443 PROD1 DRILL ELNE T R/U E-line&equipment w/grease head assembly on the Top Drive entry guide-M/U 720 gn/ft string shot on 5'shot rod&RIH while pumping down w/1.5-2 bpm @ 1420 - 1740 psi-Correlate&space out on depth @ 15,156'-Apply 21.5 wraps left w/10 k trq&appear to back out of drill string up the hole(observed a 5k wt increase&trq decrease)-Turn 35.5 wraps to the right and re-torque drill string w/11.5 k trq-Re-correlate &space out on depth @ 15,156'- Apply 20 wraps to left @ 8.5 k trq- Fire shots @ 18:42 w/no indication of back off at surface-Work pipe& apply 24 wraps to left @ 9 k trq& appear to be backing off down hole on depth @ 15,156'-POOH w/E-line &R/D same 22:15 22:45 0.50 15,443 15,443 PROD1 DRILL ELNE T Test top drive to 3500 psi-Break out pup jt&TIW&pick up single jt DP 22:45 23:30 0.75 15,443 15,156 PROD1 DRILL FISH T Work pipe w/2 bpm @ 1240 psi& apply left hand wraps to string w/9 k trq-@ 28.5 wraps total including previous left hand turns string released-PU wt decreased f/210k to 160k&psi decreased f/1240 psi to 610 psi-Rotating wt 133k without restriction(appear to be backed off on depth at XO @ 15,156') 23:30 00:00 0.50 15,156 15,156 PROD1 DRILL CIRC T Circ B/U w/2 bpm @ 610 psi 07/12/2014 Cont.to circ B/U-POOH w/DP inspecting tool joints f/15,156'to 5,612' 00:00 03:45 3.75 15,156 15,156 PROD1 DRILL CIRC T Continue to circulate B/U w/84 gpm @ 637 psi-No gas units on B/U- Lost 10 bbls on circulation-Flow check(static)-Pump 30 bbls of 14.5 ppg slug 03:45 04:30 0.75 15,156 14,649 PROD1 DRILL TRIP T POOH with 4" DP f/15,156'to 14,649' -Hold 100 psi back pressure to minimize swabbing-Check each connection while coming out of the hole-Calc Disp 2 bbls/Act Disp 3 bbls-String Speed while tripping:1,700 ft/min Page 41 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:15 1.75 14,649 14,649 PROD1 DRILL RURD T Remove 4"RCD element-Flow check(static)-Install air slips and change handling equipment over to 3 1/2".Verify ID of elevators before installing 06:15 00:00 17.75 14,649 5,612 PROD1 DRILL PULD T POOH w/3 1/2"Drill Pipe f/14,649'to 5,612'-Check each connection while coming out of the hole-Starting observing damage on box end&pin ends of DP-Racked back a total of 36 stds in derrick&continued POOH while laying down-(SIMOPS test choke manifold valves 1 -16& needle valve to 250/3500 psi&chart for 5 min) 07/13/2014 Cont.to POOH to back off point(104 jts 3 1/2"DP&BHA left in hole)-Test B.O.P.'s-M/U fishing BHA& RIH to 11,474' 00:00 02:30 2.50 5,612 5,612 PROD1 DRILL PULD T Continue to trip out of the hole with 3 1/2"XT-38 F/5,612'culling bad joints as laying down. Total joints left in the hole 104 3 1/2" XT-38. 17 total bad joints culled. Calc Hole Fill=63.7 bbls/Act Hole Fill=79.5 bbls Test the choke manifold on the way out of the hole. 250/3,500 all tests passed. 02:30 02:45 0.25 0 0 PROD1 DRILL OWFF T Observe well for flow(Slight Drop) 02:45 04:15 1.50 0 0 PROD1 DRILL RURD T C/O elevators, R/U and flush the stack with LVT 04:15 05:00 0.75 0 0 PROD1 WHDBO RURD T Pull Wear ring and set test plug. No abnormal wear noted on the wear ring. 05:00 05:30 0.50 0 0 PROD1 WHDBO RURD T Rig up to test BOPE Page 42 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 11:00 5.50 0 0 PROD1 WHDBO BOPE T Test BOPE: States right to witness waived by John Crisp 1)Annular 4"TJ 250/2,500psi-Pass 2)UPR 4"TJ, HCR Choke,4" Kill Line Demco,Auto IBOP 250/3,500psi-Pass 3)Manual IBOP, HCR Kill 250/3,500psi-Pass 4)LPR 4"TJ,250/3,500psi-Pass 5)Annular 3 1/2"TJ 250/2,500psi-Pass 6)UPR 3 1/2"TJ, Manual Kill, Manual Choke line valve, Dart Valve 250/3,500psi-Pass 7)LPR 3 1/2"TJ, FOSV 250/3,500psi-Pass 8)Annular 4 1/2"TJ 250/2,500psi-Pass 9)UPR 4 1/2"TJ 250/3,500psi-Pass 10)LPR 4 1/2"TJ 250/3,500psi-Pass 11)Blind Rams 250/3,500psi-Pass 12)Super choke bleed down F/1,500-Pass 13)Manual choke bleed down F/1,500-Pass Accumulator test: Acc. Pressure Initial Accumulator pressure: 3,000psi Function Annular 18sec to close. 1,775psi UPR 7sec to close 1,600psi LPR 7sec to close 1,450psi Kill HCR 1 sec to close 1,425psi Choke HCR 1 sec to close 1,400psi Final Pre charge 1,000psi accumulator bottles First 200psi 28sec with electric pump Final 176seconds with 3 air and 1 electric pump 4-N2 Back-up Bottles 2,050psi avg 11:00 11:30 0.50 0 0 PROD1 WHDBO RURD T Pull test plug and set W/RID 8.5" 11:30 12:00 0.50 0 0 PROD1 WHDBO RURD T Blow down surface lines from test. 12:00 14:15 2.25 0 362 PROD1 DRILL PULD T Make up Baker fishing BHA with 9 joints of 4"HWDP picked up out of the Pipe shed. BHA Length: 362' Page 43 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 17:00 2.75 362 2,252 PROD1 DRILL PULD T Pick up 60joints of 4"XT-39 DP from pipe shed. From 362'to 2,252' String speed while running in 5,580fUhr Calculated Displacement:l0bbls Actual Displacement:10 bbls 17:00 22:00 5.00 2,252 10,190 PROD1 DRILL TRIP T Trip in hole with 4"DP from derrric from 2,252'to 10,190'(84 stds) 22:00 00:00 2.00 10,190 11,474 PROD1 DRILL PULD T Pick up 42 jts HWDP from pipe shed &RIH from 10,190'to 11,474' 37/14/2014 RIH to 400'above top of fish on last 2 jts of HWDP -Install RCD element-RIH&Engage fish @ 11,675'& attempt to work free(no success)-Reduce mud wt from 10.8 ppg to 10.2 ppg-Attempt to work free(no success)-R/U E-line&RCT -RIH to 15,133' 00:00 01:45 1.75 11,474 11,474 PROD1 DRILL RURD T Install RCD element 01:45 02:00 0.25 11,474 11,675 PROD1 DRILL TRIP T RIH f/11,474'to 11,675'&tag top off fish 02:00 16:15 14.25 11,675 15,443 PROD1 DRILL JAR T Break circw/1 bpm @ 520 psi- Rotate w/10 rpm @ 10 k trq max& engage fish- PSI increase f/520 psi to 890 psi @.7 bpm-Attempt to jar fish free w/400 k max PU wt(no success)-Cut mud wt f/10.8 ppg to 10.2 ppg w/2 bpm @ 1630 psi while continuing to jar&work stuck pipe (no success)-Apply 10 wraps @ 8 k trq(no success) Set 400 psi back pressure w/MPD& 450 psi stand pipe psi-PSI bleed off /confirmed hole in DP from previous RCT run Wt up f10.2 ppg to 10.4 ppg w/2.5 bpm @ 850 psi while jarring w/380 k max PU wt(no success) Performed periodic derrick inspections(good) 16:15 23:00 6.75 15,443 15,443 PROD1 DRILL ELNE T Circ w/2.5 bpm @ 840 psi while bringing E-Line tools&equip to rig floor-Break out single jt&install FOSV&M/U lubricator jt-R/U shivs,grease head&E-line-Test lines to 1500 psi-Re-postion shivs& grease head-Re-test to 1500 psi 23:00 00:00 1.00 15,443 15,443 PROD1 DRILL ELNE T RIH w/E-line&RCT to approx 7,500' Lost 284 bbls to formation past 24 hrs 37/15/2014 Cont. RIH w/E-line&RCT to 11,617'(E-line stuck top of fish 11,583'))-Attempt to work free-POOH w/E-line (no RCT pulled out of rope socket)-R/D E-line&R/U slick line-RIH to 11,583"&attempt to gain fish(not able to latch up&pushing fish down hole) Page 44 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 15,443 15,443 PROD1 DRILL ELNE T Cont.to RIH w/E-line&RCT to 7,500'-Re-position shivs-Cont.to RIH w/E-line&RCT to 11,304'- Pump down w/2 bpm @ 520 psi to 11,617'-RCT hung up in jars of Baker fishing BHA-Not able to work free-Re-position top shiv to increase PU wt w/E-line-Attempt o work RCT free-Lost 800 lbs PU wt&E-line free(Appeared to have lost RCT BHA)-POOH w/E-line-E-line pulled out of rope socket&left RCT BHA in hole(Bottom of fish 11,617'/Top of fish 11,583') 05:00 06:15 1.25 15,443 15,443 PROD1 DRILL ELNE T R/D a-line tools&equipment 06:15 10:15 4.00 15,443 15,443 PROD1 DRILL SVRG T Wait on slick line-Service rig- Adjust breaks on draw works-Clean rig floor 10:15 14:45 4.50 15,443 15,443 PROD1 DRILL SLKL T PJSM-P/U slick line tools& equipment-R/U shivs, lubricator& cement hose-Test cement hose& lubricator to 2000 psi 14:45 00:00 9.25 15,443 15,443 PROD1 DRILL SLKL T RIH w/slick line&fishing tools to recover E-line RCT BHA-Not able to work past 11,338'(top of RCT fish @ 11,583')-Appeared to be hanging up in intensifire on Baker fishing BHA- POOH w/slick line&re-configure fishing tools-RIH to 11,583'& attempt to engage fish-Latch slipping off fish&won't stay latched up-Pump @ 2-3 bpm @ 790- 1600 psi to aid in latch up-Fish appears to be moving down hole- Reduce pump to 2 bpm @ 920 psi to circ out gas(9,300 units max gas) 07/16/2014 Attempt to engage RCT fish w/Slickline(no success)-RIH w/slickline X equalizing prong as a locator tool& tag top of fish @ 15,090'-POOH w/slickline 00:00 08:15 8.25 15,443 15,443 PROD1 DRILL SLKL T Cont.to circ out gas w/2 bpm @ 920 psi-Attempt to work fish free(No Success)-POOH w/slickline& reconfigure slickline fishing BHA- RIH w/slickline pumping down w/2.5 bpm @ 1030 psi&attempt to work fish free(No Success)-POOH w/slickline 08:15 16:45 8.50 15,443 15,443 PROD1 DRILL SLKL T Wait on slickline fishing tools from Kuparuk-Circ B/U w/2-2.5 bpm @ 940-1100 psi(1600 units max gas) -Change out&reconfigure slickline fishing BHA&Pressure test lubricator to 2000 psi 16:45 20:30 3.75 15,443 15,443 PROD1 DRILL SLKL T RIH w/slickline fishing BHA pumping down w/2 bpm @ 780 psi to 11,300'- Not able to work past-POOH w/slickline Page 45 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 00:00 3.50 15,443 15,443 PROD1 DRILL SLKL T Change out slickline fishing BHA to a locatator BHA utilizing an X equalizer plug-RIH pumping down w/2 bpm @ 820 psi to 15,090'(No issues running through Baker fishing BHA)-E-line RCT top of fish @ 15,090'-POOH w/slickline locator BHA -R/D cement hose&break off lubricator from TIW valve Total OBM losses past 24 hrs=25 bbls 07/17/2014 Stand back lubricator-M/U 12'pup jt&slack off drill string to compress Baker fishing BHA-R/U lubricator& RIH to 15,090'-Engage RCT fish-POOH to 11,600'(fish hung up in Baker jars)-Sheared off of RCT fish- POOH w/slickline&reconfigure tools-RIH with slickline tools&push RCT fish back to bottom-POOH& R/D slick line& R/U E-line 00:00 03:00 3.00 15,443 15,443 PROD1 DRILL SLKL T Rack back lubricator in derrick-P/U 12'pup jt&slack off on drill string to close&put Baker fishing tools in compression-M/U lubricator-P/U slickline fishing BHA-Test lubricator to 2000 psi 03:00 11:15 8.25 15,443 15,443 PROD1 DRILL SLKL T RIH w/slickline fishing BHA to 15,090'while pumping down w/2 bpm ©920 psi-Engage RCT fish& POOH to 11,600'-Attempt to work fish through Baker bumper sub&jars -Not able to work through&sheared off of fish-POOH w/slickline- Reconfigure slickline tools to a beat down tool-RIH to 11,600 while pumping down w/2 bpm @ 930 psi- Tag fish and attempt to work down- Increase rate to 2.8 bpm @ 1410 psi -Work free&chase down hole to 14,500'-POOH w/slickline-L?D slickline tools&R/D slickline 11:15 14:45 3.50 15,443 15,443 PROD1 DRILL ELNE T Circ B/U w/2.5 bpm @ 880 psi-Wait on E-line-Clear&clean rig floor 14:45 17:30 2.75 15,443 15,443 PROD1 DRILL ELNE T Break out 12'pup&M/U E-line lubricator assembly-Establish Baker Fishing base torque&drag parameters(Wrk down 12 wraps @ 7.5 k trq& w/125-225 k PU/SO wt -release 10 wraps)-B/D T/D 17:30 22:45 5.25 15,443 15,443 PROD1 DRILL ELNE T Wait on E-line for CCL-E-line arrived on location with out collar locator-Order special flight to pick up CCI from Kuparuk SIMOPS Shuffle drill pipe in derrick &cull out bad jts(3 jts 3 1/2"XT 38) -Cleaning pits 22:45 00:00 1.25 15,443 15,443 PROD1 DRILL ELNE T PJSM-R/U E-line tools&equipment -M/U lubricator-M/U goose neck& grease head-Hang E-line shivs in derrick Page 46 of 77 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07/18/2014 24 hr Summary Cont.to R/U E-line-RIH w/back off tool&back off below Baker fishing BHA @ 11,675'-Confirm back off- POOH&R/D E-line-POOH w/DP to 5087'(break, inspect&make up each jt) 00:00 03:00 3.00 15,443 15,443 PROD1 DRILL ELNE T Cont.to R/U E-line-Test grease head to 1500 psi-M/U E-line tools& string shot&RIH to 200'-M/U to stump&Adjust shivs in derrick 03:00 07:15 4.25 15,443 15,443 PROD1 DRILL ELNE T RIH w/E-line string shot to 11,730'- Apply left hand torque for back off as per Baker(12.5 wraps @ 7.5 k trq& -Correlate logs w/E-line&fire 5' string shot across 3 1/2"tool jt @ 11,675'-Hook load decreased from 210 k to 175 k(confirm back off at surface)-POOH w/E-line to 200' 07:15 09:30 2.25 15,443 15,443 PROD1 DRILL ELNE T Pull E-line tools to rig floor(confirm shots fired)-L/D e-line tools&R/D E-line 09:30 11:30 2.00 15,443 15,443 PROD1 DRILL CIRC T Circ&cond. mud&wt up from 10.4 ppg to 10.8 ppg w/4 bpm @ 1120 psi &w/50 rpm @ 8 k trq 11:30 12:15 0.75 15,443 15,443 PROD1 DRILL OWFF T OWFF(static)-C/O top single 12:15 12:45 0.50 15,443 15,443 PROD1 DRILL CIRC T Pump 29 bbls 13 ppg dry job 12:45 13:00 0.25 15,443 15,443 PROD1 DRILL OWFF T OWFF(static)-B/D top drive-Line up fill hole down kill line 13:00 00:00 11.00 15,443 15,443 PROD1 DRILL TRIP T POOH f/11,675'to 5,087'as per tripping schedule-Breaking all connections&inspecting tool joints 07/19/2014 Cont. POOH w/DP&L/D Baker fishing BHA(break, inspect&make up each jt)-RIH w/single 3 1/2"jt&4" DP to top of stump @ 11,675'-Circ B/U w/3 bpm @ 720 psi 00:00 09:00 9.00 15,443 15,443 PROD1 DRILL TRIP T POOH on elevators on TT f/5,087'to 361'as per tripping schedule- Breaking all connections& inspecting tool joints-Culled out 4 jts total-Pulled RCD element @ 1000' 09:00 11:45 2.75 15,443 15,443 PROD1 DRILL PULD T PJSM-L/D Baker fishing BHA f/361' -Clean&clear floor -Monitor well on TT(static) Calc/Act Hole Fill=71.17/85.5 bbls 11:45 13:00 1.25 15,443 15,443 PROD1 DRILL PULD T M/U Baker fishing BHA to 38'(1 jt 3 1/2"DP,XO's&circ sub) 13:00 21:30 8.50 15,443 15,443 PROD1 DRILL TRIP T RIH w/4"DP f/derrick f/38'to 11,675' -Tag top of fish @ 11,675' 21:30 00:00 2.50 15,443 15,443 PROD1 DRILL CIRC T Circ B/U w/3 bpm @ 720 psi&w/50 rpm©7.5 k trq-10.8 ppg in/out(no gas on B/U) 37/20/2014 Cont.to circ B/U w/3 bpm©780 psi-Screw into fish&circ B/U-R/U slickline&RIH to fish out E-line RCT- POOH w/slickline&RCT tool-R/D slickline& R/U E-line&2"DCST Page 47 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 00:30 0.50 15,443 15,443 PROD1 DRILL CIRC T Cont.to circ B/U w/3 bpm @ 720 psi &w/50 rpm @ 7.5 k trq-10.8 ppg in/out PU wt 205 k, SO wt 135 k, ROT wt 160 k 00:30 02:00 1.50 15,443 15,443 PROD1 DRILL FISH T Rack back std#124&P/U space out pups-Slack off w/1 bpm @ 270 psi&w/15 rpm @ 8 k trq to engage fish @ 11,675'-Pressure increased f/270 psi to 680 psi once fished was engaged-Wrk 7.5 RH turns w/8 k trq(PU to 225 k&SO to 125 k)to tighten up to fish-Release RH torque and confirm fish on 02:00 06:45 4.75 15,443 15,443 PROD1 DRILL CIRC T Stage pumps up to 2 bpm&circ& cond mud to 10.8 ppg-ICP 1130 mpsi-FCP 750 psi-SIMOPS bring slickline tools&equipment to rig floor 06:45 10:30 3.75 15,443 15,443 PROD1 DRILL SLKL T PJSM-R/U lubricator,XO's&FOSV -R/U cementline& 1502 valves- M/U slickline fishing tools&test lubricator to 1800 psi 10:30 18:15 7.75 15,443 15,443 PROD1 DRILL SLKL T RIH w/slickline fishing BHA while pumping down w/2bpm @ 850 psi to 15,090'-Attempt to engage RCT fish -POOH w/slickline(no fish)-RIH w/slickline fishing BHA while pumping down w/2bpm @ 850 psi to 15,090'-Attempt to engage RCT fish -POOH w/slickline(fish retrieved)- L/D RCT fish&slickline tools 18:15 20:00 1.75 15,443 15,443 PROD1 DRILL SLKL T R/D lubricator&slickline 20:00 00:00 4.00 15,443 15,443 PROD1 DRILL ELNE T Shuffle drill pipe in derrick to make room for E-line shivs-P/U XO's& pups for lubricator-M/U E-line tools on ground-R/U E-line grease head &adaptor-Hung shivs in derrick- M/U wt bars&test lubricator to 1500 psi-M/U E-line 2" DCST to wt bars 37/21/2014 RIH w/2"DCST-Sever as per Baker/HES @ 15,152'-E-line stuck in hole-Attempt to work E-line free- Pulled out of rope socket-POOH w/E-line& R/D E-line-Circ&cond. mud-Pump dry job-POOH w/DP to 10,043' 00:00 05:45 5.75 15,443 15,152 PROD1 DRILL ELNE T Adjust E-line shivs in derrick-RIH w/E-line 2"DCST to 15,152'pumping down as needed w/2-3.4 bpm @ 930- 1480 psi-Attempt to work past 15,152'with no success-Call town &decesion made to sever© 15,152' -Fire DCST(no indication of sever @ surface)-Attempt to POOH w/E-line -E-line tool stuck in hole Page 48 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 13:45 8.00 15,152 15,152 PROD1 DRILL ELNE T Attempt to free E-line-Work 5 right turns into drill string w/8 k trq&PU to 225 k SO to 150 k while pumping w/2.5 bpm @ 1130 psi(no success) -Cont.to work right hand torque into string w/8 k trq max(28 wraps total) -Observe pipe movement& decrease in torque(confirm sever)- Cont.to attempt work E-line free(no success)-Circ&cond.w/2-3 bpm @ 1020-1190 psi-Decision made to pull out of rope socket- Re-position shivs in derrick&pull out of rope socket w/6k(top of E-line fish @ 15,120')-POOH w/E-line while cont. to pump down drill string-R/D E-line tools&equipment-Test top drive to 3500 psi 13:45 14:30 0.75 15,152 15,083 PROD1 DRILL PULD T L/D single jt, pup jts,XO's&FOSV f/15,152'to 15,083'-Observe mud out of balance 14:30 17:45 3.25 15,083 15,083 PROD1 DRILL CIRC T Circ&cond. mud to balance out w/4.5 bpm @ 2040 psi-10.8 ppg In/Out 17:45 19:00 1.25 15,083 15,050 PROD1 DRILL OWFF T OWFF(slight ooze then static)- SIMOPS shuffle drill pipe in derrick& L/D single jt f/15,083'to 15,050'- Prep rig floor to POOH 19:00 19:45 0.75 '15,050 15,050 PROD1 DRILL 'CIRC T Pump 35 bbls 14.3 ppg dry job-Line up to hold back pressure w/MPD @ Balance 19:45 00:00 4.25 15,050 10,043 PROD1 DRILL TRIP T POOH on elevators on trip tank f/15,050'to 10,043'while holding back pressure as per trip schedule 07/22/2014 Cont.to POOH w/DP(L/D 17 bad jts)-M/U clean out BHA and RIH. Cut and Slip DL, service TD. PJSM, RIH with cleanout assembly(Csg scraper/gauge-mill). 00:00 03:45 3.75 10,043 3,479 PROD1 DRILL TRIP T POOH on elevators on trip tank f/10,043'to 3,479'while holding MPD back pressure, as per trip schedule 03:45 07:15 3.50 3,479 1,000 PROD1 DRILL TRIP T Continue to POOH on elevators on trip tank f/3,479'to 1,000'while holding MPD back pressure. Inspect 3-1/2"DP while POOH. Flow chk- static. 07:15 07:45 0.50 1,000 1,000 PROD1 DRILL RURD T PJSM. Remove 4"RCD element. 07:45 08:15 0.50 1,000 1,000 PROD1 DRILL OWFF T Flow chk for 30 min-static with a slight drop in annulus. Page 49 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:15 11:00 2.75 1,000 0 PROD1 DRILL TRIP T Continue to POOH on elevators on trip tank f/1,000'to 0'while holding MPD back pressure. Inspect 3 /2" DP connections and LD 17 jts of DP with tool jt wear plus 27'cutoff joint. (110 total jts of 3-1/2" DP retrieved). Hole in cutoff jt 2.5'from box end. Calc fill=91.74 bbl,Actual= 106 bbl. Note: Cut-off jt was LD in pipe shed and E-line tool removed. 11:00 12:00 1.00 0 0 PROD1 DRILL PULD T Clear and clean RU. Bring cleanout BHA tools to rig floor. 12:00 13:45 1.75 0 0 PROD1 DRILL PULD T LD fishing tools, clear and clean rig floor, continue to bring BHA tools to rig floor. 13:45 15:45 2.00 0 137 PROD1 DRILL PULD T PJSM. MU cleanout BHA with 6-1/8" mill, 7"scraper,6.059"watermelon mill to 137'. 15:45 17:30 1.75 137 2,039 PROD1 DRILL TRIP T RIH/SLM 3-1/2"DP from derrick from 137'to 2,039'. 17:30 17:45 0.25 2,039 2,039 PROD1 DRILL SFTY T PJSM on slip&cut. 17:45 18:45 1.00 2,039 2,039 PROD1 DRILL SLPC T Slip and Cut 68'of DL and drain oil from TD. 18:45 20:30 1.75 2,039 2,039 PROD1 DRILL SVRG T Service draworks and TD. Change oil in TD and perform semi-annual preventive maintenance. 20:30 21:30 1.00 2,039 3,460 PROD1 DRILL TRIP T Continue RIH/SLM 3-1/2"DP from derrick from 2,039'to 3,460'. 21:30 21:45 0.25 3,460 3,463 PROD1 DRILL TRIP T Change out 3-1/2"elevators to 4". MU 3-1/2",XT-38 x 4"XT-39 XO. 21:45 00:00 2.25 3,463 5,927 PROD1 DRILL TRIP T Continue RIH with 4"DP from derrick from 3,463'to 5,927', filling DP every 20 stds. PU= 122K, SO= 101K lb. 37/23/2014 Continue RIH to 200'above fish, install new 4"RCD element, RIH and tag up on fish. C&C mud,flow chk, pump slug and POOH to 5,000'. Flow chk, remove RCD element,flow chk-static. POOH to 2,606'md. 00:00 07:45 7.75 5,927 14,855 PROD1 DRILL TRIP T Continue RIH from 5,927'to 14.855', with 4"DP from derrick, filling DP every 20 stds. PU=225K, SO= 135K lb. 07:45 08:00 0.25 14,855 14,855 PROD1 DRILL OWFF T Flow chk-static 08:00 09:00 1.00 14,855 14,855 PROD1 DRILL RURD T PJSM. PU/MU 4" element in ROD head. Pull test to 30K-good. LD RCD element running tool. 09:00 09:30 0.50 14,855 15,045 PROD1 DRILL TRIP T Continue RIH with 4"DP from derrick from 14,855'to 15,045', PU=2:35K, SO= 140K, ROT= 180K Ib,TQoff= 10K Trip-Calc/Actual Fill =92/82 bbl 09:30 10:15 0.75 15,045 15,157 PROD1 DRILL WASH T Wash down from 15,045'to 15,157 with 3.5 bbl/min, 1,500 psi. Tag TOF at 15,157'md. Set down with 10K lb in the down stroke,2x,without rotation. Page 50 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:15 10:30 0.25 15,157 15,140 PROD1 DRILL TRIP T POOH from 15,157'to 15,140' 10:30 12:00 1.50 15,140 15,140 PROD1 DRILL CIRC T C&C mud,staging pump up to 3.5 BPM and 1,580 psi. Losing mud at 60 bbl/hr rate, reduce flowrate to 2 BPM, 740 psi and losses reduced to 24 bbl/hr. Max MW out was 12.4 PPg. 12:00 14:00 2.00 15,140 15,140 PROD1 DRILL CIRC T Continue to C&C mud staging up to 3.5 BPM and 1,330 psi. Final MW out was 11.0 ppg. 14:00 14:30 0.50 15,140 15,140 PROD1 DRILL OWFF T Flow chk.Well went static after 22 min. 14:30 14:45 0.25 15,140 15,140 PROD1 DRILL CIRC T Pump 28 bbl, 12.8 ppg slug 14:45 15:00 0.25 15,140 15,140 PROD1 DRILL OTHR T Blow down TD, line up to fill hole down the Kill line. 15:00 21:15 6.25 15,140 4,973 PROD1 DRILL TRIP T POOH from 15,140 to 4,973'mcl with MPD holding 0-200 psi while PC)OH and 0-50 psi when drillstring set in slips. 21:15 22:00 0.75 4,973 4,973 PROD1 DRILL RURD T Remove air slips,flow chk-static. PJSM, pull and remove RCD 4" element. 22:00 22:30 0.50 4,973 4,973 PROD1 DRILL OWFF T Blow down Kill line, fill hole. Flow chk-static 22:30 23:15 0.75 4,973 3,459 PROD1 DRILL TRIP T Continue to POOH from 4,973'to 3,459'md. 23:15 23:30 0.25 3,459 3,459 PROD1 DRILL PULD T LD XO and change out elevators from 4"to 3-1/2". 23:30 00:00 0.50 3,459 2,606 PROD1 DRILL TRIP T Continue to POOH from 3,459'to 2,606'md. 37/24/2014 LD cleanout BHA.Clear and clean rig floor, PU/MU cement retainer. RIH with retainer and set 2'above TOF. Test retainer and csg to 1,500 psi. Perform injectivity test. Pump cement squeeze job. Un-sting, reverse circ out any excess cement. Test retainer. C&C mud and cut back MW to 9.6 ppg. 00:00 01:30 1.50 2,606 137 PROD1 DRILL TRIP T Continue to POOH from 2,606'to 137'md. Flow chk-static 01:30 01:45 0.25 137 42 PROD1 DRILL PULD T Continue to POOH from 137'to 42' md. Stand back Non-Mag Flex collars. 01:45 02:30 0.75 42 0 PROD1 DRILL PULD T PJSM. LD 6-1/8"mills and 7"csg scraper. All mills in gauge. 02:30 03:45 1.25 0 0 PROD1 DRILL PULD T LD cleanout BHA, clear and clean rig floor. PU 7"cmt retainer to rig floor. 03:45 07:30 3.75 0 5,042 PROD1 DRILL TRIP T PJSM. MU cmt retainer and RIH to 5,042'with 3-1/2"DP. PU= 100K, SO=90K lb. 07:30 12:00 4.50 5,042 11,569 PROD1 DRILL TRIP T MU 3-1/2 x 4"XO, change out 3-1/2" to 4"DP elevators. Continue to RIH from 5,042'to 11,569'with 4"DP. 12:00 15:15 3.25 11,569 15,156 PROD1 DRILL TRIP T Continue RIH from 11,569'to 15,156' md,with 4"DP.Tag up on fish. PU=215K, SO= 125K lb. 15:15 16:00 0.75 11,569 15,099 PROD1 DRILL PULD T Space out laying down 2 singles, PU 15'pup jt, single jt and 11'pup. Page 51 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 17:00 1.00 15,099 15,150 PROD1 DRILL PACK T Work 14 wraps into drillstring (TO at 9.5-10.0K ft-Ib). Set Baker K-1 mechanical cmt retainer and verify 2X with 25K down weight and 40K up. Note:top of retainer at 15,150'rnd 17:00 17:15 0.25 15,150 15,150 PROD1 DRILL RURD T Blow down cmt line. Line up to pump down Kill line. Close annular preventer. 17:15 17:45 0.50 15,150 15,150 PROD1 DRILL PRTS T Test 7"casing, IA, cement retainer to 1,500 psi. Hold pressure for 10 min-good. Blow down Kill line, open Annular. 17:45 18:15 0.50 15,150 15,150 PROD1 DRILL PRTS T Pump down DP and perform Injectivity test, staging up to 5 BPM and 2,530 psi. Shut down pump with pressure dropping to 810 psi. Un-sting from cmt retainer with IDU to 215K and rotating drillstring 12 turns to right. DP pressure dropped from 810 to 130 psi,verifying released. 18:15 19:30 1.25 15,150 15,148 PROD1 DRILL RURD T Break pup jt, RU cmt hose and valve, head pin. Remove Bell guide on TD. 19:30 19:45 0.25 15,148 15,148 PROD1 DRILL RURD T Close Annular, line up to Gas buster and fill line. 19:45 21:00 1.25 15,148 15,148 PROD1 DRILL PLUG T Dowell pump 2 bbl of 12.5 ppg MudPush spacer. Pressure test surface lines to 4,200 psi. Pump 13 bbl of 12.5 ppg spacer, 17 bbl of 15.8 ppg cement and 15 bbl of MudPush. Displace with 89.5 bbl of 10.8 ppg MOBM to the DP tail using rig pump at 4 BPM and 1,930 psi. Hold 460-540 psi back pressure while pumping, to prevent U-tubing. 21:00 21:15 0.25 15,148 15,150 PROD1 DRILL PLUG T Sting into retainer. Squeeze 15 bbl MudPush and 15 bbls(73 sks at 1.16 yield)class G, 15.8 ppg cement with 5 BPM, 2,530 max psi. Shut down pump with calculated 2 bbl of cement in DP tail. Un-sting from retainer. CIP at 2105 hrs. 21:15 22:00 0.75 15,150 15,148 PROD1 DRILL CIRC T Reverse circ out excess cement, checking returns until clean, at 3.5- 6.5 BPM and 1,820-3,410 psi. 22:00 22:30 0.50 15,148 15,148 PROD1 DRILL PRTS T Line up and pressure test retainer to 1,500 psi for 10 min-good. 22:30 23:15 0.75 15,148 15,148 PROD1 DRILL RURD T Blow down and RD cement hose and head pin. Install Bell guide on TD. PU/MU single back into stand. 23:15 00:00 0.75 15,148 15,148 PROD1 DRILL CIRC T Displace well from 10.8 ppg, MOBM to 9.6 ppg MOBM at 6 BPM and 3,000 psi. Page 52 of 77 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07/25/2014 24 hr Summary Finish displacing well to 9.6 ppg, MOBM. Flow chk. POOH, LD retainer running tool/cmt stinger. Pressure test Choke manifold valves#1-16 while POOH.Attempt to pull wear ring but unable to, due to broken pieces of Annular preventer, sealing element wedged around WR. ND MPD equipment on the BOP stack to change out Annular preventer sealing element. Note:Witness of BOPE test waived by Bob Noble of the AOGCC 00:00 03:15 3.25 15,148 15,148 PROD1 DRILL CIRC T Displace well from 10.8 ppg, MOBM to 9.6 ppg MOBM at 6 BPM and 2,350 psi FCP. 03:15 03:30 0.25 15,148 15,148 PROD1 DRILL OWFF T Flow chk-static 03:30 03:45 0.25 15,148 15,148 PROD1 DRILL CIRC T Pump 36 bbl, 11.1 ppg dry job. 03:45 12:00 8.25 15,148 0 PROD1 DRILL TRIP T POOH from 15,148'to surface Bind LD cmt retainer running tool. Calc= 86.61 /Actual=86.5 bbl. Test Choke manifold valves#1-16 during POOH-good. Spill Drill-CRT=88 sec 12:00 13:45 1.75 0 0 PROD1 DRILL RURD T Clear and clean rig floor, LD retainer running tool, clean out drip pan under rig floor. RU FOSV/Dart valves for testing. Monitor well-Gain/Loss=0 13:45 15:00 1.25 0 0 PROD1 DRILL RURD T PJSM.Attempt to pull 8.75"Wear ring but unsuccessful. Observed a large piece of the sealing element in the Annular preventer. Could not pull WR free with floor tugger. Re-set WR and removed running tool. Close Blind rams. 15:00 16:00 1.00 0 0 PROD1 DRILL RURD T PJSM. Opened upper door on MPD and removed pieces of Annular preventer sealing element. Close and re-tighten bolts on upper MPD door. Blow down MPD lines. 16:00 00:00 8.00 0 0 PROD1 DRILL NUND T PJSM. ND MPD Bearing Assembly and RCD,to change Annular preventer sealing element. X7/26/2014 Change out Annular preventer element, NU MPD,testing BOPE. 00:00 02:15 2.25 0 0 PROD1 DRILL NUND T PJSM. Break Annular cap with 5K ft-lb on break out tongs. Lift and secure out of the way. 02:15 03:30 1.25 0 0 PROD1 DRILL NUND T PJSM. Remove old element and LD. Clean out bowl and install new element. Clean threads on cap. 03:30 04:30 1.00 0 0 PROD1 DRILL NUND T PJSM. Clean threads in top of Annular. MU Annular cap and lock nut. 04:30 05:00 0.50 0 0 PROD1 DRILL NUND T RD and LD potato masher running tool. 05:00 05:45 0.75 0 0 PROD1 DRILL NUND T PU 3-1/2"DP and RIH. Function Annular 2x, purge air from system and visually inspect-no leaks. LD 3-1/2"DP. Page 53 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:45 12:00 6.25 0 0 PROD1 DRILL NUND T PJSM-NU MPD RCD with new bearing assembly,orbit valve, f ow Riser and flow line. Install drip pan under the rig floor. 12:00 14:00 2.00 0 0 PROD1 DRILL NUND T Torqe up studs on Orbit valve, hook up and secure MPD lines,turn buckles. Install silicon seal over Riser. 14:00 14:15 0.25 0 0 PROD1 DRILL NUND T PJSM for changing Saver sub on TD. 14:15 16:00 1.75 0 0 PROD1 DRILL NUND T Change out TQ wrench head,4" XT-39 saver sub while clean up BOP/MPD stack and prep for testing 16:00 16:15 0.25 0 0 PROD1 DRILL SFTY T PJSM for testing MPD 16:15 22:00 5.75 0 0 PROD1 DRILL PRTS T Test MPD equip,trouble shoot leaks, retest-good. LD MPD test plug 22:00 22:15 0.25 0 0 PROD1 DRILL SFTY T PJSM for RU and test BOPE 22:15 00:00 1.75 0 0 PROD1 WHDBO BOPE T RU test and recording equipment for BOPE test. Drain stack, set test plug and 4"test joint. Fill stack, Choke/Kill lines and Choke manifold with water. Test BOPE with 4"test jt-Annular to 250/2500 and chart for 5 min. Test upper pipe rams(3.5"x 6"), lower pipe rams 3-1/2"x 6"VBRs, needle valve, auto/lower IBOP, HCR Choke and Kill, 4"dart and FOSV. 37/27/2014 Test BOPE, MU Baker Whipstock assy, RIH to 14,910'and could not pass.Work string, pump at 5 BPM, turn string and continue to work-no-go. CBU. Page 54 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:00 4.00 0 0 PROD1 WHDBO BOPE T Continue to test BOPE with 4"test jt- to 250/3500 and chart for 5 min. Test upper pipe rams(3.5"x 6") lower pipe rams 3-1/2"x 6"VBRs, needle valve, auto IBOP, HCR Choke and Kill, 4"dart and FOSV,3.5"dart and FOSV valves, Test with 3.5' test jt-Annular to 250/3500 and chart for 5 min.Test, upper pipe rams(3.5" x 6"), lower pipe rams 3-1/2"x 6" VBRs to 250/3,500 psi and char:for 5 min ea.Test with 4.5"test jt- Annular to 250/3500 and chart for 5 min. Test, upper pipe rams(3.5"x 6"), lower pipe rams 3-1/2"x 6" VBRs to 250/3,500 psi and char:for 5 min ea. Blind rams to 250/3,500 psi and chart for 5 min ea.Test rig gas alarms- Accumulator test, 3,000 psi,200 psi in 30 sec, 189 sec to full system pressure. 4 bottles. nitrogen at 2,050 psi. Perform Drawdown test on Super and manual choke. Test Rig gas alarms. All tests were good. Test witness waived by Mr. Bob Noble of the AOGCC. 04:00 04:45 0.75 0 0 PROD1 WHDBO BOPE T Pull test plug, drain stack, blow _ down lines and MPD equipment 04:45 05:15 0.50 0 0 PROD1 WHPST RURD T Set 8.625"wear ring 05:15 06:15 1.00 0 0 PROD1 WHPST PULD T PU whip stock and milling BHA to rig floor. PU and break MWD Impulse tool,top sub and LD. 06:15 07:15 1.00 0 289 PROD1 WHPST RURD T PJSM. MU whip stock/milling BHA and MWD to 289'. 07:15 10:00 2.75 289 1,520 PROD1 WHPST TRIP T RIH with whipstock from 289'to 1,520' 10:00 10:30 0.50 1,520 1,520 PROD1 WHPST DHEQ T Shallow pulse test MWD with 200 GPM,680 psi-good. 10:30 12:00 1.50 1,520 3,230 PROD1 WHPST TRIP T Continue to RIH from 1,520'to 3,230' PU=SO=85K lb 12:00 22:30 10.50 3,230 14,910 PROD1 WHPST TRIP T Continue to RIH from 3,230'to 14,910'with 6"Mill, 6.125"Water melon mill,filling every 2,000'. 22:30 23:30 1.00 14,910 14,910 PROD1 WHPST TRIP T Whipstock/mills hang up at 14,910' with slackoff weight decrease of 10K. (anchor sets with slackoff of 15K Ib). Circulate with 5 BPM and work string up and down with PU=235K, SO=135K while circulating.Work string 6x,turn 180 deg and work 3x with BHA hanging up at the same 14,910'and depth. Verify pipe tally and confer with town. 23:30 00:00 0.50 14,910 14,910 PROD1 WHPST CIRC T CBU with 5 BPM,2,490 psi and flow-chk. Page 55 of 77 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 07/28/2014 24 hr Summary Continue to pump/pull OOH with whip stock. Circulate and work thru tight spots.Top drive disengaged from guide rails. Secure rig, PJSM made 3x inspections of TD/derrick. Lowered TD to rig floor. 00:00 00:15 0.25 14,910 14,910 PROD1 WHPST CIRC T Continue CBU with 5 BPM,2,080 psi FCP. MWin=9.6 ppg, MWout= 9.3ppg 00:15 01:15 1.00 14,910 14,910 PROD1 WHPST OWFF T Flow chk.Allow air to break out of mud while service TD and PJSM for Slip and Cut DL. Flow chk-static. 01:15 01:30 0.25 14,910 14,821 PROD1 WHPST TRIP T POOH from 14,910'-14,821'on Trip tank. Swabbing-Calc=0.95 bbl, Actual=0 bbl. Pump at 2 BPM,430 psi, PU=235K, SO= 135K lb with pumps on. 01:30 03:00 1.50 14,821 14,821 PROD1 WHPST SLPC T Slip and Cut 75'of DL. Service Iron Roughneck and Draworks. Monitor well on Trip tank-Gain/Loss=0 bbl. 03:00 12:00 9.00 14,821 12,026 PROD1 WHPST TRIP T POOH from 14,821'to 12,026'with 430- 1,180 psi. Pulled tight at 14,396', 14,278', 14,187', 13,680', 13,555', 12,825'.Attempt to POOH on Trip tank at 13,722'-no-go. 12:00 17:30 5.50 12,026 12,026 PROD1 WHPST RGRP T At 12,026'and(TD at 72'above rig floor), Link-Tilt struck derrick girter and Top Drive de-railed and hung from the blocks. Secure brake, secure rig floor and wait for arrival of CPAI Safety, and NOV structural specialist. 17:30 18:00 0.50 12,026 12,026 PROD1 WHPST RGRP T PJSM on Inspection plans and risk assessment. 18:00 20:00 2.00 12,026 12,026 PROD1 WHPST RGRP T Derrickman made an inspection of TD, blocks, sheaves,drill line and derrick work area. NOV made an inspection of derrick,TD and blocks. Rig Mechanic made a mechanical/ hydraulic inspection of the TD 20:00 23:00 3.00 12,026 12,026 PROD1 WHPST RGRP T PJSM on safely lowering the TD to the rig floor. Raise TD 1'and send derrickman up to inspect the TD and hydraulic/electrical lines that might be in the way. Continue to raise the TD,working the bails/elevators free from the crossbeam. Lower TD to rig floor. 23:00 23:15 0.25 12,026 12,026 PROD1 WHPST RGRP T Derrickman performed an overall derrick inspection. PJSM for work plan and hazard recognition. 23:15 00:00 0.75 12,026 12,026 PROD1 WHPST RGRP T Electrician inspected TD wiring and housing and reported no damage to either. Mechanic replaced hydraulic hose on the off driller side Link-Tilt. 07/29/2014 Make detailed inspections of TD mechanical/hydraulic/electrical systems and repair as needed. NOV to inspect derrick structurally and await on assessment from NOV engineering staff. Reinstall TD on guide rails and secure. Page 56 of 77 Time Logs _ Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 12,026 12,026 PROD1 WHPST RGRP T Continue to work on TD while hanging in the derrick at floor level. Add 4 gal of hydraulic fluid. Function test hydraulics on TD(Link-tilt, handling ring,Auto IBOP)-good. 01:00 01:45 0.75 12,026 12,026 PROD1 WHPST RGRP T Rotate and remove bails from TD. Blow down TD. 01:45 03:15 1.50 12,026 12,026 PROD1 WHPST RGRP T Remove lower section of TD rails from derrick. 03:15 06:00 2.75 12,026 12,026 PROD1 WHPST RGRP T PJSM. Break and remove Auto/ Manual IBOP/Saver sub from TD quill shaft. 06:00 06:15 0.25 12,026 12,026 PROD1 WHPST RGRP T Clear and clean rig floor of tools and equip. 06:15 07:45 1.50 12,026 12,026 PROD1 WHPST RGRP T PJSM. Derrickman and welder inspect derrick. NOV rep inspect derrick. 07:45 12:00 4.25 12,026 12,026 PROD1 WHPST RGRP T PJSM. ND Kelly hose. RU and install TD back in guide rails in derrick. 12:00 12:15 0.25 12,026 12,026 PROD1 WHPST SFTY T PJSM on working on TD. 12:15 16:30 4.25 12,026 12,026 PROD1 WHPST RGRP T Make detailed inspection of electrical equip on TD. Re-install lower section of TD guide rail. Function test TD. MU IBOP to TD. Clean the TD. 16:30 16:45 0.25 12,026 12,026 PROD1 WHPST SFTY T PJSM on working in the derrick. 16:45 00:00 7.25 12,026 12,026 PROD1 WHPST RGRP T Clean and strip paint from derrick girt. Wire wheel paint from Link tilt links/bails for Mag-particle inspection. 07/30/2014 Make welding repairs in derrick. Inspect derrick. 00:00 04:15 4.25 12,026 12,026 PROD1 WHPST RGRP T Continue to prep derrick girt for welder. Continue to prep Link-Tilt for MPI and UT inspections. 04:15 09:00 4.75 12,026 12,026 PROD1 WHPST RGRP T PJSM. PU welder's tools and equipment via the Beaver slide. Welder work on girt in derrick. MPI the bails, bail clamps, 4" DP elevators-good. 09:00 12:00 3.00 12,026 12,026 PROD1 WHPST RGRP T PJSM. Prep TD bail ears for MPI. Prep welder leads for derrick work. 12:00 13:30 1.50 12,026 12,026 PROD1 WHPST RGRP T PJSM. Prep tools and plate for exterior derrick repair work. Stage crane into position for derrick work by welders. 13:30 13:45 0.25 12,026 12,026 PROD1 WHPST SFTY T PJSM on welding plate on girt. 13:45 18:00 4.25 12,026 12,026 PROD1 WHPST RGRP T Position hands in derrick. Raise plate to girt. Send welder's up in derrick via man basket. Tack and weld plate into position. 18:00 18:15 0.25 12,026 12,026 PROD1 WHPST SFTY T PJSM on RU and installing bails. 18:15 00:00 5.75 12,026 12,026 PROD1 WHPST RGRP T Install bails on TD. Continue to heat girt and weld on girt. 07/31/2014 Make welding repairs in derrick and TD rails. Page 57 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 12,026 12,026 PROD1 WHPST RGRP T Continue to straighten and weld on girt in derrick, RU Link-Tilt clamps on bails. Prep hard lines in pump room for MP/UT inspections. Inspect hard lines-good. 06:00 06:30 0.50 12,026 12,026 PROD1 WHPST RGRP T Continue welding on girt in derrick. Continue to RU clamps on bails when overhead work was not being done. 06:30 07:30 1.00 12,026 12,026 PROD1 WHPST RGRP T Finish RU Link-Tilt on bails. RU 4" DP elevators. Check hydraulic fluid in TD-good. 07:30 07:45 0.25 12,026 12,026 PROD1 WHPST SFTY T Function test Link-Tilt and Float. Recreate Incident and investigate the root cause. 07:45 12:00 4.25 12,026 12,026 PROD1 WHPST RGRP T Continue welding on girt in derrick. Prep choke manifold for inspections. Make UT(Ultra-sonic) inspection of the Choke manifold- good. 12:00 12:15 0.25 12,026 12,026 PROD1 WHPST SFTY T PJSM on working in the derrick 12:15 18:00 5.75 12,026 12,026 PROD1 WHPST RGRP T Weld plate on inner side of girt from inside the derrick. Note: Held Rig Fire drill 18:00 19:00 1.00 12,026 12,026 PROD1 WHPST RGRP T Perform prep work on girt, from inside the derrick 19:00 00:00 5.00 12,026 12,026 PROD1 WHPST RGRP T Weld plate on outer side of girt, in the derrick.Add gear oil to TD. 08/01/2014 Make welding repairs in derrick and TD rails. Test run TD, CBU. POOH with whip stock BHA. 00:00 06:00 6.00 12,026 12,026 PROD1 WHPST RGRP T Continue to weld plate on outer side of girt, in the derrick.Work on TD rollers when overhead work not being done. 06:00 07:00 1.00 12,026 12,026 PROD1 WHPST RGRP T Finish welding work on girt in derrick. 07:00 09:00 2.00 12,026 12,026 PROD1 WHPST RGRP T PJSM. Drape tarp over weld area to keep dry for Mag particle inspection. Welder work on TD rail on driller's side. 09:00 09:30 0.50 12,026 12,026 PROD1 WHPST RGRP T PJSM. Mag Particle inspect welds on girt in derrick-all good. MPI TD rails-good. 09:30 10:00 0.50 12,026 12,026 PROD1 WHPST RGRP T Clear and clean rig floor of welding equipment, man-basket,tethered tools. 10:00 12:00 2.00 12,026 12,026 PROD1 WHPST RGRP T PJSM. Clean, needle gun and prep TD roller wheels for MPI. Mag Particle inspect TD roller wheels. 12:00 12:30 0.50 12,026 12,026 PROD1 WHPST RGRP T Finish Mag Particle inspection of TD roller wheels-good. 12:30 13:30 1.00 12,026 12,026 PROD1 WHPST RGRP T Re-connect Kelly hose, secure in place, power up Top Drive. 13:30 13:45 0.25 12,026 12,026 PROD1 WHPST RGRP T Test run TD up the derrick while functioning Link-Tilt. Check adjustments-good. Page 58 of 77 Time Logs Date._ From To Dur S. Depth E. Depth Phase Code Subcode T 'Comment 13:45 16:00 2.25 12,026 12,026 PROD1 WHPST CIRC T CBU with 5 BPM, 1,570 psi. Perform derrick inspection while circulating. 16:00 19:00 3.00 12,026 9,475 PROD1 WHPST TRIP T POOH from 12,026'to 9,475'and on Trip tank. 19:00 19:15 0.25 9,475 9,475 PROD1 WHPST TRIP T Test Kelly hose to 3,500 psi-good. Blow down TD. 19:15 00:00 4.75 9,475 4,461 PROD1 WHPST TRIP T POOH from 9,475'to 4,461' and on Trip tank. 08/02/2014 Finish POOH with whip stock BHA and LD. PU cleanout assembly and RIH. Work bit and scraper thru tight area 14,930- 14,938'md. Continue to wash and ream in hole to TD. CBU. 00:00 04:45 4.75 4,461 286 PROD1 WHPST TRIP T Continue POOH from 4,461'to 286' and on Trip tank. Flow chk-static. Calc Fill=66.74,Actual=69.5 bbl. 04:45 07:30 2.75 286 0 PROD1 WHPST PULD T PJSM. LD whip stock and BHA. Flow chk-static. 07:30 08:30 1.00 286 0 PROD1 WHPST OTHR T Clear and clean rig floor. 08:30 11:00 2.50 0 46 PROD1 WHPST SFTY T Perform After Action Review on Laying Down whip stock. PJSM on MU cleanout BHA 11:00 12:00 1.00 46 994 PROD1 WHPST TRIP T RIH from 46'to 994' 12:00 20:00 8.00 994 14,124 PROD1 WHPST TRIP T Continue to RIH from 994'to 14,124' with bit and scraper cleanout assembly. 20:00 20:30 0.50 14,124 14,124 PROD1 WHPST CIRC T Mud weight in the DP vs annulus was out of balance and overflowing DP. Circulate at 3 BPM, 800 psi. 20:30 21:30 1.00 14,124 14,765 PROD1 WHPST TRIP T Continue to RIH from 14,124'to 14,765'. 21:30 23:30 2.00 14,765 15,150 PROD1 WHPST WASH T Wash and ream down from 14,765'to 14,930'with 3 BPM, 1,120 psi,40 RPM and 9K ft-lb TQ. Torque increased to 10.3K, and weight slacked off by 10-12K Ib, from 14,930'to 14,938'. Worked bit and 1 scraper through tight area 3x and continue to wash and ream to bottom, PU single. Shut down rotary and tag top of cement retainer at 15,150'md. PU=230K, SO=135K, ROT= 175K Ib,with 3 BPM and no rotary. Note: OA pressure=20 psi. 23:30 00:00 0.50 15,150 15,143 PROD1 WHPST CIRC T LD single CBU at 15,143 with 300 GPM, 3,480 psi while reciprocating pipe w/o rotary. 08/03/2014 Finish CBU,take SPRs and Flow-chk. POOH with cleanout BHA and LD. PU whip stock and RIH. Page 59 of 77 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 15,143 15,143 PROD1 WHPST CIRC T Continue 2.5x CBU at 15,143 with 300 GPM, 3,480 psi while reciprocating pipe w/o rotary. PU=210, SO= 133. Flow-chk- static. SPR- MP2- 2 BPM=520 psi, 3 BPM =810 psi 02:00 06:30 4.50 15,143 10,841 PROD1 WHPST TRIP T POOH of Trip tank from 15,143'to 10,841'. PU= 175K, SO= 120K. Had 15K overpull and 15K slackoff when passing the 7"liner tie-back with mills. Made 4x passes w/o rotary and tight spot cleaned up. Flow chk-static. 06:30 06:45 0.25 10,841 10,841 PROD1 WHPST CIRC T Pump 30 bbl. 10.9 ppg slug 06:45 12:00 5.25 10,841 2,420 PROD1 WHPST TRIP T POOH of Trip tank from 10,841'to 2,420'. PU=SO=85K. 12:00 13:30 1.50 2,420 46 PROD1 WHPST TRIP T POOH of Trip tank from 2,420'to 46'. Kick While Tripping Drill: CRT= 120 sec 13:30 13:45 0.25 46 46 PROD1 WHPST SFTY T PJSM on LD BHA 13:45 16:30 2.75 46 0 PROD1 WHPST PULD T LD bit, scraper and mills. All in gauge. Clear and clean the rig floor. 16:30 16:45 0.25 0 0 PROD1 WHPST SFTY T PJSM on PU whip stock assembly. 16:45 17:30 0.75 0 286 PROD1 WHPST PULD T PU whip stock BHA to 286' 17:30 00:00 6.50 0 7,868 PROD1 WHPST TRIP T RIH with whip stock BHA to 1,520', shallow pulse test MWD, continue RIH to 7,868', filling pipe every 2,000'. PU=SO= 105K lb OA-0 psi 08/04/2014 Finish RIH w/whip stock, orient and set. Mill window and 20'of new hole,to 15,165'md. Dress off window, CBU, Flow-chk, install RCD element, strip OOH. 00:00 06:30 6.50 7,868 14,365 PROD1 WHPST TRIP T Continue to RIH with whip stock BHA from 7,868 to 14,365', filling pipe every 2,000'. PU=220K, SO= 140K lb 06:30 08:30 2.00 14,365 15,100 PROD1 WHPST WASH T Wash down from 14,365'to 15,100' with 250 GPM, 3,050 psi(taking wt in multiple spots-10K). 08:30 08:45 0.25 15,150 15,132 PROD1 WHPST WPST T Orient whip stock 45R. PU=230, SO= 150K(pumps off). Slack off to 15,150'md, set down with 18K lb and shear setting pins for anchor. Pull 15K over to 245K and confirm anchor was set.. Slack off 65K lb and shear off whip stock. Note:TOW= 15,132'md, BOW= 15,145'and Page 60 of 77 l Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:45 12:00 3.25 15,132 15,145 PROD1 WHPST WPST T Mill window from 15,132'to 15,145' with 80 RPM, 9.5-12K TQ,250 GPM,3,000 psi, 8K WOB. PU=235K, SO= 135K, ROT= 155K, TQon= 10K,TQoff=9K at 15,165' md. Rig held Fire Drill. OA= 100 psi @1100 hrs SPR- MP2: 1.5 BPM =370 psi, 2.5=650 12:00 17:00 5.00 15,145 15,083 PROD1 WHPST WPST T Continue to mill window from 15,132' to 15,145'with 80 RPM, 9.5- 12K TQ,250 GPM, 3,000 psi, 8K WOB. Drill 20'of new formation with mill. Pump 39 bbl sweep. Pull back thru the window with pumps off. 17:00 19:00 2.00 15,083 15,083 PROD1 WHPST CIRC T CBU at 7 BPM, 3,980 psi. Pump 40 bbl"Super"sweep. Max gas=6 units on btms up. 19:00 19:30 0.50 15,083 15,083 PROD1 WHPST OWFF T Flow check for 30 min with the mud level dropping 3"below the flow line. 19:30 19:45 0.25 15,083 15,022 PROD1 WHPST CIRC T Pump out from 15,083 to 15,022'at 7 BPM, 3,980 psi pumping 40 bbl slug at 11.6 ppg. 19:45 20:45 1.00 15,022 15,022 PROD1 WHPST RURD T Lay down single, PU running tool and RCD element. RIH, set element and set down with 20K lb. Pull test with 20K lb tension-good. 20:45 00:00 3.25 15,022 12,766 PROD1 WHPST TRIP T Strip out of hole from 15,022 to 12,766'while pumping 2 BPM thru the Kill line and MPD equipment, holding 20-200 psi back pressure. OA=0 psi @ 2200 hrs X8/05/2014 Cont.to POOH w/MPD to 1,123'-R/D RCD element-Cont.to POOH&L/D mill assembly-M/U 6-1/8"Mill Assy& RIH to 8623'. 00:00 09:00 9.00 12,766 3,706 PROD1 WHPST TRIP T Strip out of hole from 12,766' MD to 3,706'MD'while pumping 2 BPM thru the Kill line and MPD equipment, holding 200-80 psi back pressure. 09:00 09:30 0.50 3,706 3,706 PROD1 WHPST TRIP T Check RCD integrity on 3 1/2"DP. Good. Change out elevators. Lay down X-O 09:30 12:00 2.50 3,706 1,123 PROD1 WHPST TRIP T Strip out of hole from 3706'MD' MD to 1123'MD'while pumping 2 BPM thru the Kill line and MPD equipment, holding 80-50 psi back pressure. OA pressure=l0 psi @10:40 hrs 12:00 12:45 0.75 1,123 1,123 PROD1 WHPST RURD T Remove RCD element 12:45 13:30 0.75 1,123 269 PROD1 WHPST TRIP T POOH from 1123'MD to 269'MD using trip tank. Page 61 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 15:30 2.00 269 0 PROD1 WHPST PULD T Lay down BHA as per SLB/Baker 15:30 16:15 0.75 0 0 PROD1 WHPST RURD T Clean rig floor. Lay down and pick up tools from beaverslide. 16:15 17:00 0.75 0 94 PROD1 WHPST PULD T PU 6.125"Starter Mill BHA to 94' MD. 17:00 19:30 2.50 94 3,514 PROD1 WHPST TRIP T TIH from 94'MD to 3514'MD. Fill pipe every 2000' 19:30 20:00 0.50 3,514 3,514 PROD1 WHPST SFTY T Safety standdown on pinched finger first aid. 20:00 20:45 0.75 3,514 3,514 PROD1 WHPST SVRG T Service rig and TD 20:45 00:00 3.25 3,514 8,623 PROD1 WHPST TRIP T TIH from 3514' MD to 8623' MD. Fill pipe every 2000' OA pressure=0 psi @ 2200 hrs. Recover 400 lbs. metal cuttings from shakers and magnets. 08/06/2014 Cont.to RIH to 14,700'. Cut&slip drill line. Cont.to RIH to window. Mill window and rat hole with 6 1/8"mill to 15,165'. Circulate Super Sweep. Pump out of hole to 13,160'. Strip out of hole to 7,014'. 00:00 06:15 6.25 8,623 14,722 PROD1 WHPST TRIP T Cont.to RIH w/6-1/8"mill assembly f/8,623'to 14,722'. Fill pipe every 20 stds 06:15 08:15 2.00 14,722 14,722 PROD1 WHPST SLPC T PJSM, Slip&cut 83'drill line. Service top drive, adjust brakes& cal. block height. 08:15 09:00 0.75 14,722 0 PROD1 WHPST TRIP T Cont.to RIH w/6-1/8"mill assembly f/14,722 to 15,097' Calc/Actual Disp=95/87 bbls 09:00 10:15 1.25 15,097 15,128 PROD1 WHPST WPST T Break circ w/250 gpm @ 2920 psi. Establish base torque&drag parametrs&wash in hole f/15,097'to 15,128'. Ream through window&rat hole f/15,128'to 15,163'.Work through window w/out pumps(good). Pull up above window @ 15,128' 10:15 12:00 1.75 15,128 15,128 PROD1 DRILL CIRC T Pump 34 bbls super sweep&circ clean w/250 gpm @ 2780 psi. OA=0 psi @11;00 hrs. 12:00 12:30 0.50 15,128 15,128 PROD1 DRILL OWFF T Flow Check(static) 12:30 12:45 0.25 15,128 15,097 PROD1 DRILL CIRC T Pump OOH f/15,128'to 15,097'while pumping 40 bbls 11.6 ppg dry job 12:45 13:30 0.75 15,097 15,097 PROD1 DRILL RURD T PJSM&install RCD element 13:30 14:00 0.50 15,097 15,097 PROD1 DRILL CIRC T First dry job did not take. Pump 2nd 40 bbls 11.6 ppg dry job(good) 14:00 15:00 1.00 15,097 14,480 PROD1 DRILL TRIP T POOH as per MPD trip schedule f/15,097'to 14,450'. Started taking weight w/15-40 k max.Appeared we are dragging an obstruction or cuttings bed up hole.Work pipe down to 14,480. PU=235K SO=135K @15,050. 15:00 15:15 0.25 14,480 14,537 PROD1 DRILL SFTY T Call town&decision made to Pump out of hole while circulating casing clean. PJSM on pumping out of hole Page 62 of 77 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 15:15 20:00 4.75 14,537 13,160 PROD1 DRILL TRIP T Pump OOH no rotation w/250 gpm @ 2800-2100 psi f/14,537''to 13,160'. 20:00 20:30 0.50 13,160 13,160 PROD1 DRILL CIRC T Circulate out previously pumped dry jobs. 9.6 ppg in and out. Pump 35 bbl. 11.6 ppg dry job. Line up on MPD. 20:30 00:00 3.50 13,160 7,014 PROD1 DRILL TRIP T POOH as per MPD trip schedule from 13,160'to 7,014'. OA=0 psi. @ 22:00 hrs 38/07/2014 Cont to strip out of hole to 757'. Remove RCD element. TOH&lay down mill BHA. L/D 4" HWDP. M/U motor BHA. TIH to 9,285'. 00:00 05:15 5.25 7,014 757 PROD1 DRILL TRIP T Cont.to POOH f/7,014'to 757'as per MPD tripping schedule 05:15 05:30 0.25 757 757 PROD1 DRILL RURD T PJSM-L/D RCD element 05:30 06:15 0.75 757 94 PROD1 DRILL TRIP T Cont. to POOH f/757'to 94' Calc/Actual Disp. =89.44/92 bbls 06:15 08:30 2.25 94 0 PROD1 DRILL PULD T Clean string magnets&L/D 6-1/8" milling BHA as per Baker 08:30 11:00 2.50 0 0 PROD1 DRILL RGRP T Clear&clean floor. Reseal riser to drip pan under rig floor while waiting on SLB tools 11:00 13:30 2.50 0 0 PROD1 DRILL PULD T Change out elevetors&prep to L/D 4"HWDP. L/D 17 stds 4"HWDP from derrick OA=0 psi @ 11:00 hrs. 13:30 14:00 0.50 0 0 PROD1 DRILL SVRG T Clean rig floor. Install skate roller. 14:00 14:15 0.25 0 0 PROD1 DRILL SFTY T PJSM on making up BHA 14:15 16:45 2.50 0 275 PROD1 DRILL PULD T Make up BHA#15 as per SLB DD/MWD to 275'. 16:45 00:00 7.25 275 9,285 PROD1 DRILL TRIP T TIH as per tripping schedule from 275'to 9,285'. Fill pipe every 2000'. Strap 17 stds 3 1/2"DP in derrick. PU= 145K SO=112K @9,285' Calc.disp=55.37 bbls Act.disp=58 bbls OA=O psi @22:00 hrs 38/08/2014 Cont.TIH to TOW. Install RCD. Orient motor and pass through window. Drill f/15,165'to 15,195'. Pull into casing. Condition mud. Perform LOT to 12.2 ppg. RIH and drill to f/15,195'to 15,265'. Circ clean. Pump OOH into casing. Flow check&pump slug. POOH as per MPD schedule to 12,498' 00:00 05:15 5.25 9,285 14,989 PROD1 DRILL TRIP T Cont.to RIH f/9,285'to 14,989'. Fill pipe every 20 stds. PU wt 210 k, SO wt132k Calc/Actual Disp=87.75/99 bbls 05:15 06:00 0.75 14,989 14,989 PROD1 DRILL RURD T Install RCD element 06:00 07:00 1.00 14,989 15,165 PROD1 DRILL TRIP T Cont.to RIH f/14,989'to 15,051'. Break circ&orient motor to 45 deg right w/200 gpm @ 2530 psi. RIH thru window without pumps f/15,051' to 15,154'.Wash in hole w/200 gpm @ 2590 psi f/15,154'to TD of 15,165' 1 Page 63 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 07:00 09:00 2.00 15,165 15,195 PROD1 DRILL DDRL T Drill ahead/15,165'to 15,195' MD/ 7,493'TVD,ADT w/100%slide= 1.10 hrs 09:00 09:30 0.50 15,195 15,112 PROD1 DRILL TRIP T Orient motor to 45 deg right&pump out of hole f/15,195'to 15,112'w/3 bpm&no rotation. Pull thru window w/no pumps f/15,145'to 15,125'. PU wt 200 k 09:30 10:45 1.25 15,112 15,122 PROD1 DRILL CIRC T Circ&cond mud for LOT/FIT w/200 gpm©2590 psi&no rotation 10:45 11:30 0.75 15,122 15,122 PROD1 DRILL LOT T Perform LOT to 12.22 ppg @ 1020 psi 11:30 12:15 0.75 15,122 15,195 PROD1 DRILL TRIP T RIH(/15,125'to TD of 15,195' OA=80 psi @ 12:00 hrs. SPR#1 20=580 psi 30=870 psi SPR#2 20=550 psi 30=860 psi 15, 129' MD, 7,483'TVD @ 12:00 hrs. 12:15 15:00 2.75 15,195 15,265 PROD1 DRILL DDRL T Drill ahead/15,195'to 15,265' MD/ 7,492'TVD, 60 rpm, 15K WOB, 200 gpm, 2770 psi.ADT= 1.32 hrs. ART=.87 hrs. AST=1.32 hrs. 15:00 17:00 2.00 15,265 15,238 PROD1 DRILL CIRC T Lay down one jt. DP. Circ and cond for TOH. 200 gpm, 2560 psi, 60 rpm, 7.5 to 9K tq. 17:00 18:00 1.00 15,238 15,051 PROD1 DRILL TRIP T P/U one jt. DP and pump out of hole to 15,051. Cease pumping while pulling through window. 3 bpm=940 psi. 18:00 20:30 2.50 15,051 15,051 PROD1 DRILL OWFF T Monitor well. Slight flow observed. 16 gals/hr initial rate diminishing to 4 gals/hr in 20 mins.Well static after additional 90 mins. Monitor static well f/30 mins. 20:30 21:00 0.50 15,051 15,051 PROD1 DRILL CIRC T Pump 34 bbl. dry job. Blow down TD. Line up to pump through kill line. 21:00 23:00 2.00 15,051 13,537 PROD1 DRILL PULD T Lay down 4"DP as per MPD trip schedule 15,051 to 13,537 23:00 00:00 1.00 13,537 12,498 PROD1 DRILL TRIP T POOH as per MPD trip schedule 13,537'to 12,498'. OA=0 psi @ 23:45 08/09/2014 Cont.to strip out of hole to 1,000'. Remove RCD element. Cont.to POOH& L/D motor BHA. Test B.O.P.'s 00:00 08:45 8.75 12,498 4,190 PROD1 DRILL TRIP T Cont.to POOH as per MPD trip schedule f/12,498'to 4,190' 08:45 10:00 1.25 4,190 4,190 PROD1 DRILL RGRP T Repair mud bucket discharge hose 10:00 12:15 2.25 4,190 1,190 PROD1 DRILL TRIP T Cont.to POOH as per MPD trip schedule f/4,190'to 1,190' OA=O psi @11:30 hrs 12:15 13:00 0.75 1,190 1,190 PROD1 DRILL RURD T Remove RCD element. Flow check (static) 13:00 14:30 1.50 1,190 184 PROD1 DRILL TRIP T Cont. to POOH on TT f/1,190'to 184'. Racked back HWDP, jars&NMFC. 14:30 17:15 2.75 184 0 PROD1 DRILL PULD T L/D mud motor BHA as per SLB. Calc disp=90.9 bbls Act disp=99.5 bbls Page 64 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:15 18:45 1.50 0 0 PROD1 DRILL RURD T (Clean and clear rig floor. Lay down MPD tools. SIMOPS-Perform derrick inspection. Monitor well with closed blind rams. Static 18:45 19:15 0.50 0 0 PROD1 DRILL PULD T P/U and reconfigure SLB Power Drive. L/D same. 19:15 20:45 1.50 0 0 PROD1 WHDBO RURD T Change out elevators. Drain BOP, pull wear ring. Make up BOP washer, flush BOP with LVT. Blow down top drive,drain BOP. 20:45 22:30 1.75 0 0 PROD1 WHDBORURD T Set test plug. Rig up to test BOPE 22:30 00:00 1.50 0 0 PROD1 WHDBO BOPE T Test BOPE.w/4"test jt.4"Demco Kill line valve, Choke and kill HCR and Manual choke valve 250/3500 psi -Test annular to 250/2500 psi, Test upper&lower rams(3 1/2"x 6" VBR's)to 250/3500 psi.Auto and Lower IBOP,to 250/3500 psi - Performed accumulator recovery test -200 psi in 39 sec's.full pressure (3,000 psi)in 195 sec's with 4X 2,000 psi on accumulator bottles.-Chuck Sheve of the AOGCC waived witnessing of test. Choke manifold tested on TOH. OA=0 psi@23:00 hrs. 08/10/2014 Cont.to test B.O.P.'s. M/U 6-1/8"RSS BHA&single in hole with 3-1/2"DP to 7,896'. 00:00 04:45 4.75 0 0 PROD1 WHDBO BOPE T Cont.to test B.O.P.'s. Test w/3-1/2" &4-1/2"test jts,Annular to 250/2500 psi&3-1/2"x6"VBR's to 250/3500 psi&chart for 5 min,Test 4"dart&FOSV, 3-1/2"dart& FOSV, manual kill&blind rams to 250/3500 psi&chart for 5 min. Koomey Test 200 psi in 39 sec&full system pressure of 3000 psi in 195 sec. Test waived by AOGCC Chuck Sheve. 04:45 06:00 1.25 0 0 PROD1 WHDBO RURD T Pull test plug&install wear ring. Break down floor valves. Blow down lines 06:00 09:00 3.00 0 0 PROD1 DRILL RGRP T PJSM. Change out saver sub on top drive 09:00 12:00 3.00 0 295 PROD1 DRILL PULD T M/U 6-1/8"RSS BHA as per SLB to 295'Change out jars 0A=0 psi. @ 11:00 hrs. 12:00 15:00 3.00 295 1,717 PROD1 DRILL PULD T RIH w/picking up 3-1/2"drill pipe from pipe shed from 295'to 1,717'. Kick w/Tripping Drill. CRT=280 sec's 15:00 15:30 0.50 1,717 1,717 PROD1 DRILL DHEQ T Shallow pulse test MWD. 195 gpm=1750 psi 15:30 00:00 8.50 1,717 7,896 PROD1 DRILL PULD T RIH w/picking up 3-1/2"drill pipe from pipe shed from 1717'to 7,896', Fill pipe every 60 jts. PU=128K SO=105K @ 7,896'. Page 65 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/11/2014 24 hr Summary Cont.to pick up 3 1/2"DP to 8,658. RIH w/3 1/2"DP f/derrick to 14,931'. C/O handling equip to 4". Circ B/U. Install RCD element. Slip&cut drill line. RIH w/4"DP to 15,265'. Drill ahead to 15,593" 00:00 01:00 1.00 7,896 8,658 PROD1 DRILL PULD T Cont.to RIH w/picking up 3-1/2"drill pipe from pipe shed f/7,896'to 8,658'. Fill pipe every 60 jts 01:00 07:30 6.50 8,658 14,931 PROD1 DRILL TRIP T RIH w/3 1/2"DP stands f/8,658'to 14,931'. Fill pipe every 20 stands 07:30 08:30 1.00 14,931 15,028 PROD1 DRILL RURD T Change out handling equipment from 3 1/2"to 4". M/U XO. M/U RCD element to 1st stand of 4"DP. Install RCD element 08:30 10:45 2.25 15,028 15,028 PROD1 DRILL CIRC T Circ&cond mud w/165 gpm @ 2800 -2560 psi w/60 rpm @ 7-8 k trq. Max gas 1457 units&heavy calcium carbonate sagged mud on B/U 10:45 12:45 2.00 15,028 15,028 PROD1 DRILL SLPC T PJSM-Slip&cut 60'drill line& service top drive OA=0 psi @ 11:00 12:45 13:30 0.75 15,028 15,028 PROD1 DRILL SVRG T Service top drive and drawworks. Blow down kill line. 13:30 14:15 0.75 15,028 15,159 PROD1 DRILL TRIP T RIH from 15,028'to 15,159'. 14:15 15:45 1.50 15,159 15,265 PROD1 DRILL REAM T Wash and ream from 15,159'to 15,265'. 150-193 gpm, 2030-3180 psi, 30-60 rpm, 8K tq. SPR#1 20 spm=750 psi 30 spm=1230 psi SPR#2 20 spm=790 psi 30 spm=1230 psi @ 15,216'MD, 7,492' TVD 15:45 18:00 2.25 15,265 15,363 PROD1 DRILL DDRL T DrIg. from 15,265'to 15,363'. 7,487' TVD.ADT=1.45 18:00 18:45 0.75 15,363 15,240 PROD1 DRILL REAM T Back ream out of hole. From 15,363' to 15,240. 193 gpm, 3190 psi, 120 rpm, 8K tq 18:45 19:15 0.50 15,240 15,028 PROD1 DRILL TRIP T POOH from 15,240'to 15,028' 19:15 20:00 0.75 15,028 15,363 PROD1 DRILL REAM T Wash in hole from 15,028'to 15,240'. 193 gpm=3120 psi.Wash and ream from 15,240'to 15,363'. 193 gpm=3130 psi.60 rpm, 8K tq. 20:00 00:00 4.00 15,363 15,593 PROD1 DRILL DDRL T Drlg from 15,363'to 15,593'. 7,503' TVD. PU=193K, 50=110K, Rot=145K, Tq on=8.5K,Tq off=7.5K WOB=8-10K ADT=3.46 Jar #1400-1023 Total hrs=4.91 0A=260 psi @23:00 hrs. 38/12/2014 Drill ahead f/15,593'to 17,081' 00:00 12:00 12.00 15,593 16,326 PROD1 DRILL DDRL T Directional drill 6 1/8"lateral f/15,593' to 16,326'7,522'TVD. PU=195K, 50=107K, Rot=145K, Tq on=9.5K, Tq off=8K WOB=8-10K ADT=8.4 OA=550 psi Page 66 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 16,326 17,081 PROD1 DRILL DDRL T Directional drill 6 1/8"lateral f/16,326' to 17,081'7,526'TVD. PU=200K, 'SO=104K, Rot=148K, Tq on=10K, Tq off=8K WOB=8-10K ADT=8.6, 185 gpm @ 3210 psi OA=620 psi 08/13/2014 Drill ahead f/17,081'to 18,180' RPM downlink comnmands @ 17,520' 00:00 12:00 12.00 17,081 17,595 PROD1 DRILL DDRL T Drill Ahead f/17,081'to 17,595'7,536' TVD. PU=207K, SO=100K, Rot=145K, RPM 150, Tq on=10.5K, Tq off=9K WOB=8-12K ADT=8.26, 185 gpm @ 3090 psi OA=710 psi RPM down linking @ 17,520' 12:00 00:00 12.00 17,595 18,180 PROD1 DRILL DDRL T Drill Ahead f/17,595'to 18,180'7,538' TVD. PU=205K, SO=105K, Rot=146K, RPM 150, Tq on=10.5K, Tq off=9.5K WOB=5-8K ADT=8.37, 193 gpm @ 3420 psi OA= 120 psi(Bleed off 70 gal to 0 psi @ 13:45) OBM loss of 0.9-1 bbl per hr for 23 bbls total past 24 hrs @ Balance building 80-90 psi on connections 08/14/2014 Drill ahead f/18,180'to 19,293'. POOH to 19,287'&Troble shoot MWD tools(tool failure).Well TD'd @ 19,293'. Circ&cond.f/19,287'to 19,095' 00:00 12:00 12.00 18,180 18,871 PROD1 DRILL DDRL T Drill Ahead f/18,180'to 18,871'- 7,553'TVD. PU=215K, SO=90K, Rot=145K, RPM 150,Tq on=12.2K, Tq off=10.1 K WOB=10/14K ADT=9.26, 185 gpm @ 3160 psi OA= 150 psi @ Balance building 100-125 psi on connections 12:00 21:00 9.00 18,871 19,293 PROD1 DRILL DDRL T Drill Ahead f/18,871'to 19,293'- 7,556'TVD. (MWD tool Failure) PU=215K, SO=95K, Rot=147K, RPM 150,Tq on=13K, Tq off=11.5K WOB=12/14K ADT=5.91, 185 gpm @ 3330 psi © Balance building 100- 125 psi on connections Page 67 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 23:00 2.00 19,293 19,287 PROD1 DRILL CIRC T Rack back partial stand f/19,293'to 19,287'. Circ w/185 gpm @ 3350 psi &w/150 rpm @ 10.5 k trq&trouble shoot MWD tools. Periscope resistivity not working, decesion made to call well TD'd @ 19,296'&POOH for liner& completion 23:00 00:00 1.00 19,287 19,095 PROD1 CASING CIRC P Circ&cond. (/19,287'to 19,095' w/190 gpm @ 3200 psi&w/120 rpm @ 11 k trq. Racking back 1 stand every 30 min @ Balance holding 150 psi on connections OA=210 psi 08/15/2014 Cont.to circ clean while reaming out of hole f/19,095'to 18,433'. Gas not decreasing. RIH to 19,293'. Circ B/U. BROOH f/19,296'to 15,419'while holding 250 psi back pressure on connections. 00:00 05:15 5.25 19,095 18,433 PROD1 CASING CIRC P Cont.to circ clean f/19,095'to 18,433'w/185 gpm @ 3220 psi& w/120 rpm @ 11 k trq. Racking back 1 stand every 30 min. @ Balance trapping 150 psi on connections. 150 psi not enough back pressure and chokes 20%open. Gas not decreasing. Decesion made to go back to bottom&circ out gas& _ increase back pressure. 05:15 08:30 3.25 18,433 19,293 PROD1 CASING REAM T RIH f/18,433'to 19,293'w/180 pgm @ 3130 psi&w/90 rpm @ 9.5 k trq. @ Balance holding 200 psi as per trip schedule. 08:30 10:30 2.00 19,293 19,293 PROD1 CASING CIRC T Circ B/U w/185 gpm @ 3300 psi& w/90 rpm @ 9.5 k trq. ECD 10.67 (3770 units max gas on B/U) 10:30 00:00 13.50 19,293 15,419 PROD1 CASING REAM P BROOH f/19,293'to 15,419'w/185- 190 gpm @ 3330-3070 psi&w/120 rpm @ 8-12 k trq. @ Balance holding 250 psi back pressure on connections as per trip schedule. Work thru tight hole f/15,445'to 15,419'. Hole attempting to pack off &stall top drive. 38/16/2014 Pump OOH to inside casing @ 15,122'. Circ B/U. Monitor psi&move DP in derrick.Wt up to 10.2ppg& POOH as per MPD schedule f/15,122'to 3,808' 00:00 02:00 2.00 15,419 15,354 PROD1 CASING REAM P Cont.to BROOH f/15,419'to 15,354' w/190-155 gpm @ 3090-2080 psi &w/120 rpm @ 7.5-13 k trq. Hole packing off and stalling top drive. Working tight hole with no success Page 68 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 03:00 1.00 15,354 15,122 PROD1 CASING TRIP P Pump out of hole f/15,354'to 15,122' w/2-2.5 bpm @ 720-920 psi. PU wt 195k, SO wt 115k, ROT wt 145k, Max excess drag 20-25 k 03:00 05:00 2.00 15,122 15,122 PROD1 CASING CIRC P Circ B/U w/190 gpm @ 3060 psi& w/120 rpm @ 8 k trq. No gas on bottoms. 05:00 08:45 3.75 15,122 15,122 PROD1 CASING OWFF P Monitor well for pressure build up to determine trip out mud wt. Initial 105 psi&final 176 psi SIMOPS-PJSM&shuffle 4"DP f/ODS to DS&rabbit each stand,45 stands total 08:45 11:15 2.50 15,122 15,122 PROD1 CASING CIRC P Circ&wt up active system f/9.6 ppg to 10.2 ppg w/190-160 psi @ 2930- 2370 psi&w/100 rpm @ 7.5 k trq (11.1 max ECD at bit) 11:15 12:15 1.00 15,122 15,122 PROD1 CASING OWFF P Observe well for floow. @ Balance close both chokes&no psi increase. Open chokes&monitor well for flow, slight ooze than static. 12:15 13:00 0.75 15,122 15,122 PROD1 CASING CIRC P SPR's&pump 38 bbls 13.2 ppg dry job. B/D top drive&line up to kill line 13:00 13:15 0.25 15,122 14,931 PROD1 CASING TRIP P POOH as per MPD trip schedule f/15,122'to 14,931'(RCD element leaking on 3 1/2"DP¬ able to mainatin proper back psi) 13:15 15:45 2.50 14,931 14,931 PROD1 CASING RURD T Change out handling equipment f/4" to 3 1/2". R/U&pull 4"RCD element.Attemept to M/U new 4" RCD element on DP w/no success. P/U RCD stabbing guide&M/U RCD element. Install new element, pull test(good)&R/D RCD install equipment 15:45 20:45 5.00 14,931 7,992 PROD1 CASING TRIP P POOH as per MPD trip schedule f/14,931'to 7,992'. @ Balance holding 325-280 psi. Pipe started pulling wet 20:45 21:45 1.00 7,992 7,992 PROD1 CASING SVRG P Service rig,top drive&draw works while mix&pump 2nd 35bbls of 13.3 _ ppg dry job 21:45 00:00 2.25 7,992 3,808 PROD1 CASING TRIP P Cont.to POOH as per MPD trip schedule f/7,992'to 3,808'. @ Balance holding 300-225 psi. 08/17/2014 Cont.to POOH as per MPD schedule to 1,000'&remove RCD element. POOH on TT&UD 6 1/8"RSS BHA. R/U to run 4 1/2"lower completion. RIH lower completion to seal bore extension @ 4,279'. Pack off seals would not go thru seal bore extension. Seals stuck in SBE. L/D 3 1/2"DP while wait on new SBE&pack off seals from Deadhorse 00:00 01:45 1.75 3,808 1,050 PROD1 CASING TRIP P Cont.to POOH f/3,808'to 1,050'as per MPD trip schedule 01:45 02:30 0.75 1,050 1,050 PROD1 CASING RURD P PJSM&remove RCD element 02:30 02:45 0.25 1,050 1,050 PROD1 CASING OWFF P Flow Check(static) 02:45 03:45 1.00 1,050 295 PROD1 CASING TRIP P POOH on TT f/1,050'to 295' Page 69 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:45 06:15 2.50 295 0 PROD1 CASING PULD P PJSM&UD 6 1/8"RSS BHA as per SLB Calc/Act Hole Fill= 111.65/195 bbls 06:15 07:15 1.00 0 0 COMPZ CASING PULD P Clear&clean floor. L/D directional tools via Beaver Slide 07:15 08:45 1.50 0 0 COMPZ CASING RURD P P/U tubing tools&equipment. PJSM. R/U to run 4 1/2"liner lower completion 08:45 18:30 9.75 0 4,279 COMPZ CASING RNCS P PJSm. RIH hole with 4 1/2"lower completion as per detail to 4,279' 18:30 22:15 3.75 4,279 4,279 COMPZ CASING RNCS T RIH w/sealbore extension(SBE)& M/U pack off seals to liner/hanger packer assembly.Attempt to run pack off seals into SBE. Pack off seals hanging up in SBE. Re-position slips&dog collar on SBE&attempt to run pack off seals into SBE w/no success¬ able to get past 5'into SBE. Change out slips&re-try w/no success¬ able to get past 3'into SBE.Attempt to pull out of SBE w/pack off seals& seals stuck+/-3'down in SBE. Attempt to free stuck pack off seals w/no success. Decision made to release pack off seals from liner hanger/packer assembly&L/D SBE. Call in hot shot for new SBE&pack off seals from Baker shop in Deadhorse. 22:15 22:45 0.50 4,279 4,279 COMPZ CASING RURD T Clear&clean floor&R/U to L/D 3 1/2"DP from derrick while waiting on new SBE. 22:45 00:00 1.25 4,279 4,279 COMPZ CASING PULD P L/D 8 stands 3 1/2"DP from derrick 08/18/2014 Cont.to UD 3 1/2"DP while waiting on new SBE(20 stands total). M/U SBE&liner hanger/packer. Circ B/U. RIH w/4 1/2"lower completion on 4" DP to 15,063. Install RCD element. Circ&cond. mud while P/U 4" HWDP&rack back in derrick w/2 bpm @ 640 psi 00:00 01:45 1.75 4,279 4,279 COMPZ CASING PULD P L/D 12 stands(20 stds total)3 1/2" DP from derrick while wait on new SBE from Deadhorse 01:45 03:00 1.25 4,279 4,279 COMPZ CASING RNCS P PJSM, M/U SBE&liner hanger packer assembly(no issues with pack off seals&SBE). Mix&pour pal mix 03:00 04:00 1.00 4,279 4,377 COMPZ CASING RURD P Wait on pal mix to set. SIMOPS R/D power tongs&equipment. C/O 3 1/2"elevators to 4". M/U XO&RIH with single jt&RIH w/liner hanger& single joint 4"DP to 4,377' 04:00 04:45 0.75 4,377 4,377 COMPZ CASING CIRC P Circ. &cond. mud(2x liner volume) w/5 bpm @ 670 psi. Liner wt PU 100k SO 90k Page 70 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:45 11:45 7.00 4,377 9,301 COMPZ CASING RUNL P RIH w/liner f/4,377'to 9,301'while single in hole with 4"DP from pipe shed. Fill pipe every 20 stands 11:45 18:30 6.75 9,301 15,063 COMPZ CASING RUNL P RIH w/liner f/9,301'to 15,063'with 4" DP from derrick. Fill pipe every 20 stands PU 212k/SO 90k 18:30 20:30 2.00 15,063 15,063 COMPZ CASING RURD P PJSM, P/U stabbing guide&Install RCD element. M/U TIW valve, head pin&cement hose 20:30 00:00 3.50 15,063 15,063 COMPZ CASING PULD P P/U 4"HWDP f/pipe shed&rck back in derrick(17 stands total)- Circ&cond mud w/2 bpm @ 640 psi 08/19/2014 Liner did not make it past 15,240'.Worked tight hole&pulled liner back to shoe @ 15,063'. Circulating inside casing w/2bpm @ 750 psi.Team meeting to determine plan forward.Wash liner thru tight spots to 15,460'. Rotate and wash liner down to 17,300'. Slide swell packers thru window without rotating to 17,426'. 00:00 00:30 0.50 15,063 15,063 COMPZ CASING RURD P RD circ equip 00:30 01:15 0.75 15,063 15,250 COMPZ CASING RUNL P Obtain parameters, 215K up, 125K dwn, 160K rot, 30 rpm, 9.5K tq, RIH thru window,taking wt from 15180', attempt work in hole w/o pump w/ 25-50K dwn 01:15 01:45 0.50 15,221 15,244 COMPZ CASING RUNL P MU TD at 15221',attempt to rot down w/o pump,w/30 rpm, 10-14K tq, could not get past 15244' 01:45 02:00 0.25 15,244 15,244 COMPZ CASING RUNL T Attempt break circ at.5 bpm, pressure to 630 psi, no returns. Decision made to POOH t/7"casing to regain circ 02:00 03:00 1.00 15,244 15,063 COMPZ CASING TRIP T POOH w/hold 250 psi back pressure on MPD from 15244 to 15063' (100K over at 15197') 03:00 06:15 3.25 15,063 15,063 COMPZ CASING CIRC T Circulate with out problem and condition mud, stage pump to 2 bpm, 520-610 psi, 30 rpm, 9.5K tq. Max MW out= 10.8 ppg. No gas. 06:15 12:00 5.75 15,063 15,460 COMPZ CASING RUNL P Wash 4-1/2"liner down from 15,063 - 15,460'and w/2 BPM, 520-610 psi. Work thru shale section and 15 deg DL. PU=215, SO= 125K 12:00 16:45 4.75 15,460 16,135 COMPZ CASING RUNL P Wash down from 15,460-16,135'and w/2 BPM, 630-720 psi. continue to work thru tight spots. PU=220, SO= 120K 16:45 23:30 6.75 16,135 17,300 COMPZ CASING RUNL P Wash and ream 4-1/2"liner down from 16,135-17,300'and w/1.3-1.6 BPM, 600-750 psi, 30 RPM, 10-12K ft-lb TQ. PU=225-240K, S0= 120- 100K 23:30 00:00 0.50 17,300 17,426 COMPZ CASING RUNL P Wash 4-1/2"liner down from 17,300- 17,426'and w/2 BPM, 660 psi.Slide swell pkr thru window w/o rotation. PU=230, SO= 115K Page 71 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/20/2014 24 hr Summary Finish running liner to TD, break circ, CBU, drop ball and pump down to WIV, Pressure up to 2,000 psi, slacked off with 60K to verify hanger was set. Work 3 wraps,followed by 6 wraps into drill string(3.5K surface TQ), PU to 275K(50K OP)and observe shear set of liner hanger. PU to 215K to verify released. Continue to SO and weight set liner top pkr. Press test WIV to 2,500 psi for 30 min-good, press test liner top pkr to 2,000 psi for 30 min-good. Pump spacers and displace MOBM from well. Flow chk for 30 min- static. POOH laying down 28 stds of 4"HWDP/DP, pull RCD element, POOH laying dwn 4"HWDP/DP to 12,325'md. 00:00 07:00 7.00 17,426 19,268 COMPZ CASING WASH P Continue washing 4-1/2"liner down from 17,426-19,268' and w/2-2.25 BPM, 680-730 psi. 07:00 07:30 0.50 19,268 19,293 COMPZ CASING RUNL P PU at 19,268'and break over at 285K. PU=260K, SO= 135K. RIH and tag bottom at 19,293'and with 2 BPM and 730 psi. 07:30 10:15 2.75 19,268 19,293 COMPZ CASING CIRC P CBU with 2-3 BPM, 750-1,080 psi. Max Gas= 1,200 units,After CBU, gas=400 units. 10:15 11:30 1.25 19,268 19,268 COMPZ CASING HOSO P Drop 1.5"liner setting ball. Pump ball down with 3 BPM, 1,100 psi, decreasing to 2 BPM, 730 psi and 1 BPM,400 psi and land ball on seat with 164 bbl pumped. Pressure up to 900 psi and hold for 5 min, pressure up to 2,000 psi setting pressure. Continue to hold pressure and slack off 60K lb and verify DG Flex-lock III liner hanger was set. TOL= 14,952' md. 11:30 12:15 0.75 19,268 19,268 COMPZ CASING PRTS P Pressure test liner/WIV to 2,500 psi for 30 min-good. 12:15 13:30 1.25 19,268 19,268 COMPZ CASING HOSO T PU to 265K with no breakover. SO to 75K(block weight), pressure up to 2,700 psi and bled off. PU to 265K without weight breaking over. SO to 75K blk wt. Pressure up to 2,800 psi and bleed off. SO to 65K and PU to 285K-not released from liner. Press up to 2,900 psi, SO to 60K, press up to 3,000 psi, PU to 280K, no break over. SO to 60K blk wt and bleed off pressure. 13:30 15:00 1.50 19,268 14,952 COMPZ CASING PACK P Attempt emergency release.Work 3.75 wraps into drill string(3.5K surface TQ), PU to 275K, no break over in wt.Work 4 wraps(2.5K surface TQ), PU to 275K w/no break over. Line up and hold 250 back press with MPD equip and 2 BPM. Work 5 wraps into string(3K TQ), PU to 275K w/o break over.Work 6 wraps(3.5K TQ), PU to 215K, SO to 130K and observe shear release off liner. Continue SO to 75K and set pkr. Release TQ from drill string. PU and break over with PU=245K and verify released.TOL at 14952.31" Page 72 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:15 0.25 14,952 14,952 COMPZ CASING RURD P PJSM. Line up to press test packer. 15:15 16:15 1.00 14,952 14,952 COMPZ CASING PRTS P Pressure test liner top pkr to 2,000 psi for 30 min-good. Bleed off press, line up to pump down DP. 16:15 17:00 0.75 14,952 14,935 COMPZ CASING PULD P LD single while POOH holding 500 psi back press and verify free from liner hngr. Continue POOH and LD 2x singles 17:00 19:30 2.50 14,952 14,935 COMPZ CASING DISP P PJSM for displacing MOBM to seawater. Pump 66 bbl transition spacer, 36 bbl cleaning spacer and 30 bbl tail spacer. Displace well to seawater. ICP= 1,760 psi w/5 BPM, FCP= 1,740 psi at 7 BPM. PU= 310K, SO= 130K with seawater. 19:30 21:00 1.50 14,935 14,935 COMPZ CASING OWFF P Blow dwn TD. Flow chk(neg test)for 30 min-static. Clean out under shakers, flush MPD lines. 21:00 00:00 3.00 14,935 12,325 COMPZ CASING PULD P POOH from 14,935'to 12,325'md, laying down 17 stds of 4"HWDP and 11 stds of 4"DP. Fill hole via the Kill line. PU=225K, SO= 120K lb. 38/21/2014 Finish POOH and LD 4"DP. LD liner running tool. Change out wear ring, RU and run 3-1/2"tubing completion assembly w/I-wire to 1,234'. 00:00 00:30 0.50 12,325 11,892 COMPZ CASING PULD P POOH from 12,325'to 11,892'md, laying down 4"DP. Fill hole via the Kill line. PU=222K, SO= 118K lb. 00:30 01:00 0.50 11,892 11,892 COMPZ CASING PULD P PJSM. Pull RCD element and LD. 01:00 01:15 0.25 11,892 11,892 COMPZ CASING OWFF P Flow-chk. Static. 01:15 02:45 1.50 11,892 11,892 COMPZ CASING SLPC P PJSM. Slip and Cut 75'of DL. Service TD and draworks. 02:45 12:00 9.25 11,892 1,468 COMPZ CASING PULD P POOH from 11,892'to 1,468'md, laying down 4"DP. PU=SO=75K lb. 12:00 13:30 1.50 1,468 0 COMPZ CASING PULD P POOH from 1,468'to surface, laying down 4"DP. 13:30 14:15 0.75 1,468 0 COMPZ CASING PULD P Change out elevators to 3-1/2", LD Liner running tool,c/o elevators to 4" and LD one std of 4"DP via the mouse hole. 14:15 14:45 0.50 0 0 COMPZ RPCOM RURD P PJSM. PU test joint,drain stack and pull wear bushing. 14:45 17:00 2.25 0 0 COMPZ RPCOM PULD P LD tools from rig floor. Clear and clean floor, PU csg equipment and control line spool. (blow down MPD lines). 17:00 19:00 2.00 0 0 COMPZ RPCOM RURD P Hang sheaves for I-wire and control line in derek. PU Canon clamps and stage completion equipment. RU csg power tongs. Page 73of77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:00 00:00 5.00 0 1,234 COMPZ RPCOM RCST P PJSM. RIH with GBH-22 seal assembly, 3-1/2", 9.3 lb/ft, L-80, EUE tbg, 3-1/2"X-nipple, 3-1/2"EUE tbg,gauge mandrel. Connect I-wire and test-good. Continue running 32 jts of 3-1/2", 9.3#, L-80 EUE tbg, 3-1/2"x 1"KBMG GLM w/DV, BK-5 latch. 34 jts of 3-1/2"tubing to 1,234', installing Canon clamps at all tbg connections and testing I-wire every 25 jts. MU 3-1/2"EUE to 2,600 ft-lb with Run-N-Seal thread compound. 08/22/2014 Continue to run 3-1/2"tbg completion, locate in seal assembly,test to 1,000 psi, un-sting from seals,spot corrosion inhibitor, space out, land tbg. 00:00 12:00 12.00 1,234 7,979 COMPZ RPCOM PUTB P Continue to ruin 3-1/2", 9.3 lb/ft, L-80, EUE tubing 1,234'-7,979, installing Canon clamps at all tbg connections and testing I-wire every 25 jts. MU 3-1/2"EUE to 2,600 ft-lb with Run-N-Seal thread compound. 12:00 20:45 8.75 7,979 12,885 COMPZ RPCOM PUTB P Continue to ruin 3-1/2", 9.3 lb/ft, L-80, EUE tubing 7,979'-12,885', installing Canon clamps at all tbg connections and testing I-wire every 25 jts. MU 3-1/2"EUE to 2,600 ft-lb with Run-N-Seal thread compound. 20:45 21:45 1.00 12,885 12,885 COMPZ RPCOM PUTB P PJSM. PU/MU 3-1/2"Camco TRMAXX-5E SSSV w/2.813""X" profile. MU control line and test to 6,200 psi for 15 min-good. Note: visually inspected SSSV ID and verified it was clear of obstructions. 21:45 00:00 2.25 12,885 14,065 COMPZ RPCOM PUTB P Continue to run 3-1/2",9.3 lb/ft, L-80, EUE tubing 12,885'- 14,065', installing Canon clamps at all tbg connections and testing I-wire every 25jts. MU 3-1/2"EUE to 2,600 ft-lb with Run-N-Seal thread compound. 08/23/2014 Cap off I-wire and control line,test tbg to 2,500 psi for 30 min. Bleed tbg press to 2,000 psi. Test tbg x 7" csg annulus to 2,500 psi for 30 min, bleed tbg pressure to 0 psi-no shear. Stage annulus pressure to 2,900 psi and shear out. Set TWC and test to 2,500 psi. Flush stack and blow down all equip. RD MPD equip, ND BOPE. 00:00 01:30 1.50 14,065 14,882 COMPZ RPCOM PUTB P Continue to run 3-1/2",9.3 lb/ft, L-80, EUE tubing 14,065'-14,882', installing Canon clamps at all tbg connections and testing I-wire every 25 jts. MU 3-1/2"EUE to 2,600 ft-lb with Run-N-Seal thread compound. 01:30 03:00 1.50 14,882 15,002 COMPZ RPCOM PUTB P PJSM, C/O elevators, MU XO, remove bell guide, RU to circ down, RIH w/4-1/2"Tbg, locate seal entry at 1 bpm,40 psi,to 100 psi. Pump off and bleeder open,continue RIH to no go w/15K,tbg tail at 15002'. 165K up, 100K down Page 74 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 03:15 0.25 15,002 15,002 COMPZ RPCOM PRTS P Pressure test seals to 1000 psi for 10 min pumping down tubing,good test 03:15 03:45 0.50 15,002 14,924 COMPZ RPCOM HOSO P Un-sting and POOH to 14,924'and (above SBE). 03:45 04:15 0.50 14,924 14,924 COMPZ RPCOM HOSO P PU 7.82'space out pup and MU 04:15 04:45 0.50 14,924 14,924 COMPZ RPCOM THGR P MU Landing Jt B,Tbg Hngr and 1502 circ equipment. 04:45 05:45 1.00 14,924 14,924 COMPZ RPCOM THGR P Terminate I-wire and SSSV control line and connect to tbg hngr. Pressure test to 5,000 psi and visually inspect for leaks-good. 05:45 07:45 2.00 14,924 14,924 COMPZ RPCOM CRIH P PJSM. Pump 254 bbl of seawater with corrosion inhibitor,followed by 130 bbl of slick seawater at 4 BPM and 550 psi. 07:45 08:00 0.25 14,924 0 COMPZ RPCOM THGR P Drain stack and land 3-1/2"tbg on hanger, at 14,999'md. (PU- 165K, S0= 100K). Note: Spaced out from 3.63'from fully located 08:00 09:15 1.25 0 0 COMPZ RPCOM RURD P PJSM. RU Squeeze manifold, 1502 swings/hoses/valves and hard line to annulus. RILDS. 09:15 11:30 2.25 0 0 COMPZ RPCOM PRTS P PJSM. Pressure test Sqz manifold and lines to 3,000 psi-good. Test 3-1/2"tubing to 2,500 psi and hold for 30 min-good. Bleed off tubing pressure to 2,000 psi. 11:30 12:00 0.50 0 0 COMPZ RPCOM PRTS P Pressure test 3-1/2"tubing x 7"csg annulus to 2,500 psi and hold for 30 min-good. 12:00 12:45 0.75 0 0 COMPZ RPCOM FRZP P PJSM. RU to shear Shear DCK-2 SOV. Pressure up on annulus to 2,500 psi. Bleed tbg press from 2,000 psi to 0 psi-no shear. Pressure up annulus from 2,500 psi to 2,900 psi in 100 psi steps and shear out SOV. 12:45 13:45 1.00 0 0 COMPZ RPCOM MPSP P PJSM. RD Landing Jt. Install TWC with dry rod. Re-install Landing Jt. Pressure test in direction of flow, from below and hold for 15 min- good. 13:45 14:15 0.50 0 0 COMPZ RPCOM RURD P PJSM. Blow down lines, RD test joint and hard line. 14:15 15:15 1.00 0 0 COMPZ RPCOM RURD P PJSM. RD I-wire/control line spooling equip and sheaves. Clear and clean rig floor. 15:15 18:00 2.75 0 0 COMPZ WHDBO WWWH P PJSM. RU stack washer and flush stack, RD. Blow down all lines. Use vac to remove remaining water in stack. Page 75 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 22:00 4.00 0 0 COMPZ WHDBO NUND P PJSM. Monitor well for 30 min- static. ND Flow riser. RD MPD valves. ND RHC and Bearing package. Remove from rig cellar. 22:00 00:00 2.00 0 0 COMPZ WHDBO NUND P PJSM. RU and ND BOP stack. 08/24/2014 Pull TWC,freeze protect well, set BPV and test, secure well, LD 3-1/2" DP. 00:00 02:15 2.25 0 0 COMPZ WHDBO NUND P PJSM. Continue to ND BOP stack. SIMOPS-Clean pits,work on choke manifold, repair leaks in the roof of the Pit module. 02:15 03:15 1.00 0 0 COMPZ WHDBO NUND P Lift and set/secure BOP stack on stump. Wrap and secure I-wire and control line, clean and inspect flange for setting the tree. Continue to clean Pits and make repair welds on Pit roof. 03:15 05:45 2.50 0 0 COMPZ WHDBO NUND P PJSM. NU tree.Test adapter flange to 5,000 psi-good. Connect the I-wire and SSSV control line and test to 6,100 psi for 15 min-good. Test I-wire signal and continuity-good Continue work in pits. 05:45 07:15 1.50 0 0 COMPZ WHDBO PRTS P PJSM. RU and test tree to 250/5,000 psi for 10 minutes and record on chart-good. RD test equip. Clear tools and clean rig floor. 07:15 09:30 2.25 0 0 COMPZ WHDBO FRZP P RU and pull TWC. RU 1502 hard lines, swings, valves and squeeze manifold for U-tubing. 09:30 11:00 1.50 0 0 COMPZ WHDBO FRZP P PJSM. Test lines to 2,500 psi-good. Pump 78 bbl of diesel freeze protect at 2.2 BPM,400-750 psi. 11:00 12:00 1.00 0 0 COMPZ WHDBO FRZP P Allow diesel to U-tube in well. Clear rig floor and work on Choke manifold while U-tubing. 12:00 12:45 0.75 0 0 COMPZ WHDBO RURD P PJSM. Vac out lines from cement unit to rig floor and cellar. 12:45 14:30 1.75 0 0 COMPZ WHDBO MPSP P PJSM. RD hardline to tubing, RU lubricator, pressure test lubricator and test for leaks-good. Install BPV and RD lubricator. 14:30 15:00 0.50 0 0 COMPZ WHDBO PRTS P PJSM. RU and pressure test the BPV to 2,500 psi for 10 min-good. 15:00 16:30 1.50 0 0 DEMOB MOVE RURD P PJSM. Blow down lines, mud line and Sqz manifold. RD circulating equip. Install Mouse hole. Secure well. 16:30 00:00 7.50 0 0 DEMOB MOVE PULD P PJSM. LD 180 jts of 3-1/2" DP from the derick,via the Mouse hole. Note: Initial Tbg Press=250 psi, IA =0, OA=0 08/25/2014 Finish LD 3-1/2"DP, finish RD, move off of CD4-96A well Note: Rig Released @ 1800 hrs Page 76 of 77 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 04:45 4.75 0 0 DEMOB MOVE PULD P PJSM. Continue to LD 123 of 402 jts of 3-1/2"DP from the derick, via the Mouse hole. Continue to clean pits, work on Pit roof/Mud lab. Clean and prep Ball mill to move. 04:45 05:15 0.50 0 0 DEMOB MOVE SVRG P Lubricate rig. 05:15 08:30 3.25 0 0 DEMOB MOVE PULD P LD final 99 of 402 jts of 3-1/2"DP from the derick, via the Mouse hole. Continue to clean the pits,work on Pit roof/Mud lab. Clean and prep Ball mill to move. 08:30 12:00 3.50 0 0 DEMOB MOVE RURD P PJSM. RU drain lines and clean rig floor, rotary table,drip pan. Continue to work on Pit roof and Choke manifold, 12:00 18:00 6.00 0 0 DEMOB MOVE RURD P PJSM. Clean drip pans under rig floor. Clean mud pits and Top Drive. Remove old Choke manifold, PU new Choke manifold to rig floor. NOTE: Rig released at 1800 hrs- 8/25/2014 Page 77 of 77 CD4-96 WELL WORK SUMMARY POST RIG WELL WORK 8/26/2014 PULLED 1" SOV© 5303' RKB, REPLACED w/ 1" DGLV. SHEARED P SLEEVE @ 19237' RKB, READY FOR E-LINE 8/26/2014 PT TBG TO 2500 PSI (PASS) PT IA TO 2500 PSI (PASS) PRESSURE UP ON P-SLEVE TO OPEN P-SLEVE OPENED AT 4700 PSI TURN WELL OVER TO SLICK LINE JOB IN PROGRESS 8/27/2014 RIH WITH WELLTEC TRACTOR AND STROKER. OPENED SLIDING SLEEVE AT 15897'. OBSERVED A CHANGE FROM 1200 PSI TO 1050 PSI ON THE TUBING AFTER THE SLEEVE WAS OPENED 8/28/2014 SET SLIP STOP CATCHER © 14,030' SLM; PULLED DV'S © 13,838' , 10,325' , & 5303' RKB; SET GLV @ 5303' RKB. IN PROGRESS. 8/29/2014 SET GLV© 10,325' RKB; SET 1/4" OV @ 13,838' RKB; PULLED SLIP STOP CATCH © 14,030' SLM. COMPLETE. 9/10/2014 PUMPED 150 BBLS OF 180* CRUDE DOWN IA TO THAW WELL. PUMPED 4 BBLS OF NEAT FOLLOWED BY 7 BBLS OF CRUDE DOWN TBG BEFORE LOCKING UP AT 2500 PSI. JOB TO CONTINUE 9/11/2014 PUMPED 580 BBLS OF 180* CRUDE DOWN IA FOR WELL THAW. 22 BBLS CRUDE DOWN TBG BEFORE LOCKING UP AT 2800 PSI JOB INCOMPLETE. 9/12/2014 PUMPED 500 BBLS OF 180* CRUDE DOWN IA AND 2 BBLS CRUDE DOWN TBG BEFORE LOCKING UP AT 2800 PSI. JOB COMPLETE 9/13/2014 PUMPED 500 BBLS OF 180* CRUDE DOWN IA AND 10 BBLS CRUDE DOWN TBG BEFORE LOCKING UP AT 4000 PSI. JOB COMPLETE 9/15/2014 PUMPED 750 BBLS OF 180* CRUDE DOWN IA. 0.5 BBLS CRUDE DOWN TBG BEFORE LOCKING UP TO 4000 PSI. JOB COMPLETE 9/20/2014 PUMP 560 BBL CRUDE AT 190* DOWN IA PUMP 300 BBL 70/30 AT 200* DOWN IA TBG IS STILL PLUGGED JOB IN PROGRESS Cement Detail Report CD4-96 C_onocoPhilrps • String: Surface Casing Cement Job: DRILLING ORIGINAL, 10/20/2013 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 10/27/2013 18:51 10/27/2013 22:46 CD4-96A Comment Cemented 13-3/8"casing as follows:Pumped 120 bbls of 10.0 ppg mud w/Nut Plug followed by a 10.0ppg 38 bbls/Biozan Spacer-Shut down-Line up to Dowell-Pumped 2 bbls fresh water-Tested lines to 3,000 psi-Line cmt head up to drop btm plug-Mixed&pumped 50 bbls-10.5 ppg MudPush @ 5 bbls/min @ 85 psi-Mixed&pumped 600 bbls lead slurry#1(Arctic Set Lite)@ 10.7 ppg-7.3-8.0 bbls/min @ 227-300 psi. (Mixed and pumped 1,375 sxs.2.45 yield) Mixed&pumped 69.5 bbls tail slurry(Class G w/additives)@ 15.8 ppg @ 5 bbls/min @ 300 psi(334 sxs, 1.17 yield)-Dropped top plug w/20 bbls fresh water f/ Dowell-Switched to rig pumps-displaced cement w/10.0 ppg mud @ 8 bbls/min @ 360 psi-slowed pumps to 3.5 bbls/min @ 680 psi for last 10 bbls of displacement-Bumped plug w/407.8 total bbls of 10.0 ppg mud and pressured up additional 520 psi @ 1,200 psi and held for 5 minutes-okay-Bleed off pressure to check floats OK-Full returns throughout the job.220 bbls cement returns to surface. Pipe was not reciprocated during job due pipe/hanger catching in riser.-CIP@ 22:46 hrs with 4,086 strokes. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement..Top Plug? Btm Plug? Surface Casing Cement Cement to surface. 36.6 2,939.0 Yes 220.0 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) 7 3 8 700.0 1,200.0 No 0.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,840.0 Drill Bit 2,951.0 12 1/4 Comment Full returns.220 bbls cement to surface Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement _ 36.6 2,430.0 1,375 AS1 600.0 Yield(ft/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 2.45 11.51, 10.70 0.0 6.00 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 2,430.0 2,939.0 336 G 59.6 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.17 5.13 15.80 0.0 5.10 'Additives Additive Type Concentration Conc Unit label S002 Accelerator 0.8 %BWOC Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label D065 Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label D185 Dispersant 0.05 gal/sx Page 1/1 Report Printed: 9/22/2014 '�0; Cement Detail Report 11 CD4-96 ConocoPhillips String: Intermediate#1 9.625"cement job. Job: DRILLING ORIGINAL, 10/20/2013 12:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate#1 9.625"cement job. 11/16/2013 19:38 11/17/2013 00:55 CD4-96A Comment Cement 9.625"liner. Dowell pumped 2 bbls CW100. Pressure test lines to 4200 psi. Pump 38 bbls CW100.(40.1 bbls total.)Pump 50 bbls 11.5 ppg mud push @ 6.4 bpm,405 psi. Pump 504 bbls 12.2 ppg lead cement,6.6 bpm,ICP=350 psi, FCP=65 psi. Full returns through out job. Pump 45.5 bbls Qannik tail 15.8 ppg @ 6 bpm, ICP=235 psi, FCP=70 psi. Drop dart, Dowell kicked it out with 10 bbls water, Rig pumped 888 bbls to bump plug.Displace with 10.2 ppg mud. Initial flow rate 7 bpm, max pressure 570 psi,final flow rate 2 bpm,470 psi. Pressure up to 1000 psi for 5 mins. Floats held. CIP @ 00:55 hrs. 11/17/13.Pipe was reciprocated until lead cement came around the shoe. Up weight increased to 500k. Casing was parked after that.4201bs Cern-NET fiber was pumped to aid in retarding any losses. 1230 sxs lead pumped(2.30 yield),220 sxs tail pumped(1.16 yield). Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate#1 9.625" 6,307.0 13,260.0 Yes 0.0 Yes No Lead Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 2 7 65.0 470.0 Yes 30.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment .Cement 9.625"liner. Dowell pumped 2 bbls CW100. Pressure test lines to 4200 psi. Pump 38 bbls CW100. (40.1 bbls total.)Pump 50 bbls 11.5 ppg mud push @ 6.4 bpm,405 psi. Pump 504 bbls 12.2 ppg lead cement,6.6 bpm, ICP=350 psi, FCP=65 psi. Full returns through out job. Pump 45.5 bbls Qannik tail 15.8 ppg @ 6 bpm, ICP=235 psi, FCP=70 psi. Drop dart, Dowell kicked it out with 10 bbls water, Rig pumped 888 bbls to bump plug.Displace with 10.2 ppg mud. Initial flow rate 7 bpm, max pressure 570 psi,final flow rate 2 bpm,470 psi. Pressure up to 1000 psi for 5 mins. Floats held. CIP @ 00:55 hrs. 11/17/13.Pipe was reciprocated until lead cement came around the shoe. Up weight increased to 500k.Casing was parked after that.4201bs Cern-NET fiber was pumped to aid in retarding any losses. 1230 sxs lead pumped(2.30 yield),220 sxs tail pumped(1.16 yield). Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 6,307.0 12,760.0 1,230 AS1 504.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 2.30 13.58 12.20 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 12,760.0 13,260.0 220 Qannik Blend 45.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/22/2014 NADConversion Western North Slope CD4 Nanuq Pad CD4-96A Definitive Survey Report N ,46,, D 2 7 08 September, 2014 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-96 Well Position +N/-S 0.00 usft Northing: 5,957,544.09 usft Latitude: 70°17'33.155 N +E/-W 0.00 usft Easting: 378,252.95 usft Longitude: 150°59'8.492 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 18.90 usft Wellbore CD4-96A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 7/22/2014 18.76 80.77 57,557 Design CD4-96A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 15,132.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 0.00 0.00 0.00 206.81 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.32 1,046.10 CD4-96 Gyro(CD4-96) GYD-GC-SS Gyrodata gyro single shots 11/13/2013 12:01 1,139.67 2,869.84 CD4-96 MWD I(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 2,965.61 3,020.73 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND Inclinometer+known azi trend 2/11/2014 12:00: 3,114.99 12,938.76 CD4-96 MWD II(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 12,950.00 13,400.00 CD4-96APB1 Svy1 SLB_NSG+MSHOT( GYD-GC-MS Gyrodata gyrocompassing m/s 6/16/2014 9:15: 13,465.21 15,132.00 CD4-96APB1 Svy2 SLB-MWD-GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2014 10:01 15,145.00 15,251.68 CD4-96A Svy1 MWD INC ONLY FILLER INC+TREND Inclinometer+known azi trend 8/8/2014 5:42:0 15,343.82 19,231.81 CD4-96A Svy2 MWD+GMAG(CD4-96A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 9/5/2014 3:57:0 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 36.80 0.00 0.00 36.80 -18.90 0.00 0.00 5,957,544.09 378,252.95 0.00 0.00 UNDEFINED 75.32 0.12 214.58 75.32 19.62 -0.03 -0.02 5,957,544.06 378,252.93 0.31 0.04 GYD-GC-SS(1) 104.55 0.19 179.56 104.55 48.85 -0.11 -0.04 5,957,543.98 378,252.91 0.39 0.11 GYD-GC-SS(1) 114.15 0.14 183.36 114.15 58.45 -0.13 -0.04 5,957,543.95 378,252.91 0.51 0.14 GYD-GC-SS(1) 20"x 42" 144.37 0.04 280.72 144.37 88.67 -0.17 -0.05 5,957,543.92 378,252.89 0.51 0.18 GYD-GC-SS(1) 241.06 0.41 229.08 241.06 185.36 -0.39 -0.35 5,957,543.70 378,252.60 0.40 0.51 GYD-GC-SS(1) 333.50 0.51 232.63 333.50 277.80 -0.86 -0.92 5,957,543.25 378,252.01 0.11 1.18 GYD-GC-SS(1) 9/8/2014 1:02:00PM Page 2 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 423.96 0.76 273.71 423.95 368.25 -1.06 -1.84 5,957,543.06 378,251.09 0.56 1.78 GYD-GC-SS(1) 520.36 1.79 306.49 520.33 464.63 -0.13 -3.69 5,957,544.02 378,249.26 1.27 1.78 GYD-GC-SS(1) 612.19 2.95 333.58 612.08 556.38 2.84 -5.90 5,957,547.03 378,247.10 1.72 0.12 GYD-GC-SS(1) 703.41 2.13 339.50 703.21 647.51 6.53 -7.53 5,957,550.74 378,245.52 0.94 -2.43 GYD-GC-SS(1) 797.65 2.47 331.34 797.37 741.67 9.96 -9.12 5,957,554.19 378,243.99 0.50 -4.77 GYD-GC-SS(1) 855.62 1.96 316.94 855.30 799.60 11.78 -10.40 5,957,556.03 378,242.75 1.30 -5.82 GYD-GC-SS(1) 950.35 1.65 246.75 949.99 894.29 12.42 -12.76 5,957,556.71 378,240.40 2.21 -5.33 GYD-GC-SS(1) 1,017,27 4.25 216.67 1,016.82 961.12 10.05 -15.12 5,957,554.38 378,237.99 4.39 -2.15 GYD-GC-SS(1) 1,046.10 5.62 215.32 1,045.54 989.84 8.04 -16.58 5,957,552.40 378,236.51 4.77 0.30 GYD-GC-SS(1) 1,139.67 9.20 213.97 1,138.32 1,082.62 -1.90 -23.41 5,957,542.57 378,229.52 3.83 12.26 MWD+IFR-AK-CAZ-SC(2) 1,233.36 14.14 215.28 1,230.04 1,174.34 -17.47 -34.21 5,957,527.18 378,218.46 5.28 31.02 MWD+IFR-AK-CAZ-SC(2) 1,326.99 19.56 216.77 1,319.62 1,263.92 -39.37 -50.21 5,957,505.54 378,202.11 5.81 57.79 MWD+IFR-AK-CAZ-SC(2) 1,377.22 22.22 214.85 1,366.54 1,310.84 -53.91 -60.67 5,957,491.18 378,191.42 5.47 75.48 MWD+IFR-AK-CAZ-SC(2) 1,422.26 24.40 213.70 1,407.91 1,352.21 -68.64 -70.70 5,957,476.61 378,181.15 4.94 93.15 MWD+IFR-AK-CAZ-SC(2) 1,472.21 26.21 211.32 1,453.06 1,397.36 -86.64 -82.16 5,957,458.79 378,169.40 4.16 114.39 MWD+IFR-AK-CAZ-SC(2) 1,516.77 27.68 209.02 1,492.79 1,437.09 -104.10 -92.30 5,957,441.50 378,158.99 4.04 134.54 MWD+IFR-AK-CAZ-SC(2) 1,567.27 30.11 205.13 1,537.00 1,481.30 -125.83 -103.37 5,957,419.96 378,147.56 6.08 158.93 MWD+IFR-AK-CAZ-SC(2) 1,611.16 33.09 204.16 1,574.38 1,518.68 -146.74 -112.95 5,957,399.21 378,137.65 6.89 181.91 MWD IFR-AK-CAZ-SC(2) 1,631.32 34.02 203.59 1,591.18 1,535.48 -156.93 -117.46 5,957,389.10 378,132.97 4.87 193.04 MWD+IFR-AK-CAZ-SC(2) 1,705.49 37.52 205.83 1,651.35 1,595.65 -196.28 -135.61 5,957,350.04 378,114.19 5.04 236.35 MWD+IFR-AK-CAZ-SC(2) 1,749.43 39.66 204.96 1,685.69 1,629.99 -221.04 -147.36 5,957,325.48 378,102.04 5.02 263.75 MWD+IFR-AK-CAZ-SC(2) 1,799.40 41.07 205.18 1,723.77 1,668.07 -250.36 -161.07 5,957,296.40 378,087.86 2.84 296.09 MWD+IFR-AK-CAZ-SC(2) 1,893.90 45.79 206.76 1,792.38 1,736.68 -308.72 -189.55 5,957,238.50 378,058.44 5.12 361.03 MWD+IFR-AK-CAZ-SC(2) 1,988.14 46.53 206.88 1,857.65 1,801.95 -369.38 -220.22 5,957,178.35 378,026.80 0.79 429.00 MWD+IFR-AK-CAZ-SC(2) 2,082.27 46.35 206.41 1,922.52 1,866.82 -430.35 -250.81 5,957,117.89 377,995.23 0.41 497.22 MWD+IFR-AK-CAZ-SC(2) 2,177.28 48.36 207.09 1,986.88 1,931.18 -492.75 -282.27 5,957,056.01 377,962.77 2.18 567.10 MWD+IFR-AK-CAZ-SC(2) 2,273.16 53.76 207.18 2,047.12 1,991.42 -559.09 -316.27 5,956,990.24 377,927.70 5.63 641.64 MWD+IFR-AK-CAZ-SC(2) 2,322.18 56.04 208.88 2,075.30 2,019.60 -594.49 -335.12 5,956,955.16 377,908.27 5.45 681.74 MWD+IFR-AK-CAZ-SC(2) 2,365.77 57.89 209.54 2,099.07 2,043.37 -626.38 -352.95 5,956,923.56 377,889.93 4.43 718.24 MWD+IFR-AK-CAZ-SC(2) 2,460.71 60.25 210.00 2,147.86 2,092.16 -697.06 -393.39 5,956,853.54 377,848.35 2.52 799.57 MWD+IFR-AK-CAZ-SC(2) 2,554.60 60.50 211.91 2,194.28 2,138.58 -767.05 -435.37 5,956,784.25 377,805.25 1.79 880.97 MVVD+IFR-AK-CAZ-SC(2) 2,649.85 61.88 215.06 2,240.19 2,184.49 -836.64 -481.42 5,956,715.43 377,758.08 3.24 963.84 MWD+IFR-AK-CAZ-SC(2) 2,742.86 63.23 219.26 2,283.07 2,227.37 -902.38 -531.28 5,956,650.50 377,707.17 4.26 1,045.01 MWD+IFR-AK-CAZ-SC(2) 2,837.37 63.96 224.05 2,325.12 2,269.42 -965.60 -587.52 5,956,588.21 377,649.91 4.60 1,126.80 MWD+IFR-AK-CAZ-SC(2) 2,869.84 64.39 225.42 2,339.26 2,283.56 -986.36 -608.09 5,956,567.79 377,629.01 4.02 1,154.61 MWD+IFR-AK-CAZ-SC(2) 2,939.12 64.76 229.43 2,369.02 2,313.32 -1,028.68 -654.16 5,956,526.22 377,582.27 5.25 1,213.16 INC+TREND(3) 13-3/8"x 16" i 2,965.61 64.93 230.95 2,380.28 2,324.58 -1,044.03 -672.58 5,956,511.17 377,563.61 5.25 1,235.16 INC+TREND(3) 3,020.73 65.46 228.71 2,403.40 2,347.70 -1,076.30 -710.80 5,956,479.53 377,524.87 3.81 1,281.21 INC+TREND(3) 3,114.99 66.20 228.12 2,442.00 2,386.30 -1,133.38 -775.13 5,956,423.50 377,459.64 0.97 1,361.17 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:02:00PM Page 3 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,209.60 66.52 229.05 2,479.94 2,424.24 -1,190.71 -840.12 5,956,367.23 377,393.72 0.96 1,441.65 MVVD+IFR-AK-CAZ-SC(4) 3,303.50 66.16 228.43 2,517.62 2,461.92 -1,247.43 -904.78 5,956,311.58 377,328.17 0.72 1,521.44 MWD+IFR-AK-CAZ-SC(4) 3,397.99 64.30 228.94 2,557.21 2,501.51 -1,304.08 -969.21 5,956,255.99 377,262.83 2.03 1,601.06 MWD+IFR-AK-CAZ-SC(4) 3,491.63 64.66 228.61 2,597.55 2,541.85 -1,359.76 -1,032.77 5,956,201.34 377,198.38 0.50 1,679.43 MWD+IFR-AK-CAZ-SC(4) 3,586.27 64.39 228.48 2,638.26 2,582.56 -1,416.33 -1,096.80 5,956,145.83 377,133.44 0.31 1,758.79 MWD+IFR-AK-CAZ-SC(4) 3,680.38 64.59 228.30 2,678.79 2,623.09 -1,472.73 -1,160.31 5,956,090.47 377,069.04 0.27 1,837.78 MWD+IFR-AK-CAZ-SC(4) 3,774.89 64.50 228.51 2,719.41 2,663.71 -1,529.38 -1,224.13 5,956,034.86 377,004.32 0.22 1,917.12 MWD+IFR-AK-CAZ-SC(4) 3,869.26 64.53 227.91 2,760.01 2,704.31 -1,586.15 -1,287.64 5,955,979.13 376,939.90 0.57 1,996.44 MWD+IFR-AK-CAZ-SC(4) 3,963.72 64.41 227.14 2,800.72 2,745.02 -1,643.71 -1,350.51 5,955,922.61 376,876.11 0.75 2,076.17 MWD+IFR-AK-CAZ-SC(4) 4,061.51 64.30 226.49 2,843.05 2,787.35 -1,704.04 -1,414.79 5,955,863.33 376,810.87 0.61 2,159.01 MWD+IFR-AK-CAZ-SC(4) 4,159.70 64.61 226.66 2,885.39 2,829.69 -1,764.93 -1,479.13 5,955,803.49 376,745.55 0.35 2,242.38 MWD+IFR-AK-CAZ-SC(4) 4,254.11 64.15 226.96 2,926.21 2,870.51 -1,823.20 -1,541.20 5,955,746.24 376,682.56 0.57 2,322.37 MWD+IFR-AK-CAZ-SC(4) 4,347.74 63.04 226.53 2,967.85 2,912.15 -1,880.66 -1,602.27 5,955,689.78 376,620.56 1.25 2,401.21 MWD+IFR-AK-CAZ-SC(4) 4,442.50 61.89 225.90 3,011.66 2,955.96 -1,938.80 -1,662.94 5,955,632.63' 376,558.97 1.35 2,480.46 MWD+IFR-AK-CAZSC(4) 4,536.09 60.62 225.68 3,056.66 3,000.96 -1,996.02 -1,721.75 5,955,576.38 376,499.24 1.37 2,558.06 MWD+IFR-AK-CAZ-SC(4) 4,632.01 59.12 225.96 3,104.81 3,049.11 -2,053.83 -1,781.24 5,955,519.54 376,438.83 1.58 2,636.49 MWD+IFR-AK-CAZ-SC(4) 4,727.18 59.45 225.96 3,153.42 3,097.72 -2,110.71 -1,840.06 5,955,463.63 376,379.10 0.35 2,713.78 MWD+IFR-AK-CAZ-SC(4) 4,821.01 59.37 225.92 3,201.17 3,145.47 -2,166.88 -1,898.10 5,955,408.41 376,320.16 0.09 2,790.10 MWD+IFR-AK-CAZ-SC(4) 4,915.29 59.38 227.17 3,249.20 3,193.50 -2,222.68 -1,957.00 5,955,353.58 376,260.38 1.14 2,866.46 MVVD+IFR-AK-CAZ-SC(4) 5,010.08 60.25 227.14 3,296.86 3,241.16 -2,278.40 -2,017.07 5,955,298.85 376,199.41 0.92 2,943.29 MWD+IFR-AK-CAZ-SC(4) 5,109.39 61.83 227.50 3,344.94 3,289.24 -2,337.30 -2,080.95 5,955,240.99 376,134.60 1.62 3,024.67 MVVD+IFR-AK-CAZ-SC(4) 5,203.58 64.83 227.59 3,387.21 3,331.51 -2,394.10 -2,143.04 5,955,185.20 376,071.60 3.19 3,103.38 MWD+IFR-AK-CAZ-SC(4) 5,299.56 64.66 226.40 3,428.17 3,372.47 -2,453.31 -2,206.52 5,955,127.04 376,007.17 1.14 3,184.85 MWD+IFR-AK-CAZ-SC(4) 5,392.87 63.31 226.51 3,469.09 3,413.39 -2,511.08 -2,267.30 5,955,070.27 375,945.47 1.45 3,263.83 MWD+IFR-AK-CAZ-SC(4) 5,486.09 63.57 226.24 3,510.77 3,455.07 -2,568.61 -2,327.66 5,955,013.73 375,884.19 0.38 3,342.40 MWD+IFR-AK-CAZ-SC(4) 5,580.38 63.54 225.13 3,552.76 3,497.06 -2,627.58 -2,388.06 5,954,955.74 375,822.84 1.05 3,422.28 MWD+IFR-AK-CAZ-SC(4) 5,674.61 62,82 226.05 3,595.28 3,539.58 -2,686.43 -2,448.13 5,954,897.88 375,761.84 1.16 3,501.90 MWD+IFR-AK-CAZ-SC(4) 5,769.13 62.64 226.64 3,638.59 3,582.89 -2,744.43 -2,508.92 5,954,840.88 375,700.12 0.59 3,581.08 MVVD+IFR-AK-CAZ-SC(4) 5,863.51 62.69 226.90 3,681.93 3,626.23 -2,801.85 -2,570.01 5,954,784.46 375,638.12 0.25 3,659.88 MWD+IFR-AK-CAZ-SC(4) 5,958.90 62.77 226.20 3,725.63 3,669.93 -2,860.16 -2,631.56 5,954,727.15 375,575.64 0.66 3,739.69 MWD+IFR-AK-CAZSC(4) 6,053.79 62.47 226.20 3,769.27 3,713.57 -2,918.48 -2,692.38 5,954,669.83 375,513.89 0.32 3,819.17 MWD+IFR-AK-CAZ-SC(4) 6,146.64 62.60 227.14 3,812.10 3,756.40 -2,975.01 -2,752.30 5,954,614.28 375,453.06 0.91 3,896.66 MWD+IFR-AK-CAZ-SC(4) 6,240.58 62.50 227.55 3,855.40 3,799.70 -3,031.50 -2,813.61 5,954,558.80 375,390.85 0.40 3,974.72 MWD+IFR-AK-CAZ-SC(4) 6,336.26 62.65 228.39 3,899.47 3,843.77 -3,088.36 -2,876.69 5,954,502.98 375,326.86 0.79 4,053.92 MWD+IFR-AK-CAZ-SC(4) 6,430.58 62.80 227.96 3,942.69 3,886.99 -3,144.26 -2,939.17 5,954,448.10 375,263.49 0.44 4,132.00 MWD+IFR-AK-CAZ-SC(4) 6,523.57 62.58 228.74 3,985.36 3,929.66 -3,199.18 -3,000.90 5,954,394.20 375,200.88 0.78 4,208.85 MWD+IFR-AK-CAZ-SC(4) 6,617.74 62.04 229.16 4,029.12 3,973.42 -3,253.94 -3,063.79 5,954,340.47 375,137.12 0.70 4,286.09 MWD+IFR-AK-CAZ-SC(4) 6,712.46 63.21 228.93 4,072.67 4,016.97 -3,309.07 -3,127.31 5,954,286.37 375,072.72 1.25 4,363.95 MWD+IFR-AK-CAZ-SC(4) 6,807.18 64.99 230.03 4,114.04 4,058.34 -3,364.42 -3,192.08 5,954,232.08 375,007.07 2.15 4,442.57 MW1J+IFR-AK-CAZ-SC(4) 6,901.57 66.76 229.83 4,152.62 4,096.92 -3,419.87 -3,258.00 5,954,177.71 374,940.26 1.89 4,521.79 M1ND+IFR-AK-CAZ-SC(4) 9/8/2014 1:02:00PM Page 4 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 6,995.55 66.41 230.49 4,189.97 4,134.27 -3,475.12 -3,324.22 5,954,123.54 374,873.17 0.74 4,600.97 MWD+IFR-AK-CAZ-SC(4) 7,090.90 64.90 230.38 4,229.27 4,173.57 -3,530.45 -3,391.19 5,954,069.31 374,805.32 1.59 4,680.56 MWD+IFR-AK-CAZ-SC(4) 7,185.57 66.20 230.38 4,268.46 4,212.76 -3,585.41 -3,457.57 5,954,015.44 374,738.06 1.37 4,759.55 MWD+IFR-AK-CAZ-SC(4) 7,279.26 66.23 230.13 4,306.24 4,250.54 -3,640.22 -3,523.49 5,953,961.71 374,671.27 0.25 4,838.21 MWD+IFR-AK-CAZ-SC(4) 7,372.88 66.19 230.38 4,344.01 4,288.31 -3,695.00 -3,589.36 5,953,908.01 374,604.53 0.25 4,916.80 MWD+IFR-AK-CAZ-SC(4) 7,468.22 66.20 229.97 4,382.49 4,326.79 -3,750.86 -3,656.35 5,953,853.24 374,536.64 0.39 4,996.88 MWD+IFR-AK-CAZ-SC(4) 7,561.95 66.09 229.06 4,420.40 4,364.70 -3,806.52 -3,721.55 5,953,798.66 374,470.56 0.90 5,075.96 MWD+IFR-AK-CAZ-SC(4) 7,656.89 66.15 227.79 4,458.83 4,403.13 -3,864.12 -3,786.49 5,953,742.11 374,404.70 1.22 5,156.67 MWD+IFR-AK-CAZ-SC(4) 7,749.14 65.59 227.45 4,496.54 4,440.84 -3,920.87 -3,848.68 5,953,686.39 374,341.60 0.69 5,235.37 MWD+IFR-AK-CAZ-SC(4) 7,844.14 64.30 227.03 4,536.78 4,481.08 -3,979.30 -3,911.86 5,953,629.00 374,277.48 1.42 5,316.01 MWD+IFR-AK-CAZ-SC(4) 7,938.86 64.08 227.23 4,578.02 4,522.32 -4,037.31 -3,974.36 5,953,572.01 374,214.06 0.30 5,395.98 MWD+IFR-AK-CAZ-SC(4) 8,032.81 64.14 226.83 4,619.04 4,563.34 -4,094.92 -4,036.20 5,953,515.41 374,151.30 0.39 5,475.29 MWD+IFR-AK-CAZ-SC(4) 8,125.50 64.11 227.04 4,659.49 4,603.79 -4,151.87 -4,097.13 5,953,459.46 374,089.46 0.21 5,553.60 MWD+IFR-AK-CAZ-SC(4) 8,222.02 63.80 227.20 4,701.87 4,646.17 -4,210.87 -4,160.68 5,953,401.50 374,024.97 0.35 5,634.93 MWD+IFR-AK-CAZ-SC(4) 8,313.92 63.12 227.26 4,742.93 4,687.23 -4,266.70 -4,221.03 5,953,346.66 373,963.73 0.74 5,711.98 MWD+IFR-AK-CAZ-SC(4) 8,411.28 62.18 227.06 4,787.66 4,731.96 -4,325.50 -4,284.44 5,953,288.90 373,899.38 0.98 5,793.06 MWD+IFR-AK-CAZ-SC(4) 8,503.41 62.08 227.39 4,830.73 4,775.03 -4,380.81 -4,344.22 5,953,234.57 373,838.72 0.33 5,869.39 MWD+IFR-AK-CAZ-SC(4) 8,600.42 62.67 227.20 4,875.71 4,820.01 -4,439.11 -4,407.38 5,953,177.31 373,774.62 0.63 5,949,90 MWD+IFR-AK-CAZ-SC(4) 8,691.17 64.04 227.41 4,916.41 4,860.71 -4,494.11 -4,467.00 5,953,123.29 373,714.13 1.52 6,025.88 MWD+IFR-AK-CAZ-SC(4) 8,790.02 63.59 227.25 4,960.03 4,904.33 -4,554.23 -4,532.22 5,953,064.23 373,647.95 0.48 6,108.96 MWD+IFR-AK-CAZ-SC(4) 8,882.67 62.03 227.12 5,002.36 4,946.66 -4,610.24 -4,592.67 5,953,009.22 373,586.60 1.69 6,186.21 MWD+IFR-AK-CAZ-SC(4) 8,976.21 62.04 227.42 5,046.22 4,990.52 -4,666.30 -4,653.36 5,952,954.15 373,525.02 0.28 6,263.62 MWD+IFR-AK-CAZ-SC(4) 9,071.00 61.95 227.15 5,090.73 5,035.03 -4,723.07 -4,714.85 5,952,898.39 373,462.63 0.27 6,342.02 MWD+IFR-AK-CAZ-SC(4) 9,165.30 62.79 227.13 5,134.47 5,078.77 -4,779.90 -4,776.09 5,952,842.56 373,400.48 0.89 6,420.37 MWD+IFR-AK-CAZ-SC(4) 9,258.78 62.00 227.07 5,177.78 5,122.08 -4,836.28 -4,836.77 5,952,787.17 373,338.90 0.85 6,498.07 MWD+IFR-AK-CAZ-SC(4) 9,353.22 62.03 227.12 5,222.10 5,166.40 -4,893.06 -4,897.86 5,952,731.39 373,276.90 0.06 6,576.29 MWD+IFR-AK-CAZ-SC(4) 9,447.52 62.02 227.58 5,266.33 5,210.63 -4,949.48 -4,959.11 5,952,675.97 373,214.75 0.43 6,654.28 MWD+IFR-AK-CAZ-SC(4) 9,541.95 62.38 227.04 5,310.37 5,254.67 -5,006.12 -5,020.51 5,952,620.34 373,152.45 0.63 6,732.52 MWD+IFR-AK-CAZ-SC(4) 9,636.02 62.29 227.14 5,354.05 5,298.35 -5,062.85 -5,081.53 5,952,564.62 373,090.52 0.13 6,810.68 MWD+IFR-AK-CAZ-SC(4) ', W 9,730.64 62.31 227.38 5,398.03 5,342.33 -5,119.70 -5,143.06 5,952,508.77 373,028.08 0.23 6,889.17 MD+IFR-AK-CAZ-SC(4) 9,825.32 62.82 227.30 5,441.66 5,385.96 -5,176.65 -5,204.86 5,952,452.84 372,965.38 0.54 6,967.87 MWD+IFR-AK-CAZ-SC(4) 9,919.47 63.85 227.56 5,483.91 5,428.21 -5,233.56 -5,266.82 5,952,396.94 372,902.51 1.12 7,046.62 MWD+IFR-AK-CAZ-SC(4) 10,013.65 63.81 227.33 5,525.44 5,469.74 -5,290.73 -5,329.08 5,952,340.80 372,839.33 0.22 7,125.72 MWD+IFR-AK-CAZ-SC(4) 10,109.47 63.92 226.77 5,567.65 5,511.95 -5,349.34 -5,392.05 5,952,283.22 372,775.43 0.54 7,206.43 MWD+IFR-AK-CAZ-SC(4) 10,202.84 63.88 226.62 5,608.73 5,553.03 -5,406.85 -5,453.06 5,952,226.71 372,713.49 0.15 7,285.28 MWD+IFR-AK-CAZ-SC(4) 10,298.09 63.81 227.01 5,650.72 5,595.02 -5,465.36 -5,515.40 5,952,169.22 372,650.22 0.37 7,365.62 MWD+IFR-AK-CAZ-SC(4) 10,390.13 63.74 227.21 5,691.39 5,635.69 -5,521.55 -5,575.90 5,952,114.02 372,588.83 0.21 7,443.06 MWD+IFR-AK-CAZ-SC(4) 10,483.60 63.96 227.44 5,732.58 5,676.88 -5,578.43 -5,637.58 5,952,058.15 372,526.24 0.32 7,521.64 M1ND+IFR-AK-CAZ-SC(4) 10,579.65 63.75 228.62 5,774.91 5,719.21 -5,636.09 -5,701.69 5,952,001.55 372,461.21 1.12 7,602.02 M1ND+IFR-AK-CAZ-SC(4) 10,675.73 62.80 229.21 5,818.11 5,762.41 -5,692.48 -5,766.37 5,951,946.21 372,395.63 1.13 7,681.53 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:O2:O0PM Page 5 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical ' MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 10,768.32 63.34 230.34 5,860.05 5,804.35 -5,745.79 -5,829.39 5,951,893.93 372,331.76 1.23 7,757.54 MWD+IFR-AK-CAZ-SC(4) 10,862.66 63,66 231.38 5,902.15 5,846.45 -5,799.08 -5,894.88 5,951,841.71 372,265.43 1.04 7,834.63 MWD+IFR-AK-CAZ-SC(4) 10,957.11 64.49 231.37 5,943.44 5,887.74 -5,852.10 -5,961.24 5,951,789.78 372,198.22 0.88 7,911.89 MWD+IFR-AK-CAZ-SC(4) 11,051.39 66.41 231.89 5,982.61 5,926.91 -5,905.33 -6,028.47 5,951,737.65 372,130.14 2.10 7,989.72 MWD+IFR-AK-CAZ-SC(4) 11,145.65 67.42 232.61 6,019.57 5,963.87 -5,958.42 -6,097.03 5,951,685.69 372,060.73 1.28 8,068.03 MWD+IFR-AK-CAZ-SC(4) 11,240.19 66.98 231.89 6,056.20 6,000.50 -6,011.77 -6,165.94 5,951,633.46 371,990.97 0.84 8,146.73 MWD+IFR-AK-CAZ-SC(4) 11,334.03 66.53 231.07 6,093.24 6,037.54 -6,065.47 -6,233.40 5,951,580.87 371,922.66 0.94 8,225.08 MWD+IFR-AK-CAZ-SC(4) 11,428.50 66.27 229.72 6,131.06 6,075.36 -6,120.65 -6,300.10 5,951,526.77 371,855.08 1.34 8,304.42 MWD+IFR-AK-CAZ-SC(4) 11,522.09 67.92 229.41 6,167.49 6,111.79 -6,176.57 -6,365.72 5,951,471.93 371,788.57 1.79 8,383.92 MWD+IFR-AK-CAZ-SC(4) 11,618.23 68.21 228.84 6,203.40 6,147.70 -6,234.93 -6,433.15 5,951,414.68 371,720.21 0.63 8,466.42 MWD+IFR-AK-CAZ-SC(4) 11,709.22 66.54 228.38 6,238.40 6,182.70 -6,290.45 -6,496.16 5,951,360.18 371,656.32 1.89 8,544.40 MWD+IFR-AK-CAZ-SC(4) 11,806.82 64.65 227.67 6,278.73 6,223.03 -6,349.89 -6,562.23 5,951,301.83 371,589.29 2.05 8,627.25 MWD+IFR-AK-CAZ-SC(4) 11,902.08 64.98 226.79 6,319.27 6,263.57 -6,408.43 -6,625.51 5,951,244.33 371,525.08 0.90 8,708.04 MWD+IFR-AK-CAZ-SC(4) 11,995.01 64.86 225.87 6,358.66 6,302.96 -6,466.55 -6,686.39 5,951,187.21 371,463.27 0.91 8,787.37 MWD+IFR-AK-CAZ-SC(4) 12,089.38 64.07 225.87 6,399.34 6,343.64 -6,525.84 -6,747.51 5,951,128.92 371,401.20 0.84 8,867.86 MWD+IFR-AK-CAZ-SC(4) 12,183.80 62.22 225.46 6,441.99 6,386.29 -6,584.70 -6,807.76 5,951,071.05 371,340.01 2.00 8,947.57 MWD+IFR-AK-CAZ-SC(4) 12,278.58 62.36 224.48 6,486.06 6,430.36 -6,644.06 -6,867.06 5,951,012.66 371,279.76 0.93 9,027.30 MWD+IFR-AK-CAZ-SC(4) 12,372.96 63.01 224.46 6,529.37 6,473.67 -6,703.91 -6,925.81 5,950,953.78 371,220.06 0.69 9,107.20 MWD+IFR-AK-CAZ-SC(4) 12,466.15 63.04 224.54 6,571.64 6,515.94 -6,763.14 -6,984.02 5,950,895.50 371,160.90 0.08 9,186.33 M1MD+IFR-AK-CAZ-SC(4) 12,560.81 62.61 224.86 6,614.87 6,559.17 -6,823.00 -7,043.25 5,950,836.61 371,100.71 0.54 9,266.47 MVVD+IFR-AK-CAZ-SC(4) 12,655.36 61.95 225.25 6,658.85 6,603.15 -6,882.13 -7,102.49 5,950,778.46 371,040.53 0.79 9,345.96 MWD+IFR-AK-CAZ-SC(4) 12,750.08 62.27 226.26 6,703.16 6,647.46 -6,940.54 -7,162.46 5,950,721.03 370,979.63 1.00 9,425.14 MWD+IFR-AK-CAZ-SC(4) 12,843.46 63.21 226.42 6,745.93 6,690.23 -6,997.84 -7,222.51 5,950,664.71 370,918.66 1.02 9,503.38 MWD+IFR-AK-CAZ-SC(4) 12,938.76 64.15 226.31 6,788.19 6,732.49 -7,056.79 -7,284.34 5,950,606.78 370,855.89 0.99 9,583.87 MWD+IFR-AK-CAZ-SC(4) 12,938.81 64.15 226,31 6,788.21 6,732.51 -7,056.82 -7,284.37 5,950,606.75 370,855.86 0.00 9,583.91 GYD-GC-MS(5) 9-5/8"x 12-1/4" 12,950.00 63.54 226.00 6,793.14 6,737.44 -7,063.78 -7,291.61 5,950,599.91 370,848.51 5.99 9,593.39 GYD-GC-MS(5) 12,975.00 64.18 224.82 6,804.15 6,748.45 -7,079.53 -7,307.60 5,950,584.41 370,832.27 4.95 9,614.66 GYD-GC-MS(5) 13,000.00 63.89 225.34 6,815.10 6,759.40 -7,095.40 -7,323.51 5,950,568.80 370,816.10 2.20 9,636.01 GYD-GC-MS(5) 13,025.00 64.17 225.27 6,826.05 6,770.35 -7,111.21 -7,339.49 5,950,553.26 370,799.87 1.15 9,657.32 GYD-GC-MS(5) 13,050.00 64.25 225.40 6,836.92 6,781.22 -7,127.03 -7,355.50 5,950,537.70 370,783.61 0.57 9,678.66 GYD-GC-MS(5) 13,075.00 64.20 225.59 6,847.80 6,792.10 -7,142.82 -7,371.55 5,950,522.18 370,767.30 0.71 9,699.99 GYD-GC-MS(5) 13,100.00 64.13 225.38 6,858.69 6,802.99 -7,158.59 -7,387.60 5,950,506.67 370,751.01 0.81 9,721.31 GYD-GC-MS(5) 13,125.00 64.65 224.61 6,869.50 6,813.80 -7,174.53 -7,403.54 5,950,490.99 370,734.81 3.47 9,742.73 GYD-GC-MS(5) 13,150.00 65.19 223.99 6,880.09 6,824.39 -7,190.74 -7,419.35 5,950,475.04 370,718.74 3.12 9,764.32 GYD-GC-MS(5) 13,175.00 65.92 223.54 6,890.44 6,834.74 -7,207.18 -7,435.09 5,950,458.86 370,702.74 3.35 9,786.09 GYD-GC-MS(5) 13,200.00 66.20 222.89 6,900.58 6,844.88 -7,223.83 -7,450.74 5,950,442.47 370,686.82 2.63 9,808.01 GYD-GC-MS(5) 13,225.00 66.64 222.23 6,910.58 6,854.88 -7,240.70 -7,466.24 5,950,425.85 370,671.06 2.99 9,830.06 GYD-GC-MS(5) 13,250.00 66.97 221.37 6,920.43 6,864.73 -7,257.83 -7,481.55 5,950,408.97 370,655.47 3.43 9,852.26 GYD-GC-MS(5) 13,275.00 67.36 220.53 6,930.13 6,874.43 -7,275.24 -7,496.65 5,950,391.81 370,640.09 3.47 9,874.60 GYD-GC-MS(5) 9/8/2014 1:02:00PM Page 6 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 13,300.00 67.39 219.68 6,939.75 6,884.05 -7,292.89 -7,511.52 5,950,374.41 370,624.94 3.14 9,897.06 GYD-GC-MS(5) 13,325.00 67.44 218.72 6,949.35 6,893.65 -7,310.77 -7,526.11 5,950,356.76 370,610.06 3.55 9,919.61 GYD-GC-MS(5) 13,350.00 67.54 217.54 6,958.92 6,903.22 -7,328.94 -7,540.37 5,950,338.83 370,595.51 4.38 9,942.25 GYD-GC-MS(5) 13,375.00 67.25 216.41 6,968.53 6,912.83 -7,347.38 -7,554.25 5,950,320.62 370,581.34 4.33 9,964.97 GYD-GC-MS(5) 13,400.00 66.96 215.39 6,978.26 6,922.56 -7,366.03 -7,567.75 5,950,302.19 370,567.53 3.93 9,987.71 GYD-GC-MS(5) 13,465.21 67.53 212.48 7,003.49 6,947.79 -7,415.92 -7,601.31 5,950,252.86 370,533.17 4.21 10,047.37 MWD+IFR-AK-CAZ-SC(6) 13,560.91 68.34 210.30 7,039.44 6,983.74 -7,491.63 -7,647.50 5,950,177.91 370,485.77 2.27 10,135.77 MWD+IFR-AK-CAZ-SC(6) 13,654.68 69.01 203.92 7,073.57 7,017.87 -7,569.33 -7,687.27 5,950,100.87 370,444.75 6.38 10,223.06 MWD+IFR-AK-CAZ-SC(6) 13,700.47 68.91 199.71 7,090.02 7,034.32 -7,609.00 -7,703.15 5,950,061.47 370,428.23 8.58 10,265.63 MWD+IFR-AK-CAZ-SC(6) 13,748.25 69.13 196.13 7,107.13 7,051.43 -7,651.44 -7,716.87 5,950,019.26 370,413.82 7.01 10,309.69 MWD+IFR-AK-CAZ-SC(6) 13,798.47 69.79 194.58 7,124.75 7,069.05 -7,696.79 -7,729.32 5,949,974.12 370,400.64 3.17 10,355.78 MVVD+IFR-AK-CAZ-SC(6) 13,843.43 69.77 191.80 7,140.29 7,084.59 -7,737.86 -7,738.95 5,949,933.22 370,390.35 5.80 10,396.78 MWD+IFR-AK-CAZ-SC(6) 13,892.22 70.19 189.78 7,157.00 7,101.30 -7,782.88 -7,747.53 5,949,888.34 370,381.04 3.98 10,440.84 M1ND+IFR-AK-CAZ-SC(6) 13,937.58 71.10 188.49 7,172.03 7,116.33 -7,825.14 -7,754.32 5,949,846.20 370,373.57 3.35 10,481.61 MWD+IFR-AK-CAZ-SC(6) 13,986.39 71.07 186.42 7,187.85 7,132.15 -7,870.92 -7,760.31 5,949,800.53 370,366.84 4.01 10,525.17 MWD+IFR-AK-CAZ-SC(6) 14,032.29 70.92 185.22 7,202.80 7,147.10 -7,914.09 -7,764.71 5,949,757.44 370,361.74 2.49 10,565.69 MWD+IFR-AK-CAZ-SC(6) 14,126.12 71.40 181.77 7,233.11 7,177.41 -8,002.71 -7,770.12 5,949,668.92 370,354.90 3.52 10,647.22 MWD+IFR-AK-CAZ-SC(6) 14,220.43 71.92 178.71 7,262.79 7,207.09 -8,092.22 -7,770.49 5,949,579.44 370,353.07 3.13 10,727.27 MWD+IFR-AK-CAZ-SC(6) 14,315.67 72.54 176.02 7,291.86 7,236.16 -8,182.81 -7,766.32 5,949,488.80 370,355.78 2.77 10,806.24 MWD+IFR-AK-CAZ-SC(6) 14,409.52 74.45 174.84 7,318.53 7,262.83 -8,272.50 -7,759.15 5,949,399.02 370,361.50 2.37 10,883.05 MWD+IFR-AK-CAZ-SC(6) 14,503.54 77.35 176.58 7,341.43 7,285.73 -8,363.42 -7,752.33 5,949,308.01 370,366.84 3.57 10,961.12 MWD+IFR-AK-CAZ-SC(6) 14,598.40 76.68 175.26 7,362.75 7,307.05 -8,455.62 -7,745.76 5,949,215.72 370,371.92 1.53 11,040.44 MWD+IFR-AK-CAZ-SC(6) 14,693.07 75.36 171.48 7,385.62 7,329.92 -8,546.85 -7,735.16 5,949,124.34 370,381.03 4.12 11,117.09 MWD+IFR-AK-CAZ-SC(6) 14,787.08 75.52 167.79 7,409.26 7,353.56 -8,636.34 -7,718.80 5,949,034.60 370,395.95 3.80 11,189.57 MWD+IFR-AK-CAZ-SC(6) 14,881.67 75.70 165.45 7,432.78 7,377.08 -8,725.46 -7,697.59 5,948,945.15 370,415.70 2.40 11,259.55 MWD+IFR-AK-CAZ-SC(6) 14,975.07 77.57 165.52 7,454.36 7,398.66 -8,813.43 -7,674.82 5,948,856.84 370,437.05 2.00 11,327.79 MWD+IFR-AK-CAZ-SC(6) 15,069.85 79.46 163.22 7,473.24 7,417.54 -8,902.87 -7,649.79 5,948,767.01 370,460.62 3.10 11,396.32 MWD+IFR-AK-CAZ-SC(6) 15,132.00 81.16 162.43 7,483.70 7,428.00 -8,961.39 -7,631.70 5,948,708.21 370,477.76 3.01 11,440.39 MWD+IFR-AK-CAZ-SC(6) Kick-off Point-7"x 8-3/4"x 9-7/8" 15,145.00 82.00 163.25 7,485.60 7,429.90 -8,973.68 -7,627.91 5,948,695.86 370,481.35 8.99 11,449.65 INC+TREND(7) 15,164.10 82.33 163.11 7,488.21 7,432.51 -8,991.79 -7,622.43 5,948,677.66 370,486.54 1.87 11,463.34 INC+TREND(7) 15,216.01 90.21 162.73 7,491.58 7,435.88 -9,041.27 -7,607.23 5,948,627.95 370,500.93 15.20 11,500.64 INC+TREND(7) 15,251.68 92.21 162.47 7,490.83 7,435.13 -9,075.30 -7,596.57 5,948,593.76 370,511.04 5.65 11,526.20 INC+TREND(7) 15,343.82 88.77 161.39 7,490.04 7,434.34 -9,162.88 -7,567.99 5,948,505.74 370,538.19 3.91 11,591.47 MWD+IFR-AK-CAZ-SC(8) 15,438.85 86.71 161.62 7,493.79 7,438.09 -9,252.92 -7,537.87 5,948,415.22 370,566.85 2.18 11,658.25 MWD+IFR-AK-CAZ-SC(8) 15,532.67 86.75 165.12 7,499.14 7,443.44 -9,342.66 -7,511.07 5,948,325.07 370,592.19 3.72 11,726.25 MWD+IFR-AK-CAZ-SC(8) 15,628.21 87.02 165.11 7,504.33 7,448.63 -9,434.86 -7,486.56 5,948,232.50 370,615.20 0.28 11,797.48 MWD+IFR-AK-CAZ-SC(8) 15,722.62 86.40 163.81 7,509.75 7,454.05 -9,525.66 -7,461.31 5,948,141.30 370,638.98 1.52 11,867.13 MWD+IFR-AK-CAZ-SC(8) 15,816.83 89.63 162.25 7,513.01 7,457.31 -9,615.70 -7,433.83 5,948,050.83 370,664,99 3.81 11,935.10 MWD+IFR-AK-CAZ-SC(8) 15,911.98 88.50 159.95 7,514.57 7,458.87 -9,705.70 -7,403.02 5,947,960.35 370,694.34 2.69 12,001.52 M1ND+IFR-AK-CAZ-SC(8) 16,005.98 88.36 160.14 7,517.14 7,461.44 -9,794.02 -7,370.95 5,947,871.53 370,724.97 0.25 12,065.89 MWD+IFR-AK-CAZ-SC(8) 9/8/2014 1:02 OOPM Page 7 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A 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 16,100.28 89.25 160.21 7,519.11 7,463.41 -9,882.72 -7,338.98 5,947,782.34 370,755.50 0.95 12,130.62 MWD+IFR-AK-CAZ-SC(8) 16,194.91 89.18 160.41 7,520.40 7,464.70 -9,971.80 -7,307.10 5,947,692.76 370,785.93 0.22 12,195.75 MWD+IFR-AK-CAZ-SC(8) 16,289.78 90.01 161.46 7,521.08 7,465.38 -10,061.47 -7,276.11 5,947,602.61 370,815.46 1.41 12,261.79 MWD+IFR-AK-CAZ-SC(8) 16,384.30 90.01 162.34 7,521.06 7,465.36 -10,151.31 -7,246.75 5,947,512.31 370,843.36 0.93 12,328.73 MWD+IFR-AK-CAZ-SC(8) 16,479.19 89.97 163.68 7,521.08 7,465.38 -10,242.05 -7,219.02 5,947,421.14 370,869.62 1.41 12,397.21 MWD+IFR-AK-CAZ-SC(8) 16,572.63 89.97 166.42 7,521.12 7,465.42 -10,332.32 -7,194.92 5,947,330.50 370,892.25 2.93 12,466.90 MWD+IFR-AK-CAZ-SC(8) 16,667.87 89.49 170.75 7,521.57 7,465.87 -10,425.66 -7,176.07 5,947,236.88 370,909.58 4.57 12,541.70 MWD+IFR-AK-CAZ-SC(8) 16,761.84 89.32 174.15 7,522.55 7,466.85 -10,518.79 -7,163.73 5,947,143.56 370,920.41 3.62 12,619.26 MWD+IFR-AK-CAZ-SC(8) 16,853.13 89.56 175.20 7,523.44 7,467.74 -10,609.68 -7,155.25 5,947,052.55 370,927.41 1.18 12,696.55 MWD+IFR-AK-CAZ-SC(8) 16,947.97 89,63 178.04 7,524.11 7,468.41 -10,704.35 -7,149.66 5,946,957.82 370,931.47 3.00 12,778.52 MWD+IFR-AK-CAZ-SC(8) 17,045.46 89.75 179.36 7,524.64 7,468.94 -10,801.81 -7,147.45 5,946,860.35 370,932.10 1.36 12,864.50 MWD+IFR-AK-CAZ-SC(8) 17,139.92 88.06 177.02 7,526.45 7,470.75 -10,896.19 -7,144.47 5,946,765.93 370,933.55 3.06 12,947.39 MWD+IFR-AK-CAZ-SC(8) 17,235.28 89.72 177.19 7,528.29 7,472.59 -10,991.41 -7,139.66 5,946,670.66 370,936.83 1.75 13,030.20 MWD+IFR-AK-CAZ-SC(8) 17,330.21 87.23 176.46 7,530.82 7,475.12 -11,086.15 -7,134.40 5,946,575.85 370,940.55 2.73 13,112.39 MWD+IFR-AK-CAZ-SC(8) 17,397.08 88.18 174.35 7,533.50 7,477.80 -11,152.75 -7,129.05 5,946,509.18 370,944.82 3.46 13,169.41 MWD+IFR-AK-CAZ-SC(8) 17,422.94 90.08 173.33 7,533.89 7,478.19 -11,178.45 -7,126.27 5,946,483.43 370,947.18 8.34 13,191.10 MWD+IFR-AK-CAZ-SC(8) 17,468.58 89.04 169.73 7,534.24 7,478.54 -11,223.59 -7,119.55 5,946,438.20 370,953.17 8.21 13,228.35 MWD+IFR-AK-CAZ-SC(8) 17,517.67 88.94 167.77 7,535.11 7,479.41 -11,271.72 -7,109.98 5,946,389.92 370,961.96 4.00 13,266.99 MWD+IFR-AK-CAZ-SC(8) 17,612.55 89.02 164.36 7,536.79 7,481.09 -11,363.78 -7,087.13 5,946,297.51 370,983.31 3.59 13,338.85 MWD+IFR-AK-CAZ-SC(8) 17,707.55 88.13 162.15 7,539.16 7,483.46 -11,454.72 -7,059.77 5,946,206.15 371,009.19 2.51 13,407.67 MWD+IFR-AK-CAZ-SC(8) 17,802.66 90.10 159.62 7,540.63 7,484.93 -11,544.56 -7,028.64 5,946,115.82 371,038.86 3.37 13,473.81 MWD+IFR-AK-CAZ-SC(8) 17,895.09 89.70 160.02 7,540.79 7,485.09 -11,631.32 -6,996.75 5,946,028.57 371,069.34 0.61 13,536.85 MWD+IFR-AK-CAZ-SC(8) 17,941.65 89.40 162.72 7,541.15 7,485.45 -11,675.43 -6,981.88 5,945,984.22 371,083.49 5.83 13,569.52 MWD+IFR-AK-CAZ-SC(8) 17,990.31 90.69 165.42 7,541.12 7,485.42 -11,722.22 -6,968.53 5,945,937.23 371,096.08 6.15 13,605.25 MWD+IFR-AK-CAZ-SC(8) 18,084.58 90.47 164.95 7,540.16 7,484.46 -11,813.35 -6,944.42 5,945,845.73 371,118.71 0.55 13,675.71 MWD+IFR-AK-CAZ-SC(8) 18,178.65 88.74 166.16 7,540.81 7,485.11 -11,904.44 -6,920.96 5,945,754.28 371,140.69 2.24 13,746.42 MWD+IFR-AK-CAZ-SC(8) 18,273.38 87.73 169.04 7,543.73 7,488.03 -11,996.91 -6,900.63 5,945,661.50 371,159.52 3.22 13,819.77 MWD+IFR-AK-CAZ-SC(8) 18,367.86 88.65 171.18 7,546.71 7,491.01 -12,089.93 -6,884.41 5,945,568.24 371,174.23 2.46 13,895.48 MWD+IFR-AK-CAZ-SC(8) 18,462.73 88.43 172.86 7,549.13 7,493.43 -12,183.85 -6,871.24 5,945,474.13 371,185.87 1.79 13,973.36 MWD+IFR-AK-CAZ-SC(8) 18,557.24 89.40 171.17 7,550.92 7,495.22 -12,277.42 -6,858.12 5,945,380.36 371,197.48 2.06 14,050.95 MWD+IFR-AK-CAZ-SC(8) 18,652.48 89.32 167.37 7,551.98 7,496.28 -12,370.97 -6,840.39 5,945,286.54 371,213.69 3.99 14,126.45 MWD+IFR-AK-CAZ-SC(8) 18,747.71 89.25 165.57 7,553.17 7,497.47 -12,463.55 -6,818.11 5,945,193.63 371,234.46 1.89 14,199.02 MWD+IFR-AK-CAZ-SC(8) 18,841.05 89.95 153.64 7,553.83 7,498.13 -12,550.87 -6,785.64 5,945,105.79 371,265.51 12.80 14,262.32 MWD+IFR-AK-CAZ-SC(8) 18,885.14 89.24 153.90 7,554.14 7,498.44 -12,590.42 -6,766.16 5,945,065.94 371,284,35 1.71 14,288.82 MWD+IFR-AK-CAZ-SC(8) 18,936.58 89.80 147,88 7,554.57 7,498.87 -12,635.34 -6,741.15 5,945,020.62 371,308.63 11.75 14,317.63 MWD+IFR-AK-CAZ-SC(8) 18,981.62 90.20 142.33 7,554.57 7,498.87 -12,672.27 -6,715.39 5,944,983.28 371,333.78 12.35 14,338.97 MWD+IFR-AK-CAZ-SC(8) 19,029.29 89.30 143.80 7,554.78 7,499.08 -12,710.37 -6,686.75 5,944,944.73 371,361.80 3.62 14,360.05 MWD+IFR-AK-CAZ-SC(8) 19,124.73 90.69 142.60 7,554.79 7,499.09 -12,786.79 -6,629.58 5,944,867.40 371,417.72 1,92 14,402.47 MWD+IFR-AK-CAZ-SC(8) 19,231.81 89.04 145.28 7,555.04 7,499.34 -12,873.34 -6,566.55 5,944,779.84 371,479.33 2.94 14,451.29 MWD+IFR-AK-CAZ-SC(8) 19,293.00 89.04 145.28 7,556.06 7,500.36 -12,923.63 -6,531.71 5,944,729.00 371,513.35 0.00 14,480.45 PROJECTED to TD 9/8/2014 1:02:00PM Page 8 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96A Survey Calculation Method: Minimum Curvature Design: CD4-96A Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 4-1/2"x 6-118" 9/8/2014 1:02:00PM Page 9 COMPASS 5000.1 Build 65 E •I.i C.1 O o v U >',n 'Eo 9 73O O O p O C M c *76 60 O c T 0, O E. a o N N y N v 1 C 0-,t; � o • V C V oao oU' O ra 3 TD LA C O : Q- itw++cts O 13 '51 -Q U 1 it C -1C 0 O CO Cr) a C a z E a5 .o CD V) � O 0 c 2 W o a0i .� U o 0 Q _ U .p � 'a wU o (CD D-P Du 0 cB 0) >, C L i5 a (u .S CD C c -t p ami u_ D IL 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N CC N U NADConversion Western North Slope CD4 Nanuq Pad CD4-96APB1 Definitive Survey Report IN 2 7] 08 September, 2014 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Project Western North Slope,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Map Zone: Alaska Zone 04 Using geodetic scale factor Well CD4-96 Well Position +N/-S 0.00 usft Northing: 5,957,544.09 usft Latitude: 70°17'33.155 N +El-W 0.00 usft Easting: 378,252.95 usft Longitude: 150°59'8.492 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 18.90 usft Wellbore CD4-96APB1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 6/5/2014 18.78 80.77 57,576 Design CD4-96APB1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 12,938.76 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (usft) (usft) (usft) (°) 0.00 0.00 0.00 196.28 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 75.32 1,046.10 CD4-96 Gyro(CD4-96) GYD-GC-SS Gyrodata gyro single shots 11/13/2013 12:01 1,139.67 2,869.84 CD4-96 MWD I(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 2,965.61 3,020.73 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND Inclinometer+known azi trend 2/11/2014 12:00. 3,114.99 12,938.76 CD4-96 MWD II(CD4-96) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11/13/2013 12:01 12,950.00 13,400.00 CD4-96APB1 Svy1 SLB_NSG+MSHOT( GYD-GC-MS Gyrodata gyrocompassing m/s 6/16/2014 9:15: 13,465.21 19,979.01 CD4-96APB1 Svy2 SLB-MWD-GMAG(C MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6/23/2014 10:01 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 36.80 0.00 0.00 36.80 -18.90 0.00 0.00 5,957,544.09 378,252.95 0.00 0.00 UNDEFINED 75.32 0.12 214.58 75.32 19.62 -0.03 -0.02 5,957,544.06 378,252.93 0.31 0.04 GYD-GC-SS(1) 104.55 0.19 179.56 104.55 48.85 -0.11 -0.04 5,957,543.98 378,252.91 0.39 0.11 GYD-GC-SS(1) 114.15 0.14 183.36 114.15 58.45 -0.13 -0.04 5,957,543.95 378,252.91 0.51 0.14 GYD-GC-SS(1) 20"x 42" 144.37 0.04 280.72 144.37 88.67 -0.17 -0.05 5,957,543.92 378,252.89 0.51 0.18 GYD-GC-SS(1) 241.06 0.41 229.08 241.06 185.36 -0.39 -0.35 5,957,543.70 378,252.60 0.40 0.47 GYD-GC-SS(1) 333.50 0.51 232.63 333.50 277.80 -0.86 -0.92 5,957,543.25 378,252.01 0.11 1.08 GYD-GC-SS(1) 423.96 0.76 273.71 423.95 368.25 -1.06 -1.84 5,957,543.06 378,251.09 0.56 1.54 GYD-GC-SS(1) 520.36 1.79 306.49 520.33 464.63 -0.13 -3.69 5,957,544.02 378,249.26 1.27 1.16 GYD-GC-SS(1) 9/8/2014 1:00:48PM Page 2 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8©55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 612.19 2.95 333.58 612.08 556.38 2.84 -5.90 5,957,547.03 378,247.10 1.72 -1.08 GYD-GC-SS(1) 703.41 2.13 339.50 703.21 647.51 6.53 -7.53 5,957,550.74 378,245.52 0.94 -4.16 GYD-GC-SS(1) 797.65 2.47 331.34 797.37 741.67 9.96 -9.12 5,957,554.19 378,243.99 0.50 -7.00 GYD-GC-SS(1) 855.62 1.96 316.94 855.30 799.60 11.78 -10.40 5,957,556.03 378,242.75 1.30 -8.39 GYD-GC-SS(1) 950.35 1.65 246.75 949.99 894.29 12.42 -12.76 5,957,556.71 378,240.40 2.21 -8.35 GYD-GC-SS(1) 1,017.27 4.25 216.67 1,016.82 961.12 10.05 -15.12 5,957,554.38 378,237.99 4.39 -5.41 GYD-GC-SS(1) 1,046.10 5.62 215.32 1,045.54 989.84 8.04 -16.58 5,957,552.40 378,236.51 4.77 -3.07 GYD-GC-SS(1) 1,139.67 9.20 213.97 1,138.32 1,082.62 -1.90 -23.41 5,957,542.57 378,229.52 3.83 8.39 MWD+IFR-AK-CAZ-SC(2) 1,233.36 14.14 215.28 1,230.04 1,174.34 -17.47 -34.21 5,957,527.18 378,218.46 5.28 26.36 MWD+IFR-AK-CAZ-SC(2) 1,326.99 19.56 216.77 1,319.62 1,263.92 -39.37 -50.21 5,957,505.54 378,202.11 5.81 51.87 MWD+IFR-AK-CAZ-SC(2) 1,377.22 22.22 214.85 1,366.54 1,310.84 -53.91 -60.67 5,957,491.18 378,191.42 5.47 68.76 MWD+IFR-AK-CAZ-SC(2) 1,422.26 24.40 213.70 1,407.91 1,352.21 -68.64 -70.70 5,957,476.61 378,181.15 4.94 85.71 MWD+IFR-AK-CAZ-SC(2) 1,472.21 26.21 211.32 1,453.06 1,397.36 -86.64 -82.16 5,957,458.79 378,169.40 4.16 106.21 MWD+IFR-AK-CAZ-SC(2) 1,516.77 27.68 209.02 1,492.79 1,437.09 -104.10 -92.30 5,957,441.50 378,158.99 4.04 125.81 MWD+IFR-AK-CAZ-SC(2) 1,567.27 30.11 205.13 1,537.00 1,481.30 -125.83 -103.37 5,957,419.96 378,147.56 6.08 149.77 MWD+IFR-AK-CAZ-SC(2) 1,611.16 33.09 204.16 1,574.38 1,518.68 -146.74 -112.95 5,957,399.21 378,137.65 6.89 172.52 MWD+IFR-AK-CAZ-SC(2) 1,631.32 34.02 203.59 1,591.18 1,535.48 -156.93 -117.46 5,957,389.10 378,132.97 4.87 183.57 MWD+IFR-AK-CAZ-SC(2) 1,705.49 37.52 205.83 1,651.35 1,595.65 -196.28 -135.61 5,957,350.04 378,114.19 5.04 226.44 MWD+IFR-AK-CAZ-SC(2) 1,749.43 39.66 204.96 1,685.69 1,629.99 -221.04 -147.36 5,957,325.48 378,102.04 5.02 253.50 MVVD+IFR-AK-CAZ-SC(2) 1,799.40 41.07 205.18 1,723.77 1,668.07 -250.36 -161.07 5,957,296.40 378,087.86 2.84 285.48 MWD+IFR-AK-CAZ-SC(2) 1,893.90 45.79 206.76 1,792.38 1,736.68 -308.72 -189.55 5,957,238.50 378,058.44 5.12 349.49 MWD+IFR-AK-CAZ-SC(2) 1,988.14 46.53 206.88 1,857.65 1,801.95 -369.38 -220.22 5,957,178.35 378,026.80 0.79 416.32 MWD+IFR-AK-CAZ-SC(2) 2,082.27 46.35 206.41 1,922.52 1,866.82 -430.35 -250.81 5,957,117.89 377,995.23 0.41 483.41 MWD+IFR-AK-CAZ-SC(2) 2,177.28 48.36 207.09 1,986.88 1,931.18 -492.75 -282.27 5,957,056.01 377,962.77 2.18 552.13 MWD+IFR-AK-CAZ-SC(2) 2,273.16 53.76 207.18 2,047.12 1,991.42 -559.09 -316.27 5,956,990.24 377,927.70 5.63 625.35 MWD+IFR-AK-CAZ-SC(2) 2,322.18 56.04 208.88 2,075.30 2,019.60 -594.49 -335.12 5,956,955.16 377,908.27 5.45 664.61 MVVD+IFR-AK-CAZ-SC(2) 2,365.77 57.89 209.54 2,099.07 2,043.37 -626.38 -352.95 5,956,923.56 377,889.93 4.43 700.22 MWD+IFR-AK-CAZ-SC(2) 2,460.71 60.25 210.00 2,147.86 2,092.16 -697.06 -393.39 5,956,853.54 377,848.35 2.52 779.41 MWD+IFR-AK-CAZ-SC(2) 2,554.60 60.50 211.91 2,194.28 2,138.58 -767.05 -435.37 5,956,784.25 377,805.25 1.79 858.36 MWD+IFR-AK-CAZ-SC(2) 2,649.85 61.88 215.06 2,240.19 2,184.49 -836.64 -481.42 5,956,715.43 377,758.08 3.24 938.07 MWD+IFR-AK-CAZ-SC(2) 2,742.86 63.23 219.26 2,283.07 2,227.37 -902.38 -531.28 5,956,650.50 377,707.17 4.26 1,015.16 MWD+IFR-AK-CAZ-SC(2) 2,837.37 63.96 224.05 2,325.12 2,269.42 -965.60 -587.52 5,956,588.21 377,649.91 4.60 1,091.61 MWD+IFR-AK-CAZ-SC(2) 2,869.84 64.39 225.42 2,339.26 2,283.56 -986.36 -608.09 5,956,567.79 377,629.01 4.02 1,117.30 MWD+IFR-AK-CAZ-SC(2) 2,939.12 64.76 229.43 2,369.02 2,313.32 -1,028.68 -654.16 5,956,526.22 377,582.27 5.25 1,170.84 INC+TREND(3) 13-3/8"x 16" 2,965.61 64.93 230.95 2,380.28 2,324.58 -1,044.03 -672.58 5,956,511.17 377,563.61 5.25 1,190.74 INC+TREND(3) 3,020.73 65.46 228.71 2,403.40 2,347.70 -1,076.30 -710.80 5,956,479.53 377,524.87 3.81 1,232.44 INC+TREND(3) 3,114.99 66.20 228.12 2,442.00 2,386.30 -1,133.38 -775.13 5,956,423.50 377,459.64 0.97 1,305.26 MWD+IFR-AK-CAZ-SC(4) 3,209.60 66.52 229.05 2,479.94 2,424.24 -1,190.71 -840.12 5,956,367.23 377,393.72 0.96 1,378.52 MWD+IFR-AK-CAZ-SC(4) 3,303.50 66.16 228.43 2,517.62 2,461.92 -1,247.43 -904.78 5,956,311.58 377,328.17 0.72 1,451.09 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:00:48PM Page 3 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,397.99 64.30 228.94 2,557.21 2,501.51 -1,304.08 -969.21 5,956,255.99 377,262.83 2.03 1,523.53 MWD+IFR-AK-CAZ-SC(4) 3,491.63 64.66 228.61 2,597.55 2,541.85 -1,359.76 -1,032.77 5,956,201.34 377,198.38 0.50 1,594.81 MWD+IFR-AK-CAZ-SC(4) 3,586.27 64.39 228.48 2,638.26 2,582.56 -1,416.33 -1,096.80 5,956,145.83 377,133.44 0.31 1,667.06 MWD+IFR-AK-CAZ-SC(4) 3,680.38 64.59 228.30 2,678.79 2,623.09 -1,472.73 -1,160.31 5,956,090.47 377,069.04 0.27 1,739.01 MWD+IFR-AK-CAZ-SC(4) 3,774.89 64.50 228.51 2,719.41 2,663.71 -1,529.38 -1,224.13 5,956,034.86 377,004.32 0.22 1,811.28 MWD+IFR-AK-CAZ-SC(4) 3,869.26 64.53 227.91 2,760.01 2,704.31 -1,586.15 -1,287.64 5,955,979.13 376,939.90 0.57 1,883.58 MWD+IFR-AK-CAZ-SC(4) 3,963.72 64.41 227.14 2,800.72 2,745.02 -1,643.71 -1,350.51 5,955,922.61 376,876.11 0.75 1,956.46 MWD+IFR-AK-CAZ-SC(4) 4,061.51 64.30 226.49 2,843.05 2,787.35 -1,704.04 -1,414.79 5,955,863.33 376,810.87 0.61 2,032.39 MWD+IFR-AK-CAZ-SC(4) 4,159.70 64.61 226.66 2,885.39 2,829.69 -1,764.93 -1,479.13 5,955,803.49 376,745.55 0.35 2,108.89 MWD+IFR-AK-CAZ-SC(4) 4,254.11 64.15 226.96 2,926.21 2,870.51 -1,823.20 -1,541.20 5,955,746.24 376,682.56 0.57 2,182.22 MWD+IFR-AK-CAZ-SC(4) 4,347.74 63.04 226.53 2,967.85 2,912.15 -1,880.66 -1,602.27 5,955,689.78 376,620.56 1.25 2,254.50 MWD+IFR-AK-CAZ-SC(4) 4,442.50 61.89 225.90 3,011.66 2,955.96 -1,938.80 -1,662.94 5,955,632.63 376,558.97 1.35 2,327.32 MWD+IFR-AK-CAZ-SC(4) 4,536.09 60.62 225.68 3,056.66 3,000.96 -1,996.02 -1,721.75 5,955,576.38 376,499.24 1.37 2,398.73 MWD+IFR-AK-CAZ-SC(4) 4,632.01 59.12 225.96 3,104.81 3,049.11 -2,053.83 -1,781.24 5,955,519.54 376,438.83 1.58 2,470.91 MWD+IFR-AK-CAZ-SC(4) 4,727.18 59.45 225.96 3,153.42 3,097.72 -2,110.71 -1,840.06 5,955,463.63 376,379.10 0.35 2,542.00 MWD+IFR-AK-CAZ-SC(4) 4,821.01 59.37 225.92 3,201.17 3,145.47 -2,166.88 -1,898.10 5,955,408.41 376,320.16 0.09 2,612.19 MVVD+IFR-AK-CAZ-SC(4) 4,915.29 59.38 227.17 3,249.20 3,193.50 -2,222.68 -1,957.00 5,955,353.58 376,260.38 1.14 2,682.26 MWD+IFR-AK-CAZ-SC(4) 5,010.08 60.25 227.14 3,296.86 3,241.16 -2,278.40 -2,017.07 5,955,298.85 376,199.41 0.92 2,752.59 MWD+IFR-AK-CAZ-SC(4) 5,109.39 61.83 227.50 3,344.94 3,289.24 -2,337.30 -2,080.95 5,955,240.99 376,134.60 1.62 2,827.04 MWD+IFR-AK-CAZ-SC(4) 5,203.58 64.83 227.59 3,387.21 3,331.51 -2,394.10 -2,143.04 5,955,185.20 376,071.60 3.19 2,898.98 MWD+IFR-AK-CAZ-SC(4) 5,299.56 64.66 226.40 3,428.17 3,372.47 -2,453.31 -2,206.52 5,955,127.04 376,007.17 1.14 2,973.61 MWD+IFR-AK-CAZ-SC(4) 5,392.87 63.31 226.51 3,469.09 3,413.39 -2,511.08 -2,267.30 5,955,070.27 375,945.47 1.45 3,046.11 MWD+IFR-AK-CAZ-SC(4) 5,486.09 63.57 226.24 3,510.77 3,455.07 -2,568.61 -2,327.66 5,955,013.73 375,884.19 0.38 3,118.25 MWD+IFR-AK-CAZ-SC(4) 5,580.38 63.54 225.13 3,552.76 3,497.06 -2,627.58 -2,388.06 5,954,955.74 375,822.84 1.05 3,191.80 MWD+IFR-AK-CAZ-SC(4) 5,674.61 62.82 226.05 3,595.28 3,539.58 -2,686.43 -2,448.13 5,954,897.88 375,761.84 1.16 3,265.13 MWD+IFR-AK-CAZ-SC(4) 5,769.13 62.64 226.64 3,638.59 3,582.89 -2,744.43 -2,508.92 5,954,840.88 375,700.12 0.59 3,337.85 MWD+IFR-AK-CAZ-SC(4) 5,863.51 62.69 226.90 3,681.93 3,626.23 -2,801.85 -2,570.01 5,954,784.46 375,638.12 0.25 3,410.10 MWD+IFR-AK-CAZ-SC(4) 5,958.90 62.77 226.20 3,725.63 3,669.93 -2,860.16 -2,631.56 5,954,727.15 375,575.64 0.66 3,483.33 MWD+IFR-AK-CAZ-SC(4) 6,053.79 62.47 226.20 3,769.27 3,713.57 -2,918.48 -2,692.38 5,954,669.83 375,513.89 0.32 3,556.36 MWD+IFR-AK-CAZ-SC(4) 6,146.64 62.60 227.14 3,812.10 3,756.40 -2,975.01 -2,752.30 5,954,614.28 375,453.06 0.91 3,627.43 MWD+IFR-AK-CAZ-SC(4) 6,240.58 62.50 227.55 3,855.40 3,799.70 -3,031.50 -2,813.61 5,954,558.80 375,390.85 0.40 3,698.84 MWD+IFR-AK-CAZ-SC(4) 6,336.26 62.65 228.39 3,899.47 3,843.77 -3,088.36 -2,876.69 5,954,502.98 375,326.86 0.79 3,771.11 MWD+IFR-AK-CAZ-SC(4) 6,430.58 62.80 227.96 3,942.69 3,886.99 -3,144.26 -2,939.17 5,954,448.10 375,263.49 0.44 3,842.29 MWD+IFR-AK-CAZ-SC(4) 6,523.57 62.58 228.74 3,985.36 3,929.66 -3,199.18 -3,000.90 5,954,394.20 375,200.88 0.78 3,912.31 MWD+IFR-AK-CAZ-SC(4) 6,617.74 62.04 229.16 4,029.12 3,973.42 -3,253.94 -3,063.79 5,954,340.47 375,137.12 0.70 3,982.50 MWD+IFR-AK-CAZ-SC(4) 6,712.46 63.21 228.93 4,072.67 4,016.97 -3,309.07 -3,127.31 5,954,286.37 375,072.72 1.25 4,053.24 MWD+IFR-AK-CAZ-SC(4) 6,807.18 64.99 230.03 4,114.04 4,058.34 -3,36442 -3,192.08 5,954,232.08 375,007.07 2.15 4,124.53 MWD+IFR-AK-CAZ-SC(4) 6,901.57 66.76 229.83 4,152.62 4,096.92 -3,419.87 -3,258.00 5,954,177.71 374,940.26 1.89 4,196.24 MWD+IFR-AK-CAZ-SC(4) 6,995.55 66.41 230.49 4,189.97 4,134.27 -3,475.12 -3,324.22 5,954,123.54 374,873.17 0.74 4,267.85 MWD+IFR-AK-CAZ-SC(4) 7,090.90 64.90 230.38 4,229.27 4,173.57 -3,530.45 -3,391.19 5,954,069.31 374,805.32 1.59 4,339.74 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:00:48PM Page 4 COMPASS 5000.1 Build 65 Schlurnberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 7,185 57 66.20 230.38 4,268.46 4,212.76 -3,585.41 -3,457.57 5,954,015.44 374,738.06 1.37 4,411.10 MWD+IFR-AK-CAZ-SC(4) 7,279.26 66.23 230.13 4,306.24 4,250.54 -3,640.22 -3,523.49 5,953,961.71 374,671.27 0.25 4,482.20 MWD+IFR-AK-CAZ-SC(4) 7,372.88 66.19 230.38 4,344.01 4,288.31 -3,695.00 -3,589.36 5,953,908.01 374,604.53 0.25 4,553.24 MWD+IFR-AK-CAZ-SC(4) 7,468.22 66.20 229.97 4,382.49 4,326.79 -3,750.86 -3,656.35 5,953,853.24 374,536.64 0.39 4,625.65 MWD+IFR-AK-CAZ-SC(4) 7,561.95 66.09 229.06 4,420.40 4,364.70 -3,806.52 -3,721.55 5,953,798.66 374,470.56 0.90 4,697.36 MWD+IFR-AK-CAZ-SC(4) 7,656.89 66.15 227.79 4,458.83 4,403.13 -3,864.12 -3,786.49 5,953,742.11 374,404.70 1.22 4,770.86 MWD+IFR-AK-CAZ-SC(4) 7,749.14 65.59 227.45 4,496.54 4,440.84 -3,920.87 -3,848.68 5,953,686.39 374,341.60 0.69 4,842.77 MWD+IFR-AK-CAZ-SC(4) 7,844.14 64.30 227.03 4,536.78 4,481.08 -3,979.30 -3,911.86 5,953,629.00 374,277.48 1.42 4,916.57 MWD+IFR-AK-CAZ-SC(4) 7,938.86 64.08 227.23 4,578.02 4,522.32 -4,037.31 -3,974.36 5,953,572.01 374,214.06 0.30 4,989.78 MWD+IFR-AK-CAZ-SC(4) 8,032.81 64.14 226.83 4,619.04 4,563.34 -4,094.92 -4,036.20 5,953,515.41 374,151.30 0.39 5,062.42 MWD+IFR-AK-CAZ-SC(4) 8,125.50 64.11 227.04 4,659.49 4,603.79 -4,151.87 -4,097.13 5,953,459.46 374,089.46 0.21 5,134.17 MWD+IFR-AK-CAZ-SC(4) 8,222.02 63.80 227.20 4,701.87 4,646.17 -4,210.87 -4,160.68 5,953,401.50 374,024.97 0.35 5,208.63 MWD+IFR-AK-CAZ-SC(4) 8,313.92 63.12 227.26 4,742.93 4,687.23 -4,266.70 -4,221.03 5,953,346.66 373,963.73 0.74 5,279.14 MWD+IFR-AK-CAZ-SC(4) 8,411.28 62.18 227.06 4,787.66 4,731.96 -4,325.50 -4,284.44 5,953,288.90 373,899.38 0.98 5,353.36 MWD+IFR-AK-CAZ-SC(4) 8,503.41 62.08 227.39 4,830.73 4,775.03 -4,380.81 -4,344.22 5,953,234.57 373,838.72 0.33 5,423.22 MWD+IFR-AK-CAZ-SC(4) 8,600.42 62.67 227.20 4,875.71 4,820.01 -4,439.11 -4,407.38 5,953,177.31 373,774.62 0.63 5,496.88 MWD+IFR-AK-CAZ-SC(4) 8,691.17 64.04 227.41 4,916.41 4,860.71 -4,494.11 -4,467.00 5,953,123.29 373,714.13 1.52 5,566.39 MWD+IFR-AK-CAZ-SC(4) 8,790.02 63.59 227.25 4,960.03 4,904.33 -4,554.23 -4,532.22 5,953,064.23 373,647.95 0.48 5,642.39 MWD+IFR-AK-CAZ-SC(4) 8,882.67 62.03 227.12 5,002.36 4,946.66 -4,610.24 -4,592.67 5,953,009.22 373,586.60 1.69 5,713.10 MWD+IFR-AK-CAZ-SC(4) 8,976.21 62.04 227.42 5,046.22 4,990.52 -4,666.30 -4,653.36 5,952,954.15 373,525.02 0.28 5,783.93 MWD+IFR-AK-CAZ-SC(4) 9,071.00 61.95 227.15 5,090.73 5,035.03 -4,723.07 -4,714.85 5,952,898.39 373,462.63 0.27 5,855.67 MWD+IFR-AK-CAZ-SC(4) 9,165.30 62.79 227.13 5,134.47 5,078.77 -4,779.90 -4,776.09 5,952,842.56 373,400.48 0.89 5,927.39 MWD+IFR-AK-CAZ-SC(4) 9,258.78 62.00 227.07 5,177.78 5,122.08 -4,836.28 -4,836.77 5,952,787.17 373,338.90 0.85 5,998.53 MWD+IFR-AK-CAZ-SC(4) 9,353.22 62.03 227.12 5,222.10 5,166.40 -4,893.06 -4,897.86 5,952,731.39 373,276.90 0.06 6,070.16 MWD+IFR-AK-CAZ-SC(4) 9,447.52 62.02 227.58 5,266.33 5,210.63 -4,949.48 -4,959.11 5,952,675.97 373,214.75 0.43 6,141.50 MWD+IFR-AK-CAZ-SC(4) 9,541.95 62.38 227.04 5,310.37 5,254.67 -5,006.12 -5,020.51 5,952,620.34 373,152.45 0.63 6,213.08 MWD+IFR-AK-CAZ-SC(4) 9,636.02 62.29 227.14 5,354.05 5,298.35 -5,062.85 -5,081.53 5,952,564.62 373,090.52 0.13 6,284.64 MWD+IFR-AK-CAZ-SC(4) 9,730.64 62.31 227.38 5,398.03 5,342.33 -5,119.70 -5,143.06 5,952,508.77 373,028.08 0.23 6,356.47 MWD+IFR-AK-CAZ-SC(4) 9,825.32 62.82 227.30 5,441.66 5,385.96 -5,176.65 -5,204.86 5,952,452.84 372,965.38 0.54 6,428.45 MWD+IFR-AK-CAZ-SC(4) 9,919.47 63.85 227.56 5,483.91 5,428.21 -5,233.56 -5,266.82 5,952,396.94 372,902.51 1.12 6,500.46 MWD+IFR-AK-CAZ-SC(4) 10,013.65 63.81 227.33 5,525.44 5,469.74 -5,290.73 -5,329.08 5,952,340.80 372,839.33 0.22 6,572.79 MWD+IFR-AK-CAZ-SC(4) 10,109.47 63.92 226.77 5,567.65 5,511.95 -5,349.34 -5,392.05 5,952,283.22 372,775.43 0.54 6,646.71 MWD+IFR-AK-CAZ-SC(4) 10,202.84 63.88 226.62 5,608.73 5,553.03 -5,406.85 -5,453.06 5,952,226.71 372,713.49 0.15 6,719.02 MWD+IFR-AK-CAZ-SC(4) 10,298.09 63.81 227.01 5,650.72 5,595.02 -5,465.36 -5,515.40 5,952,169.22 372,650.22 0.37 6,792.67 MWD+IFR-AK-CAZ-SC(4) 10,390.13 63.74 227.21 5,691.39 5,635.69 -5,521.55 -5,575.90 5,952,114.02 372,588.83 0.21 6,863.57 MWD+IFR-AK-CAZ-SC(4) 10,483.60 63.96 227.44 5,732.58 5,676.88 -5,578.43 -5,637.58 5,952,058.15 372,526.24 0.32 6,935.46 MWD+IFR-AK-CAZ-SC(4) 10,579.65 63.75 228.62 5,774.91 5,719.21 -5,636.09 -5,701.69 5,952,001.55 372,461.21 1.12 7,008.78 MWD+IFR-AK-CAZ-SC(4) 10,675.73 62.80 229.21 5,818.11 5,762.41 -5,692.48 -5,766.37 5,951,946.21 372,395.63 1.13 7,081.05 MWD+IFR-AK-CAZ-SC(4) 10,768.32 63.34 230.34 5,860.05 5,804.35 -5,745.79 -5,829.39 5,951,893.93 372,331.76 1.23 7,149.89 MWD+IFR-AK-CAZ-SC(4) 10,862.66 63.66 231.38 5,902.15 5,846.45 -5,799.08 -5,894.88 5,951,841.71 372,265.43 1.04 7,219.40 MWD+IFR-AK-CAZ-SC(4) 9/8/2014 1:00:48PM Page 5 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Fasting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 10,957.11 64.49 231.37 5,943.44 5,887.74 -5,852.10 -5,961.24 5,951,789.78 372,198.22 0.88 7,288.91 MVD+IFR-AK-CAZ-SC(4) 11,051.39 66.41 231.89 5,982.61 5,926.91 -5,905.33 -6,028.47 5,951,737.65 372,130.14 2.10 7,358.86 MWD+IFR-AK-CAZ-SC(4) 11,145.65 67.42 232.61 6,019.57 5,963.87 -5,958.42 -6,097.03 5,951,685.69 372,060.73 1.28 7,429.04 MWD+IFR-AK-CAZ-SC(4) 11,240.19 66.98 231.89 6,056.20 6,000.50 -6,011.77 -6,165.94 5,951,633.46 371,990.97 0.84 7,499.57 MWD+IFR-AK-CAZ-SC(4) 11,334.03 66.53 231.07 6,093.24 6,037.54 -6,065.47 -6,233.40 5,951,580.87 371,922.66 0.94 7,570.03 MWD+IFR-AK-CAZ-SC(4) 11,428.50 66.27 229.72 6,131.06 6,075.36 -6,120.65 -6,300.10 5,951,526.77 371,855.08 1.34 7,641.70 MWD+IFR-AK-CAZ-SC(4) 11,522.09 67.92 229.41 6,167.49 6,111.79 -6,176.57 -6,365.72 5,951,471.93 371,788.57 1.79 7,713.77 MWD+IFR-AK-CAZ-SC(4) 11,618.23 68.21 228.84 6,203.40 6,147.70 -6,234.93 -6,433.15 5,951,414.68 371,720.21 0.63 7,788.70 MWD+IFR-AK-CAZ-SC(4) 11,709.22 66.54 228.38 6,238.40 6,182.70 -6,290.45 -6,496.16 5,951,360.18 371,656.32 1.89 7,859.67 MWD+IFR-AK-CAZ-SC(4) 11,806.82 6465 227.67 6,278.73 6,223.03 -6,349.89 -6,562.23 5,951,301.83 371,589.29 2.05 7,935.25 MWD+IFR-AK-CAZ-SC(4) 11,902.08 64.98 226.79 6,319.27 6,263.57 -6,408.43 -6,625.51 5,951,244.33 371,525.08 0.90 8,009.18 MWD+IFR-AK-CAZ-SC(4) 11,995.01 64.86 225.87 6,358.66 6,302.96 -6,466.55 -6,686.39 5,951,187.21 371,463.27 0.91 8,082.04 MWD+IFR-AK-CAZ-SC(4) 12,089.38 64.07 225.87 6,399.34 6,343.64 -6,525.84 -6,747.51 5,951,128.92 371,401.20 0.84 8,156.09 MWD+IFR-AK-CAZ-SC(4) 12,183.80 62.22 225.46 6,441.99 6,386.29 -6,584.70 -6,807.76 5,951,071.05 371,340.01 2.00 8,229.49 MWD+IFR-AK-CAZ-SC(4) 12,278.58 62.36 224.48 6,486.06 6,430.36 -6,644.06 -6,867.06 5,951,012.66 371,279.76 0.93 8,303.10 MWD+IFR-AK-CAZ-SC(4) 12,372.96 63.01 224.46 6,529.37 6,473.67 -6,703.91 -6,925.81 5,950,953.78 371,220.06 0.69 8,377.01 MWD+IFR-AK-CAZ-SC(4) 12,466.15 63.04 224.54 6,571.64 6,515.94 -6,763.14 -6,984.02 5,950,895.50 371,160.90 0.08 8,450.19 MWD+IFR-AK-CAZ-SC(4) 12,560.81 62.61 224.86 6,614.87 6,559.17 -6,823.00 -7,043.25 5,950,836.61 371,100.71 0.54 8,524.26 MWD+IFR-AK-CAZ-SC(4) 12,655.36 61.95 225.25 6,658.85 6,603.15 -6,882.13 -7,102.49 5,950,778.46 371,040.53 0.79 8,597.63 MWD+IFR-AK-CAZ-SC(4) 12,750.08 62.27 226.26 6,703.16 6,647.46 -6,940.54 -7,162.46 5,950,721.03 370,979.63 1.00 8,670.51 MWD+IFR-AK-CAZ-SC(4) 12,843.46 63.21 226.42 6,745.93 6,690.23 -6,997.84 -7,222.51 5,950,664.71 370,918.66 1.02 8,742.36 MWD+IFR-AK-CAZ-SC(4) 12,938.76 64.15 226.31 6,788.19 6,732.49 -7,056.79 -7,284.34 5,950,606.78 370,855.89 0.99 8,816.27 MVD+IFR-AK-CAZ-SC(4) 12,938.81 64.15 226.31 6,788.21 6,732.51 -7,056.82 -7,284.37 5,950,606.75 370,855.86 0.00 8,816.31 GYD-GC-MS(5) 9-5/8"x 12-1/4" 12,950.00 63.54 226.00 6,793.14 6,737.44 -7,063.78 -7,291.61 5,950,599.91 370,848.51 5.99 8,825.02 GYD-GC-MS(5) 12,975.00 64.18 224.82 6,804.15 6,748.45 -7,079.53 -7,307.60 5,950,584.41 370,832.27 4.95 8,844.63 GYD-GC-MS(5) 13,000.00 63.89 225.34 6,815.10 6,759.40 -7,095.40 -7,323.51 5,950,568.80 370,816.10 2.20 8,864.32 GYD-GC-MS(5) 13,025.00 64.17 225.27 6,826.05 6,770.35 -7,111.21 -7,339.49 5,950,553.26 370,799.87 1.15 8,883.98 GYD-GC-MS(5) 13,050.00 64.25 225.40 6,836.92 6,781.22 -7,127.03 -7,355.50 5,950,537.70 370,783.61 0.57 8,903.65 GYD-GC-MS(5) 13,075.00 64.20 225.59 6,847.80 6,792.10 -7,142.82 -7,371.55 5,950,522.18 370,767.30 0.71 8,923.30 GYD-GC-MS(5) 13,100.00 64.13 225.38 6,858.69 6,802.99 -7,158.59 -7,387.60 5,950,506.67 370,751.01 0.81 8,942.95 GYD-GC-MS(5) 13,125.00 64.65 224.61 6,869.50 6,813.80 -7,174.53 -7,403.54 5,950,490.99 370,734.81 3.47 8,962.72 GYD-GC-MS(5) 13,150.00 65.19 223.99 6,880.09 6,824.39 -7,190.74 -7,419.35 5,950,475.04 370,718.74 3.12 8,982.71 GYD-GC-MS(5) 13,175.00 65.92 223.54 6,890.44 6,834.74 -7,207.18 -7,435.09 5,950,458.86 370,702.74 3.35 9,002.90 GYD-GC-MS(5) 13,200.00 66.20 222.89 6,900.58 6,844.88 -7,223.83 -7,450.74 5,950,442.47 370,686.82 2.63 9,023.27 GYD-GC-MS(5) 13,225.00 66.64 222.23 6,910.58 6,854.88 -7,240.70 -7,466.24 5,950,425.85 370,671.06 2.99 9,043.82 GY0-GC-MS(5) 13,250.00 66.97 221.37 6,920.43 6,864.73 -7,257.83 -7,481.55 5,950,408.97 370,655.47 3.43 9,064.55 GYD-GC-MS(5) 13,275.00 67.36 220.53 6,930.13 6,874.43 -7,275.24 -7,496.65 5,950,391.81 370,640.09 3.47 9,085.49 GYD-GC-MS(5) 13,300.00 67.39 219.68 6,939.75 6,884.05 -7,292.89 -7,511.52 5,950,374.41 370,624.94 3.14 9,106.60 GYD-GC-MS(5) 13,325.00 67.44 218.72 6,949.35 6,893.65 -7,310.77 -7,526.11 5,950,356.76 370,610.06 3.55 9,127.86 GYD-GC-MS(5) 9/8/2014 1:00:48PM Page 6 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 13,350.00 67.54 217.54 6,958.92 6,903.22 -7,328.94 -7,540.37 5,950,338.83 370,595.51 4.38 9,149.30 GYD-GC-MS(5) 13,375.00 67.25 216.41 6,968.53 6,912.83 -7,347.38 -7,554.25 5,950,320.62 370,581.34 4.33 9,170.89 GYD-GC-MS(5) 13,400.00 66.96 215.39 6,978.26 6,922.56 -7,366.03 -7,567.75 5,950,302.19 370,567.53 3.93 9,192.58 GYD-GC-MS(5) 13,465.21 67.53 212.48 7,003.49 6,947.79 -7,415.92 -7,601.31 5,950,252.86 370,533.17 4.21 9,249.88 MWD+IFR-AK-CAZ-SC(6) 13,560.91 68.34 210.30 7,039.44 6,983.74 -7,491.63 -7,647.50 5,950,177.91 370,485.77 2.27 9,335.50 MWD+IFR-AK-CAZ-SC(6) 13,654.68 69.01 203.92 7,073.57 7,017.87 -7,569.33 -7,687.27 5,950,100.87 370,444.75 6.38 9,421.24 MWD+IFR-AK-CAZ-SC(6) 13,700.47 68.91 199.71 7,090.02 7,034.32 -7,609.00 -7,703.15 5,950,061.47 370,428.23 8.58 9,463.77 MWD+IFR-AK-CAZ-SC(6) 13,748.25 69.13 196.13 7,107.13 7,051.43 -7,651.44 -7,716.87 5,950,019.26 370,413.82 7.01 9,508.35 MWD+IFR-AK-CAZ-SC(6) 13,798.47 69.79 194.58 7,124.75 7,069.05 -7,696.79 -7,729.32 5,949,974.12 370,400.64 3.17 9,555.37 MWD+IFR-AK-CAZ-SC(6) 13,843.43 69.77 191.80 7,140.29 7,084.59 -7,737.86 -7,738.95 5,949,933.22 370,390.35 5.80 9,597.49 MWD+IFR-AK-CAZ-SC(6) 13,892.22 70.19 189.78 7,157.00 7,101.30 -7,782.88 -7,747.53 5,949,888.34 370,381.04 3.98 9,643.12 MWD+IFR-AK-CAZ-SC(6) 13,937.58 71.10 188.49 7,172.03 7,116.33 -7,825.14 -7,754.32 5,949,846.20 370,373.57 3.35 9,685.58 MWD+IFR-AK-CAZ-SC(6) 13,986.39 71.07 186.42 7,187.85 7,132.15 -7,870.92 -7,760.31 5,949,800.53 370,366.84 4.01 9,731.21 MWD+IFR-AK-CAZ-SC(6) 14,032.29 70.92 185.22 7,202.80 7,147.10 -7,914.09 -7,764.71 5,949,757.44 370,361.74 2.49 9,773.88 MWD+IFR-AK-CAZ-SC(6) 14,126.12 71.40 181.77 7,233.11 7,177.41 -8,002.71 -7,770.12 5,949,668.92 370,354.90 3.52 9,860.47 MWD+IFR-AK-CAZ-SC(6) 14,220.43 71.92 178.71 7,262.79 7,207.09 -8,092.22 -7,770.49 5,949,579.44 370,353.07 3.13 9,946.48 MWD+IFR-AK-CAZ-SC(6) 14,315.67 72.54 176.02 7,291.86 7,236.16 -8,182.81 -7,766.32 5,949,488.80 370,355.78 2.77 10,032.27 MWD+IFR-AK-CAZ-SC(6) 14,409.52 74.45 174.84 7,318.53 7,262.83 -8,272.50 -7,759.15 5,949,399.02 370,361.50 2.37 10,116.35 MWD+IFR-AK-CAZ-SC(6) 14,503.54 77.35 176.58 7,341.43 7,285.73 -8,363.42 -7,752.33 5,949,308.01 370,366.84 3.57 10,201.71 MWD+IFR-AK-CAZ-SC(6) 14,598.40 76.68 175.26 7,362.75 7,307.05 -8,455.62 -7,745.76 5,949,215.72 370,371.92 1.53 10,288.37 MWD+IFR-AK-CAZ-SC(6) 14,693.07 75.36 171.48 7,385.62 7,329.92 -8,546.85 -7,735.16 5,949,124.34 370,381.03 4.12 10,372.97 MWD+IFR-AK-CAZ-SC(6) 14,787.08 75.52 167.79 7,409.26 7,353.56 -8,636.34 -7,718.80 5,949,034.60 370,395.95 3.80 10,454.28 MWD+IFR-AK-CAZ-SC(6) 14,881.67 75.70 165.45 7,432.78 7,377.08 -8,725.46 -7,697.59 5,948,945.15 370,415.70 2.40 10,533.88 MWD+IFR-AK-CAZ-SC(6) 14,975.07 77.57 165.52 7,454.36 7,398.66 -8,813.43 -7,674.82 5,948,856.84 370,437.05 2.00 10,611.93 MWD+IFR-AK-CAZ-SC(6) 15,069.85 79.46 163.22 7,473.24 7,417.54 -8,902.87 -7,649.79 5,948,767.01 370,460.62 3.10 10,690.76 MWD+IFR-AK-CAZ-SC(6) 15,165.32 82.07 162.01 7,488.56 7,432.86 -8,992.78 -7,621.64 5,948,676.66 370,487.32 3.01 10,769.18 MW3+IFR-AK-CAZ-SC(6) 15,220.00 83.69 160.33 7,495.33 7,439.63 -9,044.13 -7,604.12 5,948,625.04 370,503.99 4.25 10,813.56 MWD+IFR-AK-CAZ-SC(6) 7"x 8-3/4"x 9-7/8" 15,253.21 84.68 159.32 7,498.70 7,443.00 -9,075.15 -7,592.73 5,948,593.85 370,514.88 4.25 10,840.13 MWD+IFR-AK-CAZ-SC(6) 15,346.63 88.84 158.23 7,503.98 7,448.28 -9,162.07 -7,558.97 5,948,506.40 370,547.23 4.60 10,914.10 MWD+IFR-AK-CAZ-SC(6) 15,443.97 90.93 157.28 7,504.17 7,448.47 -9,252.16 -7,522.12 5,948,415.73 370,582.61 2.36 10,990.24 MWD+IFR-AK-CAZ-SC(6) 15,535.50 91.85 156.00 7,501.95 7,446.25 -9,336.16 -7,485.84 5,948,331.16 370,617.52 1.72 11,060.70 M1ND+IFR-AK-CAZ-SC(6) 15,629.09 90.93 154.19 7,499.68 7,443.98 -9,421.01 -7,446.44 5,948,245.68 370,655.54 2.17 11,131.10 MWD+IFR-AK-CAZSC(6) 15,722.40 87.91 151.97 7,500.63 7,444.93 -9,504.19 -7,404.21 5,948,161.84 370,696.41 4.02 11,199.10 MWD+IFR-AK-CAZ-SC(6) 15,818.35 87.95 150.39 7,504.09 7,448.39 -9,588.20 -7,357.99 5,948,077.10 370,741.27 1.65 11,266.78 MWD+IFR-AK-CAZ-SC(6) 15,913.45 89.01 154.49 7,506.62 7,450.92 -9,672.46 -7,314.01 5,947,992.14 370,783.87 4.45 11,335.33 MWD+IFR-AK-CAZ-SC(6) 16,007.04 89.04 158.54 7,508.21 7,452.51 -9,758.27 -7,276.73 5,947,905.75 370,819.75 4.33 11,407.24 MWD+IFR-AK-CAZ-SC(6) 16,102.56 89.04 157.36 7,509.81 7,454.11 -9,846.79 -7,240.87 5,947,816.67 370,854.17 1.24 11,482.15 MWD+IFR-AK-CAZ-SC(6) 16,196.54 89.21 161.09 7,511.25 7,455.55 -9,934.63 -7,207.55 5,947,728.31 370,886.06 3.97 11,557.13 MWD+IFR-AK-CAZ-SC(6) 16,291.51 89.87 166.58 7,512.01 7,456.31 -10,025.81 -7,181.12 5,947,636.72 370,911.01 5.82 11,637.23 MWD+IFR-AK-CAZ-SC(6) 9/8/2014 1:00:48PM Page 7 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 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 16,340.66 90.07 165.02 7,512.03 7,456.33 -10,073.46 -7,169.06 5,947,588.89 370,922.29 3.20 11,679.59 MWD+IFR-AK-CAZ-SC(6) 16,386.38 89.97 165.08 7,512.02 7,456.32 -10,117.63 -7,157.27 5,947,544.54 370,933.37 0.26 11,718.68 MWD+IFR-AK-CAZ-SC(6) 16,481.48 89.35 164.73 7,512.58 7,456.88 -10,209.45 -7,132.50 5,947,452.34 370,956.64 0.75 11,799.87 MWD+IFR-AK-CAZ-SC(6) 16,574.62 89.56 167.57 7,513.47 7,457.77 -10,299.86 -7,110.21 5,947,361.58 370,977.46 3.06 11,880.41 MWD+IFR-AK-CAZ-SC(6) 16,669.94 89.11 171.80 7,514.58 7,458.88 -10,393.62 -7,093.15 5,947,267.57 370,993.00 4.46 11,965.62 MVVD+IFR-AK-CAZ-SC(6) 16,762.10 89.18 171.60 7,515.95 7,460.25 -10,484.80 -7,079.85 5,947,176.19 371,004.83 0.23 12,049.41 MWD+IFR-AK-CAZ-SC(6) 16,857.81 89.21 175.28 7,517.30 7,461.60 -10,579.86 -7,068.92 5,947,080.97 371,014.22 3.84 12,137.59 MWD+IFR-AK-CAZ-SC(6) 16,951.97 89.42 177.21 7,518.42 7,462.72 -10,673.80 -7,062.75 5,946,986.95 371,018.86 2.06 12,226.04 MWD+IFR-AK-CAZ-SC(6) 17,047.65 89.11 177.80 7,519.65 7,463.95 -10,769.39 -7,058.58 5,946,891.32 371,021.48 0.70 12,316.62 MW3+IFR-AK-CAZ-SC(6) 17,143.93 88.94 177.76 7,521.29 7,465.59 -10,865.58 -7,054.86 5,946,795.09 371,023.65 0.18 12,407.91 MWD+IFR-AK-CAZ-SC(6) 17,236.54 88.87 177.34 7,523.06 7,467.36 -10,958.09 -7,050.90 5,946,702.53 371,026.10 0.46 12,495.59 MWD+IFR-AK-CAZ-SC(6) 17,331.29 88.29 171.92 7,525.41 7,469.71 -11,052.36 -7,042.04 5,946,608.14 371,033.44 5.75 12,583.60 MWD+IFR-AK-CAZ-SC(6) 17,384.06 88.60 170.67 7,526.84 7,471.14 -11,104.50 -7,034.05 5,946,555.88 371,040.57 2.44 12,631.41 MWD+IFR-AK-CAZ-SC(6) 17,425.03 87.84 170.25 7,528.11 7,472.41 -11,144.88 -7,027.27 5,946,515.40 371,046.71 2.12 12,668.27 MWD+IFR-AK-CAZ-SC(6) 17,520.53 87.88 169.04 7,531.68 7,475.98 -11,238.76 -7,010.11 5,946,421.26 371,062.34 1.27 12,753.57 MWD+IFR-AK-CAZ-SC(6) 17,615.23 88.29 167.62 7,534.84 7,479.14 -11,331.45 -6,990.97 5,946,328.28 371,079.97 1.56 12,837.17 MVVD+IFR-AK-CAZ-SC(6) ' 17,710.36 88.70 165.60 7,537.34 7,481.64 -11,423.95 -6,968.95 5,946,235.44 371,100.49 2.17 12,919.79 MWD+IFR-AK-CAZ-SC(6) 17,805.59 90.38 163.45 7,538.11 7,482.41 -11,515.72 -6,943.54 5,946,143.28 371,124.41 2.87 13,000.75 MVVD+IFR-AK-CAZ-SC(6) 17,899.60 90.62 163.49 7,537.29 7,481.59 -11,605.84 -6,916.79 5,946,052.75 371,149.69 0.26 13,079.76 MWD+IFR-AK-CAZ-SC(6) 17,995.02 90.31 163.37 7,536.51 7,480.81 -11,697.30 -6,889.58 5,945,960.87 371,175.41 0.35 13,159.91 MWD+IFR-AK-CAZ-SC(6) 18,089.34 90.00 163.26 7,536.26 7,480.56 -11,787.64 -6,862.50 5,945,870.10 371,201.02 0.35 13,239.04 MWD+IFR-AK-CAZ-SC(6) 18,183.54 88.94 163.34 7,537.13 7,481.43 -11,877.87 -6,835.44 5,945,779.46 371,226.63 1.13 13,318.05 MWD+IFR-AK-CAZ-SC(6) 18,278.42 89.04 163.72 7,538.80 7,483.10 -11,968.84 -6,808.54 5,945,688.07 371,252.04 0.41 13,397.83 MVVD+IFR-AK-CAZ-SC(6) 18,370.51 88.67 165.63 7,540.64 7,484.94 -12,057.63 -6,784.21 5,945,598.91 371,274.93 2.11 13,476.24 MWD+IFR-AK-CAZ-SC(6) 18,466.12 88.46 166.42 7,543.04 7,487.34 -12,150.38 -6,761.12 5,945,505.80 371,296.51 0.85 13,558.80 MWD+IFR-AK-CAZ-SC(6) 18,558.52 89.15 165.46 7,544.96 7,489.26 -12,239.99 -6,738.68 5,945,415.85 371,317.49 1.28 13,638.52 MWD+IFR-AK-CAZ-SC(6) ' 18,655.04 89.21 163.26 7,546.34 7,490.64 -12,332.92 -6,712.67 5,945,322.51 371,342.00 2.28 13,720.43 MWD+IFR-AK-CAZ-SC(6) 18,748.80 88.94 160.95 7,547.86 7,492.16 -12,422.13 -6,683.86 5,945,232.86 371,369.35 2.48 13,797.98 MWD+IFR-AK-CAZ-SC(6) 18,842.94 89.56 159.24 7,549.09 7,493.39 -12,510.64 -6,651.81 5,945,143.86 371,399.96 1.93 13,873.95 MWD+IFR-AK-CAZ-SC(6) 18,938.53 89.63 157.55 7,549.77 7,494.07 -12,599.50 -6,616.62 5,945,054.44 371,433.71 1.77 13,949.38 MWD+IFR-AK-CAZ-SC(6) 19,033.04 89.56 155.91 7,550.43 7,494.73 -12,686.32 -6,579.28 5,944,967.03 371,469.63 1.74 14,022.25 MWD+IFR-AK-CAZ-SC(6) , 19,127.59 89.59 153.15 7,551.14 7,495.44 -12,771.67 -6,538.63 5,944,881.04 371,508.89 2.92 14,092.77 MWD+IFR-AK-CAZ-SC(6) 19,221.99 90.04 151.01 7,551.44 7,495.74 -12,855.08 -6,494.43 5,944,796.94 371,551.73 2.32 14,160.44 MWD+IFR-AK-CAZ-SC(6) 19,314.38 89.93 149.73 7,551.46 7,495.76 -12,935.38 -6,448.75 5,944,715.91 371,596.10 1.39 14,224.72 MWD+IFR-AK-CAZ-SC(6) 19,391.69 90.52 149.52 7,551.16 7,495.46 -13,002.08 -6,409.66 5,944,648.59 371,634.10 0.81 14,277.78 MWD+IFR-AK-CAZ-SC(6) 19,458.89 89.56 149.22 7,551.11 7,495.41 -13,059.90 -6,375.42 5,944,590.23 371,667.40 1.50 14,323.68 MWD+IFR-AK-CAZ-SC(6) 19,504.04 90.17 148.64 7,551.22 7,495.52 -13,098.58 -6,352.12 5,944,551.19 371,690.06 1.86 14,354.26 MWD+IFR-AK-CAZ-SC(6) 19,597.81 89.11 148.22 7,551.81 7,496.11 -13,178.47 -6,303.03 5,944,470.52 371,737.85 1.22 14,417.18 MWD+IFR-AK-CAZ-SC(6) 19,691.36 89.62 149.30 7,552.85 7,497.15 -13,258.45 -6,254.52 5,944,389.77 371,785.06 1.28 14,480.35 MWD+IFR-AK-CAZ-SC(6) 19,786.40 89.97 151.07 7,553.19 7,497.49 -13,340.90 -6,207.27 5,944,306.57 371,830.97 1.90 14,546.25 MWD+IFR-AK-CAZ-SC(6) 9/8/2014 1:00:48PM Page 8 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well CD4-96 Project: Western North Slope TVD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Site: CD4 Nanuq Pad MD Reference: CD4-96:18.9+36.8 @ 55.70usft(Doyon 19) Well: CD4-96 North Reference: True Wellbore: CD4-96APB1 Survey Calculation Method: Minimum Curvature Design: CD4-96APB1 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 19,882.04 89.25 152.39 7,553.84 7,498.14 -13,425.13 -6,161.97 5,944,221.63 371,874.89 1.57 14,614.40 MWD+IFR-AK-CAZ-SC(6) 19,979.01 87.29 152.58 7,556.76 7,501.06 -13,511.09 -6,117.20 5,944,134.96 371,918.26 2.03 14,684.35 MWD+IFR-AK-CAZ-SC(6) 20,050.00 87.29 152.58 7,560.12 7,504.42 -13,574.03 -6,084.54 5,944,071.50 371,949.89 0.00 14,735.61 PROJECTED to TD 9/8/2014 1:00.48PM Page 9 COMPASS 5000.1 Build 65 vi — :} - / _0i _ « - § * u, / / 0 f� % { \ k djj \� 2' � ] 2 k\ % / . , §\ a = c � : � 0 0 E / % . • a) A q E Qs / . o / o ,; / $ Z . 0 g . ) / 0 as c 0 .� / z / / .§ > U) : D % § c \ n _ o c C ° k / o / o @ q o 0 C4- 0 o L 2 % / w � j• k 2 \ co � m / £ » / CO 3 % CO / / El El E] EI 3 k / > 0 £ ) / $ \ g \ 0 I E ± .@ 0 Cement Detail Report s� 0 r4 CD4-96 Conocc*hilhps String: Intermediate#2 Casing Cement Job: DRILLING SIDETRACK, 5/29/2014 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate#2 Casing Cement 6/23/2014 16:15 6/23/2014 18:25 CD4-96A Comment PJSM for cement job-Dowell pump 5 bbls CW100&psi test to 4500 psi(good)-Dowell pump 45 bbls CW100(50 bbls total),50 bbls 12.5 ppg mud push, 165 bbls 15.8 ppg(799 Sks)(1.16 Yield)Qannik blend cement, kick out dart with 20 bbls H2O-Rig displace with 11.0 ppg LSND f/rig&bump plug w/2772 stks- Final circ psi @ 3 bpm=850 psi&increase to 1220 psi&hold for 5 min-CIP @ 18:26 hrs-Periodically reciprocated&rotated pipe during cement job w/100% returns Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Intermediate#2 Casing Cement to 200'above 12,765.0 15,220.0 Yes 10.0 Yes No Cement liner top Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Reclp? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 5 700.0 1,200.0 Yes 20.00 Yes Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Good job,circulated out approximately 10 bbls excess cement after released from liner Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 12,765.0 15,220.0 799 G 165.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.07 15.80 113.3 8.27 Additives Additive Type Concentration Conc Unit label Antifoam D046 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant D065 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.03 gal/sx Page 1/1 Report Printed: 9/22/2014 : ,,,,.',:;,,;::::: Cement Detail Report 01 CD4-96 Conocc*hiflips String: Squeeze 7"Cmt Retainer at 15,150' Job: DRILLING SIDETRACK,5/29/2014 09:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Squeeze 7"Cmt Retainer at 15,150' 7/24/2014 20:23 7/24/2014 21:05 CD4-96A PB1 Comment PJSM for cement job-Dowell pump 2 bbls of MudPush II&psi test to 4,200 psi(good)-Dowell pump 13 bbls MudPush II(15 bbls total), 17 bbls 15.8 ppg"G" cmt,and 15 bbls 12.5 ppg Mudpush II -Rig displace with 10.8 ppg MOBM f/rig at 4 BPM and 1980 psi-FCP.-CIP @ 21:05 hrs-Leaving 2 bbls Cmt in DP- Unsting from retainer and reverse out excess cmt and mud push behind-Tested retainer/cmt to 1500 psi for 10 min ok Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Squeeze 7"Cmt Retainer Isolate previous wellbore 15,150.0 15,650.0 No 2.0 No No at 15,150' 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) 4 5 5 2,390.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Plug Back Cement 15,152.0 15,652.0 73 G 15.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.16 5.10 15.80 78.0 7.37 50.0 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 9/22/2014 z.41 65% WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 22, 2014 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 M K.MIR Anchorage, Alaska 99501 _ RECEIVED AUG04 2014 RE: Drill Collar Severing Tool Record, String Shot Back Off: CD4-96 A AOGCC Run Date: 7/18/2014 - 7/21/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4-96A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20673-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LEITER TO THE ATIENTION OF: Halliburton Wireline& Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: cC5( Lk Signed: ,Lt4-05G RECEIVE' 24kcp3 UL 2 4 2014 WELL LOG TRANSMITTAL AOGCC To: Alaska Oil and Gas Conservation Comm. July 15, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 M K BENDER RE: Tubing Cut, String Shot, Back Off Record: CD4-96A Run Date: 7/9/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD4-96A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20673-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'1"1'LNTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: t‘24 Signed: 6- 4l4% "t , /§ 11/7.%\ s THE STATE �;.. �T (1-) Gar 7,'a, 0f i' s G,`, "1 F /:\‘ Ai 333 West Seventh Avenue GOVERNOR SEAN PARNELL Anchorage, Alaska 99501-3572 Mein 907 279.1433 it � I - I �-b Chip Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD4-96A Sundry Number: 314-428 Dear Mr. Alvord: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P,1k,J,L,,,_ Cathy P oerster Chair ,,/54- DATED this U day of July, 2014. End. ' 1 r RECEIVE STATE OF ALASKA JUL ]. 8 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION m 7/2/4-- APPLICATION ,/, 4-- APPLICATION FOR SUNDRY APPROVALS AOGCU 20 MC 25.280 1.Type of Request Abandon 0 Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program 2• Suspend❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ Stimulate ❑ Alter Casing E Other: ❑ 2.Operator Name. 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ❑ Development Q , 214-056 ' 3.Address: Stratigraphic ❑ Service ❑ 6.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 50-103-20673-01-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CD4-96A Will planned perforations require a spacing exception? Yes ❑ No Q 9.Property Designation(Lease Number). 10.Field/Pool(s): 384209,388077,388902,384211,387209,388905,390337 Colville River Field,Alpine 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): 20050 7560 15446 Casing Length Size MD TVD Burst Collapse Structural Conductor 77 20 114 114 n/a n/a Surface 2903 13.375 2939 2369 5020 2260 Intermediate 10420 9.625 13260 6924 5750 3080 Production 15183 7 15220 7496 7240 5410 Liner Perforation Depth MD(ft). Perforation Depth TVD(ft): Tubing Size. Tubing Grade: Tubing MD(ft): Packers and SSSV Type. Packers and SSSV MD(ft)and TVD(ft). 12.Attachments: Description Summary of Proposal J 13.Well Class after proposed work: Detailed Operations Program ❑✓ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development Q • Service ❑ 14.Estimated Date for 7/19/2014 15.Well Status after proposed work: Commencing Operations: Oil 2, Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 7/16/2014 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative. Victoria Ferguson GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact /� Email 1 - C\va.1 Q Co fi.(04.-- Printed o4- Printed Name / Ln, CGS--4 Title I.A-A✓ ��„ur�. Signature / Phone Die 7fr j (9- COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \4*--"V2../? Plug Integrity ❑ BOP Test V Mechanical Integrity Test ❑ Location Clearance ❑ Other. 0 0 p tt-5f fa 3So6p5 f Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required. /0 — 4 G 7-• APPROVED BY , Approved by:eleP74 — COMMISSIONER THE COMMISSION7o Date. 7— u_/ D ���� 7''�0'� Submrt Form and Form 10-403(Revised 10/2012) App aR IGI NAL months from the date of approv I.� At �uyl hca�R�L 2 2 20.1 , ver 7-/z1 l I 1 ` 1VVV �7��� {,,1�V1��7 ,JU ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPh u I I i ps Telephone 907-276-1215 July 18, 2014 RECEIVED Alaska Oil and Gas Conservation Commission ,ILIL 1 8 2014 333 West 7'h Avenue, Suite 100 Anchorage, Alaska 99501 .OGCC Re: Sundry Permit: CD4-96A Change to Approved Program (PTD: 214-056) V��oo Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a sundry permit to change the operations with the currently approved plan for well CD4-96A(PTD: 214-056). Doyon 19 moved onto CD4-96 and pulled the 3.5" upper completion and 7" tie-back to allow for a bridge plug and whipstock to be set in the 9-5/8" casing. The well was then sidetracked above the HRZ formation and successfully drilled and cased using MPD technology to assist with providing stability through the HRZ, Kalubik, and Miluveach formations. The section was lined with a 7" cemented liner and tied-back to surface. The rig then drilled just over 4,800' of the planned 8,000' production hole (utilizing MPD to prevent wellbore breathing) prior to having to trip out of the hole due to a MWD failure. While tripping out of the hole, the BHA became stuck at the shoe and subsequent attempts to free the fish have been unsuccessful. The plan forward is to sever the BHA, set a whipstock, and sidetrack to re-drill the lateral hole section. / Please find attached: • Form 10-403 Application • Plan forward • Whipstock schematic • Proposed final well schematic If you have any questions or require further information, please contact J.G. Samuell at 265-6309 (John.G.Samuell(a)cop.com) or Rob Stinson at 263-4449. Sincerely, • J.G. Samuell Drilling Engineer CC: CD4-96A Well File J.G. Samuell Rob Stinson Chip Alvord /tomPsP 24 ps' P1J Proposed Plan 1. RIH with e-line and 2" O.D. drill collar severing tool. 2. Correlate with CCL and fire severing charge across jar connection located at the 7" shoe at 15,220' MD. 3. Pull out of hole and rig down e-line. 4. Pull out of hole with drill pipe and lay down severed drill pipe. 5. Run in hole with cement retainer and set at 15,136' MD. 6. Establish injection rate through retainer. 7. Pump 8.5 bbls 15.8 ppg Class G cement through retainer. • 4.5 bbls around BHA from the retainer to the bit • 4 bbls for 100' of coverage in open hole 8. Pull out of retainer and perform charted pressure test to 1,500 psi for 30 minutes. 9. Pull out of hole and lay down running tool. 10. Perform drift run down to retainer with 6.125" mill and casing scraper. 11. Pull out of hole and test BOPE. 12. RIH with whipstock and window mills. 13. Displace well to 9.4 ppg Versapro MOBM system. 14. Set whipstock, mill window and 20' of new formation. 15. Peform FIT. Minimum required to drill ahead to TD of lateral is 11.7 ppg EMW. 16. Pull out of hole using MPD system to mitigate swab and lay down mills and whipstock running tool. 17. RIH with 6-1/8" bit, motor and MWD. Drill —120 of rathole to accommodate RSS and LWD tools. 18. Pull out of hole with motor assembly using MPD system to mitigate swab. 19. Pick up and RIH with 6-1/8" RSS assembly. 20. Drill ahead as per original PTD to section TD of 23,034' MD. AiafZ c l .' "FA a 6-4. vzcC0viras' GLo lz 51 0 ,�l be rfcry ,-icrc' 45 -F0 6lowS .' 4-Pt F# - JDD 3 - 2 0 6 7-3 -70 - o a i CD4-96A Whipstock Schematic–07/18/14 20"94#H-40 Welded Conductor to 114' iii 9-5/8" Liner Top 1,565.8'MD/1,535.7'TVD @30.5° In 0 13-3/8"68#L-80 BTC Al— 2,939' MDI 2,369'TVD @ 64.8°/229.4°azi. TOC –6394'MD(500' above Qannik) iii 9 5/8"40#L-80 BTC-M Liner .' Asi 12,950 MD/6,793'TVD @ 64.2°inc. iiilil .,!,,i..iii..1:! i Top of Whipstock 15,114 MD/7,481'TVD @ 80.6°inc. Cement Retainer 15,136' MD/7,485'TVD @ 81.2°inc. Top Alpine C 15,154' MD/7,487'TVD 7"Shoe 15,220 MD/7,496'TVD @ 83.6°inc. , 6-118" Bit 15,446 MD/7,504'TVD @ 91°inc. Bottom of Cement 15,546 MD/7,502'TVD @ 91.8°inc 6-1/8"Hole,TD at 20,050'MD/7,560'TVD @ 89° r CD4-96A Alpine C Producer Production Sidetrack iprl 9-5/8"Liner Top 1,565.8'MD/1535.7'TVD @ 30.5° Mill/Sidetrack BHA ???? 13-3/8"68#L-80 BTC • 7777 Surface Casing 2939'MD/2369'ND @ 64° iiiiii IN iiiii cemehted to SUrface A • • • 7"x 9 5/8" Liner Top s Packer 12,756' ill MD/6,726' is ND @ 62.8° :a� •: 7"29#L-80 Liner Window: Top: i 15,XXX'MD/7,4XX'TVD 9 5/8"40# i Bottom:15,XXX'MD/7,4XX'TVD L-80 Liner Inc:©_; ° Formation Tops Window: II III. 13,098'MD/6,802'TVD HRZ Top:12,935' MD/6,786' 13,870'MD/7,093'TVD Kalubik TVD Bottom: 12955'MD/ • 1 MD/ 71 6,795'ND �' : 4,108 7,1 ' Mtluveaeh Inc:@ 64° 15,154'MD/7,431'ND 0 . Alpine C 4 111 I i �- ate' iwi J 1 7"26#L-80 Tenaris Blue Liner 6-1/8°Hole,CD4-96A TD Bo51 i 4715,2 0'MD/7,493'TVDI563 8Tail -15446'MD Fish,m of 7 502'TVD '20'05 @M88 7,559.6'TVD l IU ai 90.98°inc. ®_, *All depths are Doyon 19 RKB. Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) 1 ?clo Sent Wednesday,July 16, 2014 6:31 PM To: Samuell,John G Subject: Re:CD4-96A Follow Up Flag: Follow up Flag Status: Flagged Yes,pressure testing the retainer is acceptable. I assume the BHL will be within 500' of the approved PTD. Please submit a sundry for change of approved program. It is acceptable to take the original PTD and highlight any changes. Thanx for the update, Victoria On Jul 16, 2014,at 5:53 PM, Samuell,John G<John.G.Samuell@conocophillips.com>wrote: Victoria, We've been stuck"'230'outside of the 7" shoe on CD4-96A since July 6th.After several unsuccessful backoff attempts and RCT runs,we've decided to call it quits on trying to fish the BHA. During our last run with e-line,we became detained inside the fishing jars and have been trying to fish the e-line assembly with slick line since yesterday. Once we get the e-line fish and fishing jars out of the hole,the plan forward will be to set a cement retainer,squeeze cement into the open hole and use the retainer as a base for a whipstock.The sidetrack well plan will exit the 7"casing parallel the original well path with approximately 50 to 100'of separation.Since we will be drilling in such close proximity to the original hole and setting a production packer above both,will it be acceptable to pressure test the retainer in lieu of placing cement on top? Thank you. J.G. Samuell Drilling Engineer 1 ConocoPhillips Alaska I Direct (907)265-6309 I Mobile (832)465-8148 <2014.07.15 CD4-96A Stuck BHA.pdf><2014.07.16 CD4-96A Whipstock.pdf> 1 pro 21 4--d Sb CD4-96A Whipstock Schematic-07/16/14 20"94#H-40 Welded Conductor to 114' 9-5/8"Liner Top 1,565.8'MD/1,535.7'TVD @ 30.5° illiiIial fdiiii 13-318"68#L-80 BTC 2,939'MD/2,369'TVD @ 64.8°/229.4°azi. TOC -6394'MD(500' above Qannik) lilli 9 5/8"40#L-80 BTC-M Liner .i.I•i .11.1.! 12,950 MD/6,793'TVD @ 64.2°inc. '.., Top of Whipstock 15,114 MD/7,481'TVD @ 80.6°inc. €> Cement Retainer 15,136'MD/7,485'TVD @ 81.2°inc. Top Alpine C 15,154'MD/7,487'TVD 7"Shoe 15,220 MD/7,496'TVD @ 83.6°inc. 6-1/8"Bit 15,446 MD/7,504'TVD @ 91°inc. 6-1/8"Hole,TD at 20,050'MD/7,560'TVD @ 89° CD4-96A Stuck Pipe Schematic—07/15/14 ill 20"94#H-40 Welded Conductor to 114' 9-5/8"Liner Top 1,565.8'MD/1,535.7'TVD @ 30.5° Ar /6. 13-3/8"68#L-80 BTC 2,939'MD 12,369'TVD @ 64.8°/229.4°azi. TOC —6394'MD(500' above Qannik) li ii III 4"Drill Pipe from 11,313'MD to surface Baker Fishing BHA 11,313 MD/6,085'TVD @ 66.6°inc. E-Line Fish 11,583 MD/6,190'TVD @ 68.2°inc. 3-1/2"Drill pipe 11,675 MD/6,225'TVD @ 67.5°inc. 9 5/8"40#L-80 BTC-M Liner 4 12,950 MD/6,793'TVD @ 64.2°inc. Top Alpine C 15,154'MD/7,487'TVD Partial RCT cut 15,124 MD/7,483'TVD @ 81°inc. Ai t , 7"Shoe 15,220 MD/7,496'TVD @ 83.6°inc. 6-1/8"Bit 15,446 MD/7,504'TVD @ 91° inc. 6-1/8"Hole,TD at 20,050'MD/7,560'TVD @ 89° Ferguson, Victoria L (DOA) From: Samuell,John G <John.G.Samuell@conocophillips.com> Sent: Wednesday,July 16, 2014 5:54 PM To: Ferguson,Victoria L(DOA) Subject: CD4-96A PTD 214-056 Victoria, We've been stuck^230'outside of the 7"shoe on CD4-96A since July 6` •After several unsuccessful backoff attempts and RCT runs,we've decided to call it quits on trying to fish the BHA. During our last run with e-line,we became detained inside the fishing jars and have been trying to fish the e-line assembly with slick line since yesterday. Once we get the e-line fish and fishing jars out of the hole,the plan forward will be to set a cement retainer,squeeze cement into the open hole and use the retainer as a base for a whipstock.The sidetrack well plan will exit the 7" casing parallel the original well path with approximately 50 to 100'of separation.Since we will be drilling in such close proximity to the original hole and setting a production packer above both,will it be acceptable to pressure test the retainer in lieu of placing cement on top? Thank you. J.G. 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'n g tl38 [ F In L3228 gg g. ,- A o� mmo 2 $ �aoao 2 PC{:n naryn" a Si� Rnn.iP nX€ N 8!! !. a24MIy�%m8 O HMryiN et MlV p g e ^'^^ LLn.n x - NN girn8g 8gppg 'M3' ; a y j m i LL LL a Og civ+N j� a .1.,7U mHL1. n Xm tl tl "Im O - uzF cn �Pi:n� ngSmr' xa nIt ' N 8 o C 1 .2 Prb Regg, James B (DOA) �1ao 51;0 From: Regg,James B (DOA) Sent: Thursday,July 10, 2014 10:26 AM 1`e44 ?I i O((4 To: Samuell,John G Cc: DOA AOGCC Prudhoe Bay; Schwartz, Guy L (DOA) Subject: RE:AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine ba;,, Y'e go✓fn c6vufr clt r-fr,Q . CRU CD4-96A Pc iaat_c( ,,,,c G,c,Q,[ Li.r3 4L . PTD 2140560 /li(.G 3/4 //S- Thank you for providing the daily reports. Request for extension to commence testing BOPE (beyond 14 day window) is approved based on prolonged issues with stuck pipe. Please continue to update our Inspectors by email (aogcc.inspectors@alaska.gov) as you work to resolve and when you can confirm BOPE test time. Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 orjim.regg@alaska.gov. From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Thursday, July 10, 2014 10:09 AM To: Regg, James B (DOA) Subject: RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine J.G. Samuell Drilling Engineer ConocoPhillips Alaska Direct,(907)265-6309 I Mobile (832)465-8148 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, July 10, 2014 10:02 AM To: Samuell, John G Subject: [EXTERNAL]RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Send daily reports for past 3 days Jim Regg Supervisor, Inspections AOGCC 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 1 CONFIDENTIALITY NOTICE:This e-mail messag,., . .,.luding any attachments,contains information frog... .e Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.reggPalaska.sov. From: Samuell, John G [mailto:John.G.Samuell@conocophillips.com] Sent: Thursday, July 10, 2014 7:20 AM To: Regg, James B (DOA) Subject: FW: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Mr. Regg, We are due for our bi-weekly BOP test at midnight tonight. We're currently stuck 230' outside of the shoe and have had issues getting backed off. We're running in with an RCT to cut the drill pipe above the BHA so we can get out of the hole to test our BOP's. We expect to have the RCT on depth around lunch time today. If the cut is successful, we could potentially be out of the hole tomorrow evening. We would need a variance for the bi-weekly BOP test statute. Please let me know how you would like us to proceed. Thank you. J.G. Samuell Drilling Engineer I ConocoPhillips Alaska I Direct:(907)265-6309 I Mobile (832)465-8148 From: Doyon 19 Company Man Sent: Thursday, July 10, 2014 6:08 AM To: Crisp, John H (DOA) Cc: Samuell, John G Subject: RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Jon, We are currently making up a RCT tool to cut the 3%2" drill pipe above the 4" HWDP to fish it. Estimated time to the cut point and correlation will put us about noon today. Potentially pulling pipe tonight around 8pm. I will contact our town folks on getting an extension as I do not think we will make it in time even setting a storm packer. I will update you later todayafter we fire the RCT togiveyou another update. p Thanks Rick gijorljus / Rbtuu Dort lopoii 19 Rig uperbi5ors' Rig ifloor ()ffire 670-4350 From: Crisp, John H (DOA) [mailto:john.crisp@alaska.gov] Sent: Wednesday, July 09, 2014 10:22 PM To: Doyon 19 Company Man Cc: Samuell, John G Subject: [EXTERNAL]Re: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Please contact our Anchorage office if extension is needed for two week test cycle. You have kept us informed of progress, thank you. Progress update in the morning please. Sent from my iPhone 2 On Jul 9, 2014, at 6:36 PM, "Doyon 19 Company Man" <doyonl@conocophillips.com> wrote: Jon, Looking forward on a worst case scenario our BOPE test is due tomorrow at midnight, if we do not get loose of the fish in time and get out of the hole/set a storm packer to start testing how should we proceed as far as notifications and asking for a variance for testing BOPE until pipe is free. Thanks for all help extended our direction. Rick Tgiorlms. / Man!Derr lovon 19 Rig +uperbi5or5 Rig camp Office G70-4300 Rig,door Office 670-4350 From: Crisp, John H (DOA) [mailto:john.crispOalaska.gov] Sent: Wednesday, July 09, 2014 6:11 PM To: Doyon 19 Company Man Subject: [EXTERNAL]RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine OK From: Doyon 19 Company Man [mailto:doyon1@ conocophillips.com] Sent: Wednesday, July 09, 2014 6:09 PM To: Crisp, John H (DOA) Subject: RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Jon, Our string shot failed to fire. We are currently coming out of the hole to inspect the tools.The soonest I can see us testing now is tomorrow night if everything goes as planned now. I will update you in the morning. Thanks Rich 1 orlju5 / abant Darr 3opott 19 Rig 6uperbigor5 Ata ramp Office 670-4300 Rig Poor Office 670-4350 From: Crisp, John H (DOA) [mailto:john.crispOalaska.gov] Sent: Wednesday, July 09, 2014 3:01 PM To: Doyon 19 Company Man Subject: [EXTERNAL]RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Notification received, thank you. From: Doyon 19 Company Man [mailto:doyon1Oconocophillips.com] Sent: Wednesday, July 09, 2014 2:58 PM To: Crisp, John H (DOA) Subject: RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Jon, 3 We are currently at 13,000'guu g in the hole with the string shot to back cm. I will update you later this afternoon when we have it free and the projected updated time for our BOPE test. Thanks 3Mck ISjorbuo / Sbaui 3orr Mopon 19 ikiq 6uperUt5or5 1ig ramp efftcc 670-4300 Rig Jffoor Office 670-4330 From: Crisp, John H (DOA) [mailto:john.crisD alaska.gov] Sent: Tuesday,July 08, 2014 5:01 PM To: Doyon 19 Company Man; DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine Notification received,thank you. From: Rick Bjorhus [mailto:noreplv0formresponse.com] Sent: Tuesday, July 08, 2014 4:50 PM To: DOA AOGCC Prudhoe Bay; DOA AOGCC Prudhoe Bay Subject: AOGCC1 Test Witness Notification Request: BOPE, Doyon 19, CD4-96A, Alpine kimage001.jpg> Question Answer Type of Test Requested: BOPE Requested Time for 07-10-2014 8:00 AM Inspection Location Doyon 19, CD4-96A, Alpine Name Rick Bjorhus E-mail doyonl@conocophillips.com Phone Number (907) 670-4350 Company Conoco Phillips Alaska Inc. We are currently stuck at 15,446'. We have E-line and fishing hand onsight in preparation for backing off the pipe. Our best Other Information: calculated estimate for being ready to test BOPE's is Thursday morning. We will advise as things progress or digress. Thanks Rick Bjorhus Submission ID: 270676208621686391 4 0,„ I'/%".tv THE STATE L a c'J, 1 all,:: ?� 1a- ,, _ ,; f- - _�''"_ - .)L. 2- ,J_—_,,,,, �`,L.) i_\_,I L 1€ tE� --- 1 = 333 West Seven`h Avenue ��_ , GOVERNOR SEAN PaRNF,L1. Anchorage, Alaska 99501-3572 Main 907 279 1 z133 (;'�� F r:a' Q1-171_7, 7,A2 Graham L. Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Alpine Oil Pool, CD4-96A ConocoPhillips Alaska, Inc. Permit No: 214-056 Surface Location: 2863.31' FNL, 4953.88' FEL, SEC. 19, T11N, R5E, UM Bottomhole Location: 3326.69' FNL, 4756.31' FEL, SEC. 1, T1ON, R4E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, di,,,, p4,_„1/4_,_. Cathy P. yloerster Chair DATED this S day of May, 2014. STATE OF ALASKA RECEIVED P k OIL AND GAS CONSERVATION COMA )N PERMIT TO DRILL APR 2 8 2014 20 AAC 25.005 1 a.Tyipz,of Work: lb.Proposed Well Class: Development-Oil ❑., , Service- Winj ❑ Single Zone ❑✓ . 1 c.Specify /• 00 G fd or. Drill E-] Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ■ Gas Hydrates ❑ Redril El, Reentry ❑ Exploratory ❑ Service- WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • CD4-96A 3.Address: 6.Proposed Depth: / ` 12.Field/Pool(s): P.O.Box 100360,Anchorage,AK 99510-0360 MD: 2384' 2 0341 TVD: 7590' Colville River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number).ADL Alpine Oil Pool • Surface: 2863.31 FNL;4953.88 FEL;Sec19;T11N;R5E;UM 384209,388077,388902,384211,387209,388905,390337 Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date' 1298.71 FNL,2344.95 FEL,Sec35;T11N,R4E;UM Tobin No.932351,932357,300618 6/1/2014 Total Depth. 9.Acres in Property: 2560 14.Distance to Nearest Property: 3326.69 FNL;4756.31 FEL;Sect;T10N;R4E;UM - 1,950'from ADL 390672 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10 KB Elevation above I 55.2 t feet 15.Distance to Nearest Well Open Surface. x-378253 y- 5957544 Zoi 4 • GL Elevation above I 18.9 • feet to Same Pool: 2000' 16.Deviated wells. Kickoff depth: / 9 ) feet ?AV, 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: j,, 99-7 degrees Downhole: 3435 ' Surface: 2675 , 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" 94# H-40 Welded 77 37 37 114 114 12 yds 16" 13.375" 68# L-80 BTC-M 2903 36 36 2939 2369 1375 sx AS Lite,336 sx Class G 12.25" 9.625" 40# L-80 BTC-M 10420 2840 2332 13260 6924 1230 sx Class G,220 sx Qannik Blend 8 75"x 9 875" 7.0" 26# L-80 IBTM/Blue 15143 37 37 15180 7484 428 sx 15.8# 6.125" 4.5" 12.6# L-80 IBT-M 8054 15030 7464 23084 7590 Liner with frac sleeves 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): 14,158 Casing Length Size Cement Volume MD TVD Conductor/Structural 80.00 20 114 114 Surface 2,902.40 13.875 449.5 bbls 2939 2368.9 Intermediate 11,694.20 9.625 549.5 bbls 13260 6924.7 Production 13,036.30 7 n/a 13,070.10 6844.8 Liner 1,086.60 4.5 n/a 14146 7246.5 Perforation Depth MD(ft): 14059.0-14078.0 Perforation Depth TVD(ft): 7216.7-7223.2 20. Attachments: Property Plat ❑ BOP Sketch ❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch ❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements0 21. Verbal Approval: Commission Representative: Date 412.eitZo l4- 22. I hereby certify that the foregoing is true and correct. Contact Email C.. 1•cA{rJr A Q Cap.COA. Printed Name /d _ ��nn� Title l)u, , ,_ � 1 ` Signature / L Phone 2,4s -L(2D Date 4(Ly(2o(c-- Commission Commission Use Only Permit to Drill / API Number: Permit Approval See cover letter for other Number: �19 -' 06 W 50- 103- a 0(0'7,3 --O/-00 Date: 4I'I requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: [l; Other. /2 y� Samples req'd: Yes Ei' No Mud log req'd:Yes n ,No 7✓0 P f e 5 4 f° `350 0 /- S / HZS measures: Yes No❑ Directional svy req'd:Yes,t=!d✓No❑ Spacing exception req'd: Yes Ill No[" Inclination-only svy req'd:Yes❑ No ai APPROVED BY (7 Approved by: ..967 COMMISSIONER THE COM IS ION Date:,3 '3 RIn .. p�J, Submit Form and Form 10-401(Revised 10/2012) This permit is v rd 4 r{) flit of approval(20 C 25.005(8)) Attachments in Duplicate VLF 5-/2/4 r 2ey ConocoPhillips Alaska,Inc. RECEIV E D P.O.Box 100360 Anchorage,AK 99510-0360 ConocoPhillips Tel: 907-276-1215 APR 2 8 2014 April 28th,2014 AOGCC Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,AK 99501 Re: Application for Permit to Drill CD4-96A Dear Sir or Madam: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill an onshore production well from the CD4 drilling pad with rig Doyon 19. The intended spud date for this well is 6/1/14. CD4-96A is planned to be a horizontal Alpine C sand producer.The original wellbore,CD4-96,was drilled down past the Kuparuk C at which point further progress was halted due to communication issues with the Steerable Drilling Liner tool (SDL). The decision was made to run a 4.5"liner and perforate the Kuparuk C until the rig could return to CD4 after the 2014 winter drilling season at CD3. The plan is to re-enter the well and sidetrack off of a whipstock out of the 9-5/8"intermediate#1 casing at 12,950' MD/ 6,793' TVD.The second intermediate will be drilled with a 8-3/4" x 9-7/8"drilling assembly down to the Alpine C sand. Managed Pressure Drilling technology will be utilized to assist with providing stability through the HRZ,Kalubik, and Miluveach formations.The section will be lined with a 7"cemented liner and tied-back to surface on a subsequent run. The production interval will be comprised of a 6-1/8"horizontal hole that will be geo-steered in the Alpine C sand at 89° inclination.Managed Pressure Drilling will be used in this hole section to prevent wellbore breathing during connections.Once the drilling assembly is pulled from the hole,thewell will be completed as a producer with a 4.5"liner with sliding frac sleeves.A 3.5"tubing upper completion will then be run. 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 proposed completion diagram 4. A drilling fluids program summary 5. Pressure information as required by 20 ACC 25.035(d)(2) 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b) Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information,please contact J.G. Samuell at 265-6309 (John.G.Samuell(a,conocophillips.com)or Chip Alvord at 265-6120. Sincerely, cc: CD4-96A Well File/Sharon Allsup-Drake ATO 1530 Rob Stinson ATO 1728 Chip Alvord ATO 1570 J.G. Samuell Jack Walker ATO 1740 Drilling Engineer Lanston Chin Kuukpik Corp Ap on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 CD4-96A Application for Permit to Drill Document 4-4 al OOHS' ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.0050 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) Requirements of 20 AAC 25.050(b) 3. Blowout Prevention Equipment Information 3 Requirements of 20 AAC 25.005(c)(3) 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005 (c)(5) 6. Casing and Cementing Program 5 Requirements of 20 AAC 25.005(c)(6) 7. Diverter System Information 5 Requirements of 20 AAC 25.005(c)(7) 8. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 9. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005 (c)(9) 10. Seismic Analysis 7 Requirements of 20 AAC 25.005 (c)(10) 11. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(1 I) 12. Evidence of Bonding 7 Requirements of 20 AAC 25.005(c)(12) CD4-96A APD Page 1 of 14 ORIGINAL Printed:28-Apr-14 • Ap on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 13. Proposed Drilling Program 7 Requirements of 20 AAC 25.005(c)(13) 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 8 Requirements of 20 AAC 25.005(c)(14) 15. Attachments 8 Attachment 1 Drilling Hazards Summary 9 Attachment 2 Well Schematic 11 Attachment 3 Cement Summary 12 Attachment 4 MPD Equipment Layout 13 Attachment 5 Directional Plan..........................................................................................................15 CD4-96A APD Page 2of14 ORIGINAL Printed:28-Apr-14 Apr 'on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 1. Well Name (Requirements of 20 AAC 25.005 (0) The well for which this application is submitted will be designated as CD4-96A. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned for: Location at Surface 2863.31' FNL, 4,953.88' FEL, Sec 19, T11N,R5E,UM NAD 1927 RKB Elevation_ 55.55'AMSL Northings: 5,957,544.09 Eastings: 378,252.95 Pad Elevation 18.9'AMSL Location at Top of Productive Interval 1384.06'FNL,2309.92' FEL, Sec 35,T11N,R4E,UM (Heel) NAD 1927 Measured Depth, RKB: 15,222.34' Northings: 5,948,592.15 Eastings: 370,509.81 Total Vertical Depth, RKB: 7,498.55' Total Vertical Depth, SS: 7,443.0' Location at Total Depth 3326.69' FNL, 4756.31' FEL, Sec 1,T10N,R4E,UM (Toe) NAD 1927 Measured Depth, RKB: 23,033.76' Northings: 5,941,322.90 Eastings: 373,225.83 Total Vertical Depth, RKB: 7,590.55' Total Vertical Depth, SS: 7,535.0' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Doyon 19. CD4-96A APD Page 3 of 14 Printed:28-Apr-14 ORIGINAL • Ap' 'on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: Casing Csg Setting Depth Fracture Pore pressure ASP Drilling Size(in) MD/TVD(ft) Gradient(ppg) (psi) (psi) 9.625 12,950/6,793 14.0 3,074 2,638 7 15,222/7,498 12.5 3,387 2,675 4.5 23,034/7,590 12.5 3,435 N/A PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) 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 J D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where: FPP=Formation Pore Pressure at the next casing point FPP=0.4525 x TVD 1. ASP CALCULATIONS a. Drilling below intermediate liner(9-5/8") ASP=[(FG x 0.052)—0.1] D =[(14.0 x 0.052)—0.1]x 6793 =4266 psi OR ASP=FPP—(0.1 x D) =3393—(0.1 x 7498')=2643 psi b. Drilling below intermediate casing(7") ASP=[(FG x 0.052)—0.1] D =[(13.0 x 0.052)—0.1]x 7498=4319 psi OR ASP=FPP—(0.1 x D) 3435—(0.1 x 7590')=2675 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; Please see Attachment 2-Drilling Hazards Summary CD4-96A APD Page 4 of 14 Printed:28-Apr-14 ORIGINAL Ap on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out surface casing shoe and perform LOT test or FIT in accordance with the Alpine LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cement in Place Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) ��) (1b/ft) Grade Conn. (ft) (ft) (ft) Cement in Place 20 42 65 H-40 Welded 81 Surf 114/114 Cemented 4/28/12 Cemented on 10/27/13 to Surface with 13-3/8 16 68 L-80 BTC-M 2,903 Surf 2,939/2,369 1137 sx ASLite Lead 10.7 ppg, 328 sx Class G Tail Slurry 15.8 ppg Cemented on 11/17/13 with 1230 sx Class 9-5/8 12-1/4 40 L-80 BTC-M 11,694 1,566/1,536 13,260/6,924 G Lead at 12.2 ppg w/TOC at 6307'MD (Qannik Isolation)followed by 220 sx Class G Tail at 15.8 ppg Casing and Cementing Program Csg/Tbg Hole Weight Length Top MD/TVD Btm MD/TVD OD(in) Size(i, (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Tie- 7 26 L-80 BTC-M 12,764 Surf 12,800/6,726 Uncemented tie-back back 8-3/4 Tenaris 878.4 sx Class G 15.8 ppg to liner top at 7 x 9- 26 L-80 Blue 2,422 12,800/6,726 15,222/7,498 12,800 MD 7/8 EUE- 3 1/2 n/a 9.3 L-80 14,994 Surf 15,222/7,498 n/a 8RD-M ' 4 1/2 6-1/8 12.6 L-80 IBT-M 5,429 15,222/7,498 23,034/7,590 Open hole liner w/frac sleeves 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) N/A. Surface hole already cased and cemented. CD4-96A APD Page 5 of 14 Printed:28-Apr-14 ORIGINAL Apr on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Intermediate#2 Production Hole Size 8-3/4"x 9-7/8" 6-1/8" Casing 7.0" 4.5"liner , Density 10.8 ppg 9.4 ppg PV 20-25 15-22 YP 15 - 18 10- 15 Initial Gels 15—20 9— 12 10 Minute Gels 20-30 12 -20 API Filtrate <2 cc/30 min <2 cc/30 min HPHT Fluid Loss @ 160°F 2—4 cc/30 min 2—4 cc/30 min pH n/a n/a 0/0 by wt.CaCl2 20% 25% Oil/Water Ratio 80/20 80/20 Intermediate#2: The intermediate section will be drilled with a Mineral Oil-Based Mud(MOBM).Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation,particularly after the reservoir is penetrated. Maintain mud weight at 10.8 ppg and be prepared to add loss circulation material. Good filter cake quality,hole cleaning and maintenance of low drill solids(by diluting and running centrifuge as required)will all be important in maintaining wellbore stability. Production Hole: The horizontal production interval will be drilled with M-I SWACO's Versapro MOBM drill-in fluid. Sized calcium carbonate will be used as a bridging agent for proper filter cake building and fluid loss control.Micronized barite will be on location if higher than expected reservoir pressures are encountered. Diagram of Doyon 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. CD4-96A APD Page 6 of 14 Printed:28-Apr-14 ORIGINAL • Ap' on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005(c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of20AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 3: Completion Schematic. 1. Pick up motor BHA and run in hole to kick-off from window. 2. Once sidetrack is confirmed,pull out of hole for a 8-3/4"rotary steerable assembly with a 9-7/8"hole opener. 3. Trip in hole to TD with rotary steerable assembly. 4. Displace LSND to 10.8 ppg mineral oil-based mud. 5. Install rotating head element. Hold 11.8 ppg EMW at the window by holding backpressure during connections. 6. Drill hole to intermediate casing point into the Alpine C sand maintaining 11.8 ppg EMW with MPD system (LWD Program: GR/RES/PWD). .1 7. At TD,circulate until hole is clean. 8. Weight up to 11.8 ppg and pull out of hole on elevators. 9. Change upper VBRs to 7"solid body rams. Test same to 250/3500 psi. 10. Run in hole with 7"liner on 5"drill pipe. Stop at 9-5/8"shoe and drop ball to convert auto-fill to float equipment. 11. Run in hole to TD. 12. Circulate and reduce mud weight to 10.8 ppg. 13. Cement 7"liner while reciprocating and rotating if possible. 14. Land drill pipe dart in liner wiper plug and pressure up to set hanger and to release liner running tool. 15. Set 7"x 9-5/8"packer. 16. Circulate out any excess cement. 17. Pull out of hole with liner running tool and lay down same. 18. Run 7"tie-back. 19. Displace backside of 7"to corrosion inhibited brine and diesel freeze protect.Test tie-back seals. 20. Change upper rams to 3-1/2"x 6"VBR's.Test BOPE to 250/3500 psi. 21. Pick up RIH with 6.125"drilling assembly.(LWD Program: GR/PWD/AZI.RES.). Test casing to 3500 psi. CD4-96A APD Page 7of14 ORIGINAL Printed:28-Apr-14 • Ap on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 22. Drill out and perform LOT. Minimum acceptable leak-off for drilling ahead is 11.8 ppg EMW. 23. Install RCD element to hold back pressure during connections to minimize wellbore breathing. 24. Drill 6.125"horizontal section to TD. 25. Circulate the hole clean,weight up for trip margin and pull out of hole. 26. Run lower completion of 4-1/2"liner with frac sleeves,liner top hanger/packer and swell packers for zonal isolation. 27. Run upper completion of 3-1/2,9.3#,L-80 EUE tubing with SSSV,3 GLM,BHP gauge,Premier Packer,XN profile and wireline entry guide. 28. Space out and land hanger. 29. Install 2 way check and pressure test hanger seals to 5000 psi.Nipple down BOP. 30. Install tubing head adapter assembly.Pressure test adapter assembly to 5000 psi. Remove 2 way check. 31. Test tubing and tubing-casing annulus separately to 3500 psi/30 mins. 32. Drop ball and rod. Shear circulation valve in GLM. 33. Circulate tubing to diesel and install freeze protection in the annulus. 34. Set BPV and secure well.Move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005 (c)(14)) Incidental fluids developed from drilling operations on well CD4-96A will be injected into a permitted annulus on the CD4 pad,or the Class 1 disposal well on CD1 pad. CD4-96A will not be a viable candidate for annular injection due to the three string casing design. 15. Attachments Attachment 1 Drilling Hazards Summary Attachment 2 Completion Schematic Attachment 3 Cement Summary&Calculations Attachment 4 MPD Equipment Schematic Attachment 5 Directional Plan CD4-96A APD Page 8 of 14 f 3 I G I N A L Printed:28-Apr-14 • Ap- on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 Attachment 1 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 8-3/4"x 9-7/8"INTRM2 Section-7"Liner w/Tieback Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Low circulating density(ECD)monitoring,mud rheology,lost circulation material. Borehole Instability Moderate Use MPD equipment to provide a constant BHP while drilling and tripping pipe Reduced trip speeds,mud properties,proper hole filling,pumping Hole swabbing on trips Moderate out of hole,real time equivalent circulating density(ECD) monitoring,weighted sweeps. Abnormal Reservoir Pressure Low Well control drills,increased mud weight.No mapped faults occur across the path of the planned wellbore. Hydrogen Sulfide gas Low H2S drills,detection systems, alarms,standard well control practices, mud scavengers 6-1/8"Hole/Horizontal Production Hole Event Risk Level Mitigation Strategy Reduced pump rates,reduced trip speeds,real time equivalent Lost circulation Moderate circulating density(ECD)monitoring,mud rheology, lost circulation material Wellbore breathing Moderate Use MPD equipment to maintain constant BHP to prevent wellbore from breathing fluid back into wellbore Hole swabbing on trips Moderate Reduced trip speeds,mud properties,proper hole filling,pumping out of hole,ECD monitoring,weighted sweeps. BOPE drills,Keep mud weight above 9.9 ppg. Check for flow Abnormal Reservoir Pressure Medium during connections and if needed, increase mud weight.Well control drills,increased mud weight. Hydrogen Sulfide gas Low H2S drills,detection systems,alarms,standard well control practices, mud scavengers Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050(b)is provided in the following attachments. Min. Ellipse Clearance Summary Based on Comparison Well Name MD(ft) Distance Depth(ft) Separation @MD(ft) Factor Minimum (ft) ,._ (ft) CD4-25-CD4-25-CD4-25 14,828.37 207.38 14,828.37 61 08 14,725 00 1 42 Centre Distance CD4-25-CD4-25-CD4-25 14,778.63 225.68 14,778 63 50 34 14,825 00 1 29 Clearance Factor CD4-25-CD4-25L1-CD4-25L1 14,828.37 207.38 14,828.37 60.95 14,725 00 1.42 Centre Distance CD4-25-CD4-25L1-CD4-25L1 4,778 63 225 68 14,778 63 50.20 14,825.00 1.29 Clearance Factor CD4-25-CD4-25PB1-CD4- 14,645 80 211.66 14,645.80 62.76 14,725 00 1 42 Centre Distance 25PB1 CD4-25-CD4-25PB1 -CD4- 14,593.84 233.30 14,593 84 42.64 14,850.00 1.22 Clearance Factor 25PB1 CD4-96-CD4-96-CD4-96 12,950.00 0.00 12,950 00 -0.91 12,950.00 0.00 Centre Distance CD4-96-CD4-96-CD4-96 12,974 99 0.46 12,974.99 -0.95 12,975 00 0 33 Clearance Factor CD4-96A APD Page 9 of 14 Pnnted:28-Apr-14 ORfGINAL Ap• on for Permit to Drill,Well CD4-96A Saved:28-Apr-14 Drilling Area Risks: Reservoir Pressure: Offset injection has the potential to increase reservoir pressure over predicted. Although this is unlikely,the rig will be prepared to weight up if required. Lower Shale Stability: HRZ/Kalubik/Miluveach in the intermediate#2 hole section will require higher mud weights than historically used to enhance wellbore stability. Managed pressure drilling will be used in conjunction with a 4- string casing design to mitigate shale instability. 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 taking swabbed kicks. CD4-96A APD Page 10 of 14 Printed:28-Apr-14 O1GNAL Ap, Dn for Permit to Drill,Well CD4-96A Saved:28-Apr-14 Attachment 2—Well Schematic CD4 -96 Alpine C Producer wp18 Proposed Schematic updated 7/29/2013 by J.Samuell All depths are Doyon 19 RKB. 20"94#H-40 Welded Conductor to 114' Upper Completion: Length 1)4-W 12.6#/ft IBT-M Tubing(2jts) O XO to 3-W'EUE tubing 2)3-1/2"TRMAXX-5E SSSV 1.5' 2.812"X Profile(5.176"OD) O II 3)3-'/"x 1"Camco KBMG GLM (xx°)w/DV 7' 1J 4)3-W x 1"Camco KBMG GLM(xx°)w/DV 7' 5)3-1/2"x 1"Camco KBMG GLM(xx°)w/DCK2 7' 13-3/8"68#L-80 BTC pinned for 2500 psi casing to tbg shear Surface Casing 6)SLB BHP Gauge,Encapsulated I-Wire 1.5' 2994'MD/2400'TVD @ 64 w/cannon clamps on every joint cemented to surface 7)Baker Premier Packer 3.5"x 7" 10' 8)HES XN nipple 2.750"ID 1.5' 9)\A/LEG 1.5' O =� Lower Completion: 10)Flexlock Liner Hanger 60' XO 5"Hydril 563 Box X 4'/"TSH-563 pin Planned TOC 11)Baker CMD sliding sleeve for high water cut isolation in 9 5/8—6394'ft MD 12)Swell packers for high water cut isolation Qannik 13)4-W sliding frac sleeves O 6894'MD 14115'TVD 14)Baker P-Sleeve 15)Baker WIV(wellbore isolation valve) 16)Orange Peel Shoe 3-112" 9.3#L-80 EUE 7"x 9 518"Liner Top Packer +i @—13221'MD f • 1' \11. O Swept heel/high 9 518"40#L-80 water production BTC-3 Liner CD to 13371'MD/ 6968'TVD @65° 1111111- r0 0 0 0 Top Alpine C 0 l 4 0 0 0 15140'MD/7479'TVD Q 9.8-10.5ppg " Q 0 7"26#L-80 Tenaris Blue Liner 41/2"12.6#L-80 Liner —400'7"29#TH1l0SS Tenaris Blue Tail to 15180'MD/7484'TVD @ 83' CD4-96A APD Page 11 of 14 R I G I N A L Printed:28-Apr-14 • Apr Dn for Permit to Drill,Well CD4-96A Saved:28-Apr-14 Attachment 3—Cement Summary 7"Intermediate liner run to 15180'MD/7484' TVD Top of slurry is designed to be at liner top at 12,850' MD,which will isolate the Alpine C and Kuparuk C. Assume 40% excess annular volume. Lead Slurry: (15222'-12950')x 0.2646 ft3/ft x 1.40(40%excess) =841.7 ft3 annular vol. (12950'-12800')x 0.1585 ft3/ft x 1.00(no excess)=23.8 ft3 liner lap vol. (15222'-15162')x 0.2148 ft3/ft x 1.00(no excess)= 12.9 ft3 shoe track vol. Total volume=814.7+23.8+ 12.9=845.8 ft3=>878.4 Sx @ 1.16 ft3/sk System: 729.1 Sx Class G+0.4%D167,0.3%D65,0.11%B155,0.2%D46 @ 15.8 ppg yielding 1.16 ft3/sk CD4-96A APD Page 12 of 14 Printed:28-Apr-14 ORIGINAL Q - pvv rn co l 0 �� Q o > / I c hi v) / _ ! 1 Z / N O / m ■i' / a 8 illiri o IC E14 T U 9 ::44w. O itp a- 0_ 4 1NOM00d11 u� b N Q C ® t Ii of 2 8 ,111 ,il I I �---- Q. I o I a 7� � y1 • . . I I III I 0 0. .0 a i ® MP3$ 0 ik^ 111 a 1------- — -----I 111al Q r lii � 111::I I 1 ir (I LIColl Ioo4011:014 A i > li II 1 1 > > I ' I I I II �� - i i i =F—MI I 011 r ■ ■ }ag III 1 1 1 I u_ ;?I� ORIGINAL ConocoPhillips(Alaska) Inc. Western North Slope CD4 Nanuq Pad CD4-96 Plan: CD4-96A Plan: CD4-96Awp21 Standard Proposal Report Perrnit PaCK 21 April, 2014 ORIGINAL Easting(5500 ft/in) \11/4: Plirtf \ q 1\ _\ c"r-s ••a CD'-07PB2 ���• � AIR- 38P;�..CD4-07 -x'-45CD -12Lr 3 ,- ' CD!-;59A-45 -3 CD -[r•b1-07 PI a, t�;�' ,,!;�:.,10�- t 'ad D2 3 • \ CD -1gD1-11 • 0,40.,....,,,,....... 1064, t._,. • - schrund 2 \\ C* 01. .i• .`:"�48' 4 4.4,4 1wp0 D1 r6 _ CD2 • p0• CD' 4* -40 CI - 1-20 CD2.6 m.,,9,!• • \CD•-58k CD2-52 CD1-2=9 CD1-46 CDt„ 6 Cb 4CD1-48 CD5-. •07 b•i•is;e;,-v_y�•5202-27 CD4-3`18 p b• D417 " `• CD1-48A CDSOBwp 7w , ♦�• •! i "1CD2-61wp06 CD4-:6 1,.-•6 AW-9Cwp06 CCD5-11wp07 CD -30 .1. Vier,... r � anu Pd CD5-315PB1w.•09 �. aaCD4-301A CD5-314PB1w 09Illb CD -.to . •"I - ��` \`, �\\ ` CD4-301 gyp`''��.'--- K* 2- \7I - CD444110/1 //. • Jr� gpRt 04-321 - ` rj. '�� • D4 290198 ` z �:� 10* ����f�.. C'4- •0 �. .� _? CD5-315wp09 CD5-314wp09 .� C '..-4 4 r.c �"r''287wp02 • lei% -_, ; CD4-292 _ c 4 w.r q�r x, 209 CD4-286wp01 - N o� • 5 anuq 5 _g t al"": 'i'•=:3 D4-214 Z3,,_j@PB1 E CD4- •PB3 _ CD4-2' CD4 wp08 CD4-295wp02 CD4-•1r•' +4-208A CD4-210A - CD4-96Awp21 fkat 18 of kat 1 • .t 1A Easting(5500 ft/in) ORIGINAL Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 Project Western North Slope 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 Site CD4 Nanuq Pad Site Position: Northing: 5,957,908.57ft Latitude: 70°17'36.666 N From: Map Easting: 377,794.25 ft Longitude: 150°59'22.031 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.93 ° Well CD4-96 Well Position +N/-S 0.00 ft Northing: 5,957,544.09 ft Latitude: 70°17'33.155 N +El-W 0.00 ft Easting: 378,252.95 ft Longitude: 150°59'8.492 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 18.90 ft Wellbore Plan:CD4-96A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2013 6/5/2014 14.63 79.75 57,344 Design CD4-96Awp21 Audit Notes: Version: Phase: PLAN Tie On Depth: 12,950.00 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (0) 36.65 0.00 0.00 196.29 NAD 27 4/21/2014 3:58:15PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL CD4-96Awp21 Plan View 0_ ;0, 13-3/8" x 16'--- 08 o 0 -3000- 54) .o . co 9-5/8"x 12 o1/4"- CD4-96 kip° &9000— 7"x 8-3/4"x 0 -12000- -15000— ,02:\ 4-1/2 x 00'6—• CP(' -15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West(-)/East(+) (3000 ft/in) ORIGINAL CD4-96Awp21 Plan View -6750- 9-5/8"x 12-1/4"- e -7200— 000 07650— CD4-96 28100- 5 0 cn -8550— -9000— 11 21 7"x 8-3/4"x 9-7 GOR g6P.NP I I I I -9450 -9000 -8550 -8100 -7650 -7200 -6750 -6300 -5850 -5400 West(-)/East(+) (450 ft/in) ORIGINAL CD4-96Awp21 Section View -2000- : 0— 1° 1000 o° ) 2000- o0 00 0 00 d o0 cu ho 0o HRZ Base 0 13-3/8" x 16" co ^000 o HRZ Top K-1 0 4000- moo 0o Kup C 3 0 o0 000 Q o c) LCU v 0 m ,� o' Alp C F= 6000- 4Vc?, ,\,o '® ,p '0 0 0 0 0 CO m ' ,' o° ; 0 ° 0 0 o do o 0 0 ' , 4)O,-' O f� 6)CO 6) O N CO r a- aou Cit Aflt 8000- 9-5/8" x 12-1/4" g -a 0 rn 4-1/2 x 6-1/8" cQt 7"x 8-3/4"x 9-7/8" U 10000- 1 i I i I i I I i 0 2000 4000 6000 8000 10000 12000 14000 16000 Vertical Section at 196.28° (2000 ft/in) ORIGINAL CD4-96Awp21 Section View 6600 9-5/8" x 12-1/4" oo iso HRZ Top 6800 HRZ Base K-1 c Kup C X7000 c o LOU CV ,o o • -- Q a CD 07200 ro - _--_ _ --- - _ a UQ > co Alp C co a) 0) p 4 ot 7400 4 o coo-0 o U w- ° O o 0 0 U c) rn - 0 0 0 o Go o co,' N ;4^D O 7600 O -a 7"x 8-3/4"x 9-7/8" ' 4-1/2 x 6-1/8" 7800 9000 10000 11000 12000 13000 14000 15000 16000 17000 Vertical Section at 196.28° (1000 ft/in) ORIGINAL Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 12,950.00 64.20 226.32 6,793.00 6,737.45 -7,063.87 -7,291.75 0.00 0.00 0.00 0.00 12,969.60 65.09 224.63 6,801.39 6,745.84 -7,076.29 -7,304.38 9.00 4.55 -8.59 -60.00 12,989.60 65.09 224.63 6,809.81 6,754.26 -7,089.20 -7,317.12 0.00 0.00 0.00 0.00 13,923.20 71.83 188.61 7,162.45 7,106.90 -7,851.62 -7,692.07 3.65 0.72 -3.86 -85.83 14,244.09 71.83 188.61 7,262.53 7,206.98 -8,153.07 -7,737.70 0.00 0.00 0.00 0.00 15,128.48 79.75 157.69 7,484.55 7,429.00 -8,991.53 -7,632.80 3.50 0.90 -3.50 -79.44 15,221.85 83.00 157.69 7,498.55 7,443.00 -9,076.92 -7,597.76 3.48 3.48 0.00 0.05 15,241.85 83.00 157.69 7,500.99 7,445.44 -9,095.28 -7,590.23 0.00 0.00 0.00 0.00 15,591.71 92.20 151.39 7,515.64 7,460.09 -9,410.37 -7,440.15 3.18 2.63 -1.80 -34.55 15,608.17 92.20 151.39 7,515.00 7,459.45 -9,424.81 -7,432.27 0.00 0.00 0.00 0.00 16,148.69 90.00 168.47 7,504.55 7,449.00 -9,930.52 -7,247.56 3.18 -0.41 3.16 97.12 16,185.80 89.85 168.81 7,504.60 7,449.05 -9,966.90 -7,240.25 1.00 -0.41 0.91 114.41 16,849.60 89.85 168.81 7,506.38 7,450.83 -10,618.07 -7,111.40 0.00 0.00 0.00 0.00 17,018.70 89.36 165.46 7,507.55 7,452.00 -10,782.90 -7,073.76 2.00 -0.29 -1.98 -98.31 17,179.72 89.42 168.68 7,509.26 7,453.71 -10,939.80 -7,037.74 2.00 0.04 2.00 88.88 18,067.48 89.42 168.68 7,518.22 7,462.67 -11,810.25 -6,863.50 0.00 0.00 0.00 0.00 18,809.64 89.15 153.84 7,527.55 7,472.00 -12,511.05 -6,625.75 2.00 -0.04 -2.00 -91.16 23,033.33 89.15 153.85 7,590.55 7,535.00 -16,301.83 -4,764.14 0.00 0.00 0,00 89.94 4/21/2014 3:58:15PM Page 3 COMPASS 2003.16 Build 69 OG1N. AL Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/.W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,737.45 12,950.00 64.20 226.32 6,793.00 6,737.45 -7,063.87 -7,291.75 5,950,599.82 370,848.37 0.87 8,825.51 KOP:9°/100'DLS,-60°TF,for 19.6' 12,950.01 64.20 226.32 6,793.00 6,737.45 -7,063.88 -7,291.76 5,950,599.81 370,848.36 0.00 8,825.52 9-6/8"x 12-1/4" 12,969.60 65.09 224.63 6,801.39 6,745.84 -7,076.29 -7,304.38 5,950,587.60 370,835.54 9.00 8,840.97 Hold for 20' 12,989.60 65.09 224.63 6,809.81 6,754.26 -7,089.20 -7,317.12 5,950,574.91 370,822.59 0.00 8,856.94 Start 3.66°/100'DLS,-85.85°TF,for 937.87' 13,000.00 65.12 224.22 6,814.19 6,758.64 -7,095.94 -7,323.72 5,950,568.28 370,815.88 3.65 8,865.26 13,098.88 65.45 220.26 6,855.55 6,800.00 -7,162.42 -7,384.09 5,950,502.78 370,754.46 3.65 8,946.01 HRZ Top 13,100.00 65.45 220.21 6,856.01 6,800.46 -7,163.20 -7,384.74 5,950,502.02 370,753.79 3.65 8,946.94 13,200.00 65.89 216.24 6,897.23 6,841.68 -7,234.76 -7,441.10 5,950,431.38 370,696.28 3.65 9,031.44 13,300.00 66.42 212.29 6,937.67 6,882.12 -7,310.34 -7,492.58 5,950,356.65 370,643.59 3.65 9,118.41 13,400.00 67.06 208.38 6,977.17 6,921.62 -7,389.62 -7,538.96 5,950,278.14 370,595.94 3.65 9,207.52 13,500.00 67.79 204.50 7,015.58 6,960.03 -7,472.28 -7,580.05 5,950,196.16 370,553.51 3.65 9,298.39 13,600.00 68.61 200.67 7,052.72 6,997.17 -7,557.99 -7,615.70 5,950,111.05 370,516.49 3.65 9,390.66 13,677.49 69.31 197.74 7,080.55 7,025.00 -7,626.27 -7,639.48 5,950,043.17 370,491.60 3.65 9,462.87 HRZ Base 13,700.00 69.52 196.89 7,088.47 7,032.92 -7,646.39 -7,645.75 5,950,023.15 370,485.01 3.65 9,483.94 13,800.00 70.51 193.15 7,122.66 7,067.11 -7,737.14 -7,670.09 5,949,932.82 370,459.21 3.65 9,577.88 13,866.75 71.21 190.68 7,144.55 7,089.00 -7,798.83 -7,683.10 5,949,871.35 370,445.20 3.65 9,640.74 K-1 13,900.00 71.57 189.46 7,155.16 7,099.61 -7,829.86 -7,688.61 5,949,840.42 370,439.19 3.65 9,672.07 13,923.20 71.83 188.61 7,162.45 7,106.90 -7,851.62 -7,692.07 5,949,818.72 370,435.38 3.65 9,693.92 13,927.47 71.83 188.61 7,163.78 7,108.23 -7,855.63 -7,692.68 5,949,814.72 370,434.71 0.00 9,697.94 Hold for 321.58' 14,000.00 71.83 188.61 7,186.40 7,130.85 -7,923.76 -7,702.99 5,949,746.77 370,423.29 0.00 9,766.23 14,099.88 71.83 188.61 7,217.55 7,162.00 -8,017.59 -7,717.19 5,949,653.19 370,407.57 0.00 9,860.28 Kup C 14,100.00 71.83 188.61 7,217.59 7,162.04 -8,017.71 -7,717.21 5,949,653.08 370,407.55 0.00 9,860.39 14,119.12 71.83 188.61 7,223.55 7,168.00 -8,035.67 -7,719.93 5,949,635.16 370,404.55 0.00 9,878.39 LCU 14,200.00 71.83 188.61 7,248.78 7,193.23 -8,111.65 -7,731.43 5,949,559.38 370,391.82 0.00 9,954.55 14,244.09 71.83 188.61 7,262.53 7,206.98 -8,153.07 -7,737.70 5,949,518.07 370,384.88 0.00 9,996.07 14,249.05 71.86 188.43 7,264.07 7,208.52 -8,157.72 -7,738.39 5,949,513.43 370,384.11 3.50 10,000.73 Start 3.5°/100'DLS,-79.41°TF,for 879.93' 14,300.00 72.20 186.59 7,279.79 7,224.24 -8,205.77 -7,744.73 5,949,465.49 370,377.00 3.50 10,048.63 14,400.00 72.91 182.99 7,309.79 7,254.24 -8,300.82 -7,752.69 5,949,370.59 370,367.50 3.50 10,142.10 14,500.00 73.68 179.43 7,338.54 7,282.99 -8,396.56 -7,754.71 5,949,274.91 370,363.93 3.50 10,234.56 14,600.00 74.51 175.90 7,365.95 7,310.40 -8,492.64 -7,750.78 5,949,178.79 370,366.30 3.50 10,325.67 14,700.00 75.40 172.39 7,391.91 7,336.36 -8,588.69 -7,740.92 5,949,082.60 370,374.60 3.50 10,415.11 14,800.00 76.34 168.91 7,416.32 7,360.77 -8,684.36 -7,725.16 5,948,986.70 370,388.80 3.50 10,502.52 14,900.00 77.33 165.47 7,439.10 7,383.55 -8,779.29 -7,703.57 5,948,891.44 370,408.85 3.50 10,587.58 15,000.00 78.37 162.04 7,460.15 7,404.60 -8,873.13 -7,676.22 5,948,797.17 370,434.68 3.50 10,669.98 4/21/2014 3:58:15PM Page 4 COMPASS 2003.16 Build 69 ORIGINAL Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65©55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,423.85 15,100.00 79.44 158.65 7,479.40 7,423.85 -8,965.52 -7,643.22 5,948,704.26 370,466.18 3.50 10,749.41 15,128.48 79.75 157.69 7,484.55 7,429.00 -8,991.53 -7,632.80 5,948,678.10 370,476.17 3.50 10,771.45 CD4-96 Heel DK 10Jun13(copy)(copy) 15,128.98 79.77 157.69 7,484.64 7,429.09 -8,991.98 -7,632.62 5,948,677.64 370,476.35 3.48 10,771.83 Start 3.48°/100'DLS,0.05°TF,for 93.37' 15,184.31 81.69 157.69 7,493.55 7,438.00 -9,042.49 -7,611.89 5,948,626.80 370,496.26 3.48 10,814.50 Alp C 15,200.00 82.24 157.69 7,495.74 7,440.19 -9,056.87 -7,605.99 5,948,612.33 370,501.92 3.48 10,826.65 15,221.85 83.00 157.69 7,498.55 7,443.00 -9,076.92 -7,597.76 5,948,592.16 370,509.82 3.48 10,843.58 15,222.34 83.00 157.69 7,498.61 7,443.06 -9,077.37 -7,597.58 5,948,591.71 370,510.00 0.00 10,843.96 Hold for 20'-7"x 8-3/4"x 9-7/8" 15,241.85 83.00 157.69 7,500.99 7,445.44 -9,095.28 -7,590.23 5,948,573.68 370,517.06 0.00 10,859.10 15,242.34 83.01 157.68 7,501.05 7,445.50 -9,095.73 -7,590.04 5,948,573.22 370,517.24 3.18 10,859.48 Start 3.18°/100'DLS,44.75°TF,for 351.43' 15,300.00 84.53 156.64 7,507.30 7,451.75 -9,148.55 -7,567.79 5,948,520.05 370,538.63 3.18 10,903.94 15,400.00 87.16 154.83 7,514.56 7,459.01 -9,239.46 -7,526.81 5,948,428.50 370,578.13 3.18 10,979.71 15,500.00 89.79 153.04 7,517.23 7,461.68 -9,329.25 -7,482.89 5,948,338.02 370,620.59 3.18 11,053.57 15,591.71 92.20 151.39 7,515.64 7,460.09 -9,410.37 -7,440.15 5,948,256.23 370,662.00 3.18 11,119.44 15,593.78 92.20 151.39 7,515.56 7,460.01 -9,412.18 -7,439.16 5,948,254.40 370,662.96 0.00 11,120.91 Hold for 12.97' 15,600.00 92.20 151.39 7,515.32 7,459.77 -9,417.64 -7,436.18 5,948,248.89 370,665.85 0.00 11,125.31 15,606.75 92.20 151.39 7,515.06 7,459.51 -9,423.56 -7,432.95 5,948,242.92 370,668.98 0.00 11,130.09 Start 3.18°1100'DLS,97.16°TF,for 542.44' 15,608.17 92.20 151.39 7,515.00 7,459.45 -9,424.81 -7,432.27 5,948,241.66 370,669.64 0.00 11,131.10 15,700.00 91.83 154.30 7,511.77 7,456.22 -9,506.46 -7,390.39 5,948,159.35 370,710.19 3.18 11,197.72 15,800.00 91.43 157.46 7,508.92 7,453.37 -9,597.67 -7,349.55 5,948,067.49 370,749.55 3.18 11,273.82 15,900.00 91.02 160.62 7,506.78 7,451.23 -9,691.02 -7,313.78 5,947,973.59 370,783.80 3.18 11,353.39 16,000.00 90.61 163.77 7,505.35 7,449.80 -9,786.21 -7,283.21 5,947,877.92 370,812.82 3.18 11,436.18 16,100.00 90.20 166.93 7,504.64 7,449.09 -9,882.94 -7,257.93 5,947,780.80 370,836.53 3.18 11,521.94 16,148.69 90.00 168.47 7,504.55 7,449.00 -9,930.52 -7,247.56 5,947,733.07 370,846.13 3.18 11,564.70 CD4-96 Intl 042114 DK 16,149.19 90.00 168.47 7,504.55 7,449.00 -9,931.00 -7,247.46 5,947,732.58 370,846.22 1.00 11,565.14 Start 1°/100'DLS,114.88°TF,for 36.45' 16,185.64 89.85 168.81 7,504.60 7,449.05 -9,966.74 -7,240.28 5,947,696.73 370,852.82 1.00 11,597.43 Hold for 664.81' 16,185.80 89.85 168.81 7,504.60 7,449.05 -9,966.90 -7,240.25 5,947,696.57 370,852.85 1.00 11,597.57 16,200.00 89.85 168.81 7,504.64 7,449.09 -9,980.83 -7,237.49 5,947,682.61 370,855.38 0.00 11,610.16 16,300.00 89.85 168.81 7,504.91 7,449.36 -10,078.93 -7,218.08 5,947,584.21 370,873.19 0.00 11,698.88 16,400.00 89.85 168.81 7,505.17 7,449.62 -10,177.02 -7,198.67 5,947,485.82 370,891.01 0.00 11,787.60 16,500.00 89.85 168.81 7,505.44 7,449.89 -10,275.12 -7,179.26 5,947,387.43 370,908.83 0.00 11,876.31 16,600.00 89.85 168.81 7,505.71 7,450.16 -10,373.22 -7,159.85 5,947,289.04 370,926.65 0.00 11,965.03 16,700.00 89.85 168.81 7,505.98 7,450.43 -10,471.32 -7,140.44 5,947,190.65 370,944.46 0.00 12,053.74 16,800.00 89.85 168.81 7,506.24 7,450.69 -10,569.41 -7,121.03 5,947,092.26 370,962.28 0.00 12,142.46 16,849.60 89.85 168.81 7,506.38 7,450.83 -10,618.07 -7,111.40 5,947,043.46 370,971.12 0.00 12,186.46 4/21/2014 3:58:15PM Page 5 COMPASS 2003.16 Build 69 ORIGINAL • Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp214u t, I Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-WNorthing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 7,450.83 16,850.45 89.84 168.79 7,506.38 7,450.83 -10,618.90 -7,111.24 5,947,042.62 370,971.27 2.00 12,187.22 Start 2°/100'DLS,-98.33°TF,for 168.74' 16,900.00 89.70 167.81 7,506.58 7,451.03 -10,667.42 -7,101.19 5,946,993.95 370,980.53 2.00 12,230.97 17,000.00 89.41 165.83 7,507.35 7,451.80 -10,764.78 -7,078.39 5,946,896.24 371,001.75 2.00 12,318.03 17,018.70 89.36 165.46 7,507.55 7,452.00 -10,782.90 -7,073.76 5,946,878.06 371,006.09 2.00 12,334.12 CD4-96 Intl DK 10Jun13(copy)(copy) 17,019.19 89.36 165.47 7,507.56 7,452.01 -10,783.37 -7,073.63 5,946,877.58 371,006.20 2.00 12,334.54 Adjust TF to 88.88°,for 160.45' 17,100.00 89.39 167.09 7,508.44 7,452.89 -10,861.87 -7,054.47 5,946,798.79 371,024.09 2.00 12,404.51 17,179.64 89.42 168.68 7,509.26 7,453.71 -10,939.73 -7,037.75 5,946,720.67 371,039.55 2.00 12,474.55 Hold for 888.86' 17,179.72 89.42 168.68 7,509.26 7,453.71 -10,939.80 -7,037.74 5,946,720.60 371,039.56 2.00 12,474.62 17,200.00 89.42 168.68 7,509.47 7,453.92 -10,959.69 -7,033.75 5,946,700.65 371,043.22 0.00 12,492.59 17,300.00 89.42 168.68 7,510.48 7,454.93 -11,057.74 -7,014.13 5,946,602.31 371,061.25 0.00 12,581.20 17,400.00 89.42 168.68 7,511.49 7,455.94 -11,155.79 -6,994.50 5,946,503.96 371,079.29 0.00 12,669.81 17,500.00 89.42 168.68 7,512.50 7,456.95 -11,253.84 -6,974.88 5,946,405.61 371,097.32 0.00 12,758.42 17,600.00 89.42 168.68 7,513.50 7,457.95 -11,351.89 -6,955.25 5,946,307.27 371,115.35 0.00 12,847.03 17,700.00 89.42 168.68 7,514.51 7,458.96 -11,449.94 -6,935.62 5,946,208.92 371,133.39 0.00 12,935.64 17,800.00 89.42 168.68 7,515.52 7,459.97 -11,547.99 -6,916.00 5,946,110.57 371,151.42 0.00 13,024.25 17,900.00 89.42 168.68 7,516.53 7,460.98 -11,646.04 -6,896.37 5,946,012.23 371,169.46 0.00 13,112.86 18,000.00 89.42 168.68 7,517.54 7,461.99 -11,744.09 -6,876.74 5,945,913.88 371,187.49 0.00 13,201.47 18,067.48 89.42 168.68 7,518.22 7,462.67 -11,810.25 -6,863.50 5,945,847.52 371,199.66 0.00 13,261.26 18,068.50 89.42 168.66 7,518.23 7,462.68 -11,811.26 -6,863.30 5,945,846.51 371,199.85 2.00 13,262.17 Start 2°/100'DLS,-91.16°TF,for 741.6' 18,100.00 89.41 168.03 7,518.55 7,463.00 -11,842.10 -6,856.94 5,945,815.57 371,205.71 2.00 13,289.99 18,200.00 89.37 166.03 7,519.62 7,464.07 -11,939.54 -6,834.50 5,945,717.79 371,226.57 2.00 13,377.22 18,300.00 89.33 164.03 7,520.75 7,465.20 -12,036.14 -6,808.67 5,945,620.79 371,250.82 2.00 13,462.70 18,400.00 89.29 162.03 7,521.95 7,466.40 -12,131.77 -6,779.49 5,945,524.71 371,278.45 2.00 13,546.31 18,500.00 89.25 160.03 7,523.22 7,467.67 -12,226.33 -6,746.99 5,945,429.64 371,309.41 2.00 13,627.96 18,600.00 89.22 158.03 7,524.56 7,469.01 -12,319.69 -6,711.21 5,945,335.72 371,343.67 2.00 13,707.54 18,700.00 89.18 156.03 7,525.95 7,470.40 -12,411.75 -6,672.19 5,945,243.05 371,381.19 2.00 13,784.96 18,800.00 89.15 154.03 7,527.41 7,471.86 -12,502.39 -6,629.99 5,945,151.74 371,421.92 2.00 13,860.12 18,809.64 89.15 153.84 7,527.55 7,472.00 -12,511.05 -6,625.75 5,945,143.02 371,426.01 2.00 13,867.24 CD4-96 Int3 DK 10Jun13(copy)(copy) 18,810.10 89.15 153.84 7,527.56 7,472.01 -12,511.46 -6,625.55 5,945,142.60 371,426.21 0.00 13,867.58 Hold for 4223.66' 18,900.00 89.15 153.84 7,528.90 7,473.35 -12,592.15 -6,585.92 5,945,061.30 371,464.52 0.00 13,933.91 19,000.00 89.15 153.84 7,530.39 7,474.84 -12,681.89 -6,541.83 5,944,970.86 371,507.15 0.00 14,007.69 19,100.00 89.15 153.84 7,531.88 7,476.33 -12,771.64 -6,497.75 5,944,880.41 371,549.77 0.00 14,081.47 19,200.00 89.15 153.84 7,533.37 7,477.82 -12,861.38 -6,453.67 5,944,789.97 371,592.39 0.00 14,155.25 19,300.00 89.15 153.84 7,534.86 7,479.31 -12,951.13 -6,409.58 5,944,699.53 371,635.01 0.00 14,229.03 19,400.00 89.15 153.84 7,536.36 7,480.81 -13,040.88 -6,365.50 5,944,609.09 371,677.63 0.00 14,302.81 19,500.00 89.15 153.84 7,537.85 7,482.30 -13,130.63 -6,321.42 5,944,518.65 371,720.24 0.00 14,376.59 19,600.00 89.15 153.84 7,539.34 7,483.79 -13,220.37 -6,277.34 5,944,428.21 371,762.86 0.00 14,450.37 19,700.00 89.15 153.84 7,540.83 7,485.28 -13,310.12 -6,233.26 5,944,337.76 371,805.48 0.00 14,524.15 4/21/2014 3:58:15PM Page 6 COMPASS 2003.16 Build 69 ORIGINAL • Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 c 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65©55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 . . 3 t Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (0) (ft) ft (ft) (ft) ; ;, (ft) (ft) 7,486.77 19,800.00 89.15 153.84 7,542.32 7,486.77 -13,399.87 -6,189.18 5,944,247.32 371,848.10 0.00 14,597.93 19,900.00 89.15 153.84 7,543.81 7,488.26 -13,489.62 -6,145.10 5,944,156.88 371,890.72 0.00 14,671.72 20,000.00 89.15 153.84 7,545.31 7,489.76 -13,579.37 -6,101.02 5,944,066.44 371,933.33 0.00 14,745.50 20,100.00 89.15 153.84 7,546.80 7,491.25 -13,669.11 -6,056.94 5,943,975.99 371,975.95 0.00 14,819.28 20,200.00 89.15 153.84 7,548.29 7,492.74 -13,758.86 -6,012.86 5,943,885.55 372,018.56 0.00 14,893.07 20,300.00 89.15 153.84 7,549.78 7,494.23 -13,848.61 -5,968.78 5,943,795.11 372,061.18 0.00 14,966.85 20,400.00 89.15 153.84 7,551.27 7,495.72 -13,938.36 -5,924.70 5,943,704.66 372,103.79 0.00 15,040.63 20,500.00 89.15 153.84 7,552.76 7,497.21 -14,028.11 -5,880.63 5,943,614.22 372,146.41 0.00 15,114.42 20,600.00 89.15 153.84 7,554.25 7,498.70 -14,117.86 -5,836.55 5,943,523.77 372,189.02 0.00 15,188.20 20,700.00 89.15 153.84 7,555.75 7,500.20 -14,207.61 -5,792.47 5,943,433.33 372,231.64 0.00 15,261.99 20,800.00 89.15 153.84 7,557.24 7,501.69 -14,297.36 -5,748.40 5,943,342.88 372,274.25 0.00 15,335.77 20,900.00 89.15 153.84 7,558.73 7,503.18 -14,387.11 -5,704.32 5,943,252.44 372,316.86 0.00 15,409.56 21,000.00 89.15 153.85 7,560.22 7,504.67 -14,476.86 -5,660.25 5,943,161.99 372,359.48 0.00 15,483.34 21,100.00 89.15 153.85 7,561.71 7,506.16 -14,566.61 -5,616.17 5,943,071.55 372,402.09 0.00 15,557.13 21,200.00 89.15 153.85 7,563.20 7,507.65 -14,656.36 -5,572.10 5,942,981.10 372,444.70 0.00 15,630.91 21,300.00 89.15 153.85 7,564.70 7,509.15 -14,746.11 -5,528.02 5,942,890.66 372,487.31 0.00 15,704.70 21,400.00 89.15 153.85 7,566.19 7,510.64 -14,835.86 -5,483.95 5,942,800.21 372,529.92 0.00 15,778.49 21,500.00 89.15 153.85 7,567.68 7,512.13 -14,925.62 -5,439.88 5,942,709.77 372,572.53 0.00 15,852.28 21,600.00 89.15 153.85 7,569.17 7,513.62 -15,015.37 -5,395.80 5,942,619.32 372,615.14 0.00 15,926.06 21,700.00 89.15 153.85 7,570.66 7,515.11 -15,105.12 -5,351.73 5,942,528.87 372,657.75 0.00 15,999.85 21,800.00 89.15 153.85 7,572.15 7,516.60 -15,194.87 -5,307.66 5,942,438.43 372,700.36 0.00 16,073.64 21,900.00 89.15 153.85 7,573.65 7,518.10 -15,284.62 -5,263.59 5,942,347.98 372,742.97 0.00 16,147.43 22,000.00 89.15 153.85 7,575.14 7,519.59 -15,374.38 -5,219.52 5,942,257.53 372,785.57 0.00 16,221.22 22,100.00 89.15 153.85 7,576.63 7,521.08 -15,464.13 -5,175.45 5,942,167.09 372,828.18 0.00 16,295.01 22,200.00 89.15 153.85 7,578.12 7,522.57 -15,553.88 -5,131.38 5,942,076.64 372,870.79 0.00 16,368.80 22,300.00 89.15 153.85 7,579.61 7,524.06 -15,643.64 -5,087.31 5,941,986.19 372,913.40 0.00 16,442.59 22,400.00 89.15 153.85 7,581.10 7,525.55 -15,733.39 -5,043.24 5,941,895.74 372,956.00 0.00 16,516.38 22,500.00 89.15 153.85 7,582.59 7,527.04 -15,823.14 -4,999.17 5,941,805.29 372,998.61 0.00 16,590.17 22,600.00 89.15 153.85 7,584.09 7,528.54 -15,912.90 -4,955.10 5,941,714.85 373,041.21 0.00 16,663.96 22,700.00 89.15 153.85 7,585.58 7,530.03 -16,002.65 -4,911.03 5,941,624.40 373,083.82 0.00 16,737.75 22,800.00 89.15 153.85 7,587.07 7,531.52 -16,092.41 -4,866.96 5,941,533.95 373,126.42 0.00 16,811.54 22,900.00 89.15 153.85 7,588.56 7,533.01 -16,182.16 -4,822.90 5,941,443.50 373,169.03 0.00 16,885.33 23,000.00 89.15 153.85 7,590.05 7,534.50 -16,271.91 -4,778.83 5,941,353.05 373,211.63 0.00 16,959.12 23,033.33 89.15 153.85 7,590.55 7,535.00 -16,301.83 -4,764.14 5,941,322.90 373,225.83 0.00 16,983.72 CD4-96 Toe DK 29May13(copy)(copy) 4/21/2014 3:58:15PM Page 7 COMPASS 2003.16 Build 69 ORIGINAL Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (1 (0) (ft) (ft) (ft) (ft) (ft) CD4-96 Intl 042114 DK 0.00 7,504.55 -9,930.52 -7,247.56 5,947,733.07 370,846.13 -plan hits target center -Circle(radius 100.00) CD4-96 Heel DK 10Jun13(copy)(copy) 0.00 7,484.55 -8,991.53 -7,632.80 5,948,678.10 370,476.17 -plan hits target center -Circle(radius 100.00) CD4-96 Int3 DK 10Jun13(copy)(copy) 0.00 7,527.55 -12,511.05 -6,625.75 5,945,143.02 371,426.01 -plan hits target center -Circle(radius 100.00) CD4-96 Int2 DK 10Jun13(copy)(copy) 0.00 7,507.55 -10,782.90 -7,073.76 5,946,878.06 371,006.09 -plan hits target center -Circle(radius 100.00) CD4-96 Toe DK 29May13(copy)(copy) 0.00 7,590.55 -16,301.83 -4,764.14 5,941,322.90 373,225.83 -plan hits target center -Circle(radius 100.00) CD4-96 Intl DK 10Jun13(copy)(copy) 0.00 7,490.55 -9,930.52 -7,247.56 5,947,733.07 370,846.13 -plan misses target center by 14.00ft at 16148.69ft MD(7504.55 TVD,-9930.52 N,-7247.56 E) -Circle(radius 100.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,938.97 2,368.87 13-3/8"x 16" 13-3/8 16 12,950.01 6,793.00 9-5/8"x 12-1/4" 9-5/8 12-1/4 15,222.34 7,498.61 7"x 8-3/4"x 9-7/8" 7 9-7/8 23,033.76 7,590.56 4-1/2 x 6-1/8" 4-1/2 6-1/8 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (1 (') 14,099.88 7,217.55 Kup C 13,098.88 6,855.55 HRZ Top 0.00 13,677.49 7,080.55 HRZ Base 14,119.12 7,223.55 LCU 15,184.31 7,493.55 Alp C 13,866.75 7,144.55 K-1 4/21/2014 3:58:15PM Page 8 COMPASS 2003.16 Build 69 ORIGINAL • Standard Proposal Report Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well CD4-96 Company: ConocoPhillips(Alaska)Inc. TVD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Project: Western North Slope MD Reference: CD4-96:18.9+36.65 @ 55.55ft(Doyon 19) Site: CD4 Nanuq Pad North Reference: True Well: CD4-96 Survey Calculation Method: Minimum Curvature Wellbore: Plan:CD4-96A Design: CD4-96Awp21 ,. v Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 12,950.00 6,793.00 -7,063.87 -7,291.75 KOP:9°/100'DLS,-60°TF,for 19.6' 12,969.60 6,801.39 -7,076.29 -7,304.38 Hold for 20' 12,989.60 6,809.81 -7,089.20 -7,317.12 Start 3.65°/100'DLS,-85.85°TF,for 937.87' 13,927.47 7,163.78 -7,855.63 -7,692.68 Hold for 321.58' 14,249.05 7,264.07 -8,157.72 -7,738.39 Start 3.5°/100'DLS,-79.41°TF,for 879.93' 15,128.98 7,484.64 -8,991.98 -7,632.62 Start 3.48°/100'DLS,0.05°TF,for 93.37' 15,222.34 7,498.61 -9,077.37 -7,597.58 Hold for 20' 15,242.34 7,501.05 -9,095.73 -7,590.04 Start 3.18°/100'DLS,-34.75°TF,for 351.43' 15,593.78 7,515.56 -9,412.18 -7,439.16 Hold for 12.97' 15,606.75 7,515.06 -9,423.56 -7,432.95 Start 3.18°/100'DLS,97.16°TF,for 542.44' 16,149.19 7,504.55 -9,931.00 -7,247.46 Start 1°/100'DLS,114.88°TF,for 36.45' 16,185.64 7,504.60 -9,966.74 -7,240.28 Hold for 664.81' 16,850.45 7,506.38 -10,618.90 -7,111.24 Start 2°/100'DLS,-98.33°TF,for 168.74' 17,019.19 7,507.56 -10,783.37 -7,073.63 Adjust TF to 88.88°,for 160.45' 17,179.64 7,509.26 -10,939.73 -7,037.75 Hold for 888.86' 18,068.50 7,518.23 -11,811.26 -6,863.30 Start 2°/100'DLS,-91.16°TF,for 741.6' 18,810.10 7,527.56 -12,511.46 -6,625.55 Hold for 4223.66' 23,033.76 TD:23033.76'MD,7590.55'ND 4/21/2014 3:58:15PM Page 9 COMPASS 2003.16 Build 69 imp .) ' \ SAL ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD4 Nanuq Pad CD4-96 Plan: CD4-96A CD4-96Awp21 Clearance Summary Anticollision Report 21 April,2014 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:CD4 Nanuq Pad-CD4-96-Plan:CD4-96A-CD4-96Awp21 Well Coordinates:5,957,291.25 N,1,518,286.46 E(70°17'31.97"N,150°59'19.76"W) Datum Height: CD4-96:18.9+36.65 55.55ft(Doyon 19) Scan Range: 12,950.00 to 23,034.20 ft.Measured Depth. Scan Radius is 2,499.75 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 200'+100/1000 of reference Scan Type: 25.00 ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for CD4-96-CD4-96Awp21 Tray.Cylinder North Proximity Scan on Current Survey Data(North Reference) Reference Design:CD4 Nanuq Pad-CD4-98-Plan:CD4-96A-CD4-96Awp21 Scan Range: 12,950.00 to 23,034.20 ft.Measured Depth. Scan Radius is 2,499.75 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 CD4 Nanuq Pad CD4-24-CD4-24-CD4-24 13,263.55 781.36 13,263.55 607.63 14,575.00 4.498 Clearance Factor Pass-Major Risk CD4-24-CD4-24-CD4-24 13,198.95 770.57 13,198.95 615.67 14,700.00 4.974 Centre Distance Pass-Major Risk C04-24-CD4-24PB1-CD4-24PB1 13,181.88 883.69 13,181.88 696.54 14,479.00 4.722 Clearance Factor Pass-Major Risk CD4-24-CD4-24PB2-CD4-24PB2 13,432.55 1,234.65 13,432.55 967.02 13,814.00 4.613 Clearance Factor Pass-Major Risk CD4-25-CD4-25-CD4-25 14,828.37 207.38 14,828.37 61.08 14,725.00 1.417 Centre Distance Pass-Major Risk CD4-25-CD4-25-CD4-25 14,778.63 225.68 14,778.63 50.34 14,825.00 1.287 Clearance Factor Pass-Major Risk CD4-25-CD4-25L1-CD4-25L1 14,828.37 207.38 14,828.37 60.95 14,725.00 1.416 Centre Distance Pass-Major Risk CD4-25-CD4-25L1-CD4-25L1 14,778.63 225.68 14,778.63 50.20 14,825.00 1.286 Clearance Factor Pass-Major Risk CD4-25-CD4-25P81-CD4-25PB1 14,645.80 211.66 14,645.80 62.76 14,725.00 1.421 Centre Distance Pass-Major Risk CD4-25-CD4-25PB1-CD4-25PB1 14,593.84 233.30 14,593.84 42.64 14,850.00 1.224 Clearance Factor Pass-Major Risk CD4-27-CD4-27-CD4-27 17,338.61 1,551.66 17,338.61 1,299.81 14,725.00 6.161 Centre Distance Pass-Major Risk CD4-27-CD4-27-CD4-27 17,363.61 1,551.83 17,363.61 1,299.56 14,750.00 6.152 Clearance Factor Pass-Major Risk CD4-27-CD4-27PB1-CD4-27PB1 16,100.00 2,289.12 16,100.00 2,048.90 13,088.00 9.529 Clearance Factor Pass-Major Risk CD4-27-CD4-27PB2-CD4-27PB2 16,053.01 1,992.77 16,053.01 1,759.31 13,255.00 8.536 Clearance Factor Pass-Major Risk CD4-27-CD4-27PB3-CD4-27PB3 16,704.88 1,747.66 16,704.88 1,479.94 14,050.00 6.528 Clearance Factor Pass-Major Risk CD4-27-CD4-27P83-CD4-27PB3 17,057.86 1,738.82 17,057.86 1,500.25 14,325.00 7289 Centre Distance Pass-Major Risk CD4-96-CD4-96-CD4-96 _ - _ - CD4-96-CD4-96-CD4-96 - - - Plan:CD4-97-Plan:CD4-97-CD4-97wp08 12,950.00 2,168.31 12,950.00 1,813.88 13,100.00 6.118 Clearance Factor Pass-Major Risk Plan:CD4-97-Plan:CD4-97-CD4-97wp08 18,800.00 2,088.10 18,800.00 1,843.56 22,450.00 8.539 Centre Distance Pass-Major Risk 21 April,2014- 14:30 Page 2 of 5 COMPASS ORIGINAL ConocoPhillips(Alaska)Inc.-WNS Western North Slope Anticollision Report for CD4-96-CD4-96Awp21 Survey tool program From To Survey/Plan Survey Tool (n) (n) 75 17 1,045 95 GYD-GC-SS 1,13952 2,86969 MWD+IFR-AK-CAZ-SC 2,96546 3,0205E INC+TREND 3,114 84 12,950 00 MWD+IFR-AK-CAZSC 12,950 00 14,450 00 CD4-96Awp21 MWD 12,950 00 15,22234 CD4-96Awp21 MWD+IFR-AK-CAZSC 15,222 34 16,722 34 CD4-96Awp21 MWD 15,222 34 23,033 76 CD4-96Awp21 MWD+IFR-AK-CAZSC Ellipse error terms are correlated across survey tool be-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 21 Apn/2014- 14 30 Page 3 o/5 COMPASS fl [flGNAL ConocoPhilli ps C D 4-9 6 Aw p 21 Schlumberger Alaska W 0 1 0 60 - rn a2 30 N N U - 0 I I I I I I I I I I I 1 1 1 a l 1 1 1 l 13000 14000 15000 16000 17000 18000 19000 20000 Displayed interval could be less than entire rbred Depth 12950.00 To 23034.20 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 12950.00 To 23034.20 Results Limited By: Centre Distance:2499.75 GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 75.17 1045.95 CD4-96 Gyro(CD4-96) GYD-GC-SS 1139.52 2869.69 CD4-96 MWD I (CD4-96) MWD+IFR-AK-CAZ-SC 2965.46 3020.58 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND 3114.84 12950.00 CD4-96 MWD II(CD4-96) MWD+IFR-AK-CAZ-SC 12950.00 14450.00 CD4-96Awp21 (Plan:CD4-96A) MWD CASING DETAILS TVD MD Name Size 2368.87 2938.97 13-3/8" x 16" 13-3/8 6793.0012950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.34 7"x 8-3/4"x 9-7/8" 7 7590.55 23033.76 4-1/2 x 6-1/8" 4-1/2 LEGEND CD4-03,CD4-03,CD4-03 VO -X- CD4-213,Plan CD4-2138,CD4-213Bwp20 VO -0- CD4-298,CD4-298PB1,CD4-298PB1 VO - CD4-05,CD4-05,CD4-05 VO -e- CD4-23,CD4-23,CD4-23 VO -9- CD4-301,CD4-301,CD4-301 VO -A- CD4-07,CD4-07,CD4-07 VI -9- CD4-23,CD4-23P81,CD4-23PB1 VO -0- CD4-301,CD4-301A,CD4-301A VO - CD4-12,CD4-12,CD4-12 VO -0- CD4-23,CD4-23PB2,CD4-23PB2 VO -e- CD4-301,CD4-301B,CD4-3018 VO - CD4-12,CD4-12PB1,CD4-12PB1 VO -0- CD4-24,CD4-24,CD4-24 VO -e- CD4-302,CD4-302,CD4-302 V3 CD4-12,Nanuq 5,Nanuq 5 V1 -9- CD4-24,CD4-24PB1,CD4-24PB1 VO CD4-304,CD4-304,CD4-304 V6 -X- CD4-208,CD4-208,CD4-208 V7 -e- CD4-24,CD4-24PB2,CD4-24PB2 VO CD4-304,CD4-304PB1,CD4-304PB1 V16 - CD4-208,CD4-208A,CD4-208A VO -X- CD4-25,CD4-25,CD4-25 VO -X- CD4-306,CD4-306,CD4-306 V1 - CD4-208,CD4-208APB1,CD4-208APB1 VO CD4-25,CD4-25L1,CD4-25L1 VO -X- CD4-319,CD4-319,CD4-319 V5 - CD4-208,CD4-208PB1,CD4-208PB1 V6 -- CD4-25,CD4-25PB1,CD4-25PB1 VO C04-96,CD4-96,CD4-96 VO CD4-209,CD4-209,CD4-209 V4 CD4-27,CD4-27,CD4-27 VO -e-- Plan:CD4-286,Plan:CD4-286,CD4-286wp01 VO CD4-210,CD4-210,CD4-210 V3 CD4-27,CD4-27PB1,CD4-27PB1 VO Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO -X- CD4-210,CD4-210A,CD4-210A VO CD4-27,CD4-27PB2,CD4-27PB2 VO - - Plan:CD4-288,Plan:CD4-288,CD4-288wp01 VO - CD4-210,CD4-210APB1,CD4-210APB1 VO -9- CD4-27,CD4-27PB3,CD4-27PB3 VO -'9- Plan:CD4-289,Plan:CD4-289,CD4-289wp02 VO - CD4-211,C04-211,CD4-211 V2 CD4-290,CD4-290,CD4-290 VO -g- Plan:CD4-295,Plan:CD4-295,CD4-295wp02 VO - CD4-213,CD4-213,CD4-213 V4 --X-- C04-291,CD4-291,CD4-291 VO - Plan:CD4-93,Plan:CD4-93,CD4-93wp02b VO _e- CD4-213,CD4-213A,CD4-213A VO CD4-291,CD4-291 P81,CD4-291 PB1 VO -8- Plan:CD4-97,Plan:CD4-97,CD4-97wp08 VO -9- CD4-213,CD4-2138PB1,CD4-213BPBI VO -4- CD4-292,CD4-292,CD4-292 VO $ Nanuk 2,Nanuk 2,Nanuk 2 V1 - CD4-213,CD4-2138PB2,CD4-2138P82 VO 0-R4-198G4-18tCq-29A/0 j -9- C04-96Awp21 ConocoPhillips CD4-96Awp21 Schlumberger Alaska a LO o e U U 300 • - CD l l (/) - 150 p VIII E - CD r 1°111" 1'. �� 1 I 11111111 00 0 I I 1 1 I I I I I 1 I I I I I I 1111 I I 1 1 I 1 13000 14000 15000 16000 17000 18000 19000 20000 Displayed Interval could be less than entire raIRIVAbred Depth 12950.00 To 23034.20 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 12950.00 To 23034.20 Results Limited By: Centre Distance:2499.75 GLOBAL FILTER APPLIED:All wellpaths within 200'+ 100/1000 of reference SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 75.17 1045.95 CD4-96 Gyro(CD4-96) GYD-GC-SS 1139.52 2869.69 CD4-96 MWD I (CD4-96) MWD+IFR-AK-CAZ-SC 2965.46 3020.58 CD4-96 MWD II INC+TREND(CD4-96) INC+TREND 3114.84 12950.00 CD4-96 MWD II (CD4-96) MWD+IFR-AK-CAZ-SC 12950.00 14450.00 CD4-96Awp21 (Plan: CD4-96A) MWD CASING DETAILS TVD MD Name Size 2368.87 2938.97 13-3/8" x 16" 13-3/8 6793.0012950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.34 7"x 8-3/4"x 9-7/8" 7 7590.55 23033.76 4-1/2 x 6-1/8" 4-1/2 LEGEND - CD4-03,CD4-03,CD4-03 VO -X- CD4-213,Plan CD4-2138,CD4-213Bwp25 VO -0- CD4-298,CD4-298PB1,CD4-298PB1 VO -9- CD4-05,CD4-05,CD4-05 VO -- CD4-23,CD4-23,CD4-23 VO -8- CD4-301,CD4-301,CD4-301 VO - CD4-07,CD4-07,CD4-07 VI $ CD4-23,CD4-23PB1,CD4-23PB1 VO -0- CD4-301,CD4-301A,CD4-301A VO CD4-12,CD4-12,CD4-12 VO -0- CD4-23,CD4-23PB2,CD4-23PB2 VO -Q- CD4-301,CD4-3018,CD4-301B VO - CD4-12,CD4-12PB1,CD4-12PB1 VO -0- CD4-24,CD4-24,CD4-24 VO -e- CD4-302,CD4-302,CD4-302 V3 CD4-12,Nanuq 5,Nanuq 5 V1 $ CD4-24,CD4-24PB1,CD4-24PB1 VO -A- CD4-304,CD4-304,CD4-304 V6 X CD4-206,CD4-208,CD4-208 V7 _e_ CD4-24,CD4-24PB2,CD4-24PB2 VO CD4-304,CD4-304PB1,CD4-304PB1 V16 --8- CD4-208,CD4-208A,CD4-208A VO -X- CD4-25,CD4-25,CD4-25 VO -X- CD4-306,CD4-306,CD4-306 V1 -A- CD4-208,CD4-208APB1,CD4-208APB1 VO -0- CD4-25,CD4-25L1,CD4-25L1 VO -X-- CD4-319,CD4-319,CD4-319 V5 - CD4-208,CD4-208PB1,CD4-208PB1 V6 -A- CD4-25,CD4-25PB1,CD4-25PB1 VO -4-- CD4-96,CD4-96,CD4-96 VO CD4-209,CD4-209,CD4-209 V4 CD4-27,0D4-27,CD4-27 VO -e- Plan:CD4-286,Plan:CD4-286,CD4-286wp01 VO CD4-210,CD4-210,CD4-210 V3 -e- CD4-27,CD4-27PB1,CD4-27PB1 VO Plan:CD4-287,Plan:CD4-287,CD4-287wp02 VO ->E CD4-210,CD4-210A,CD4-210A VO CD4-27,CD4-27PB2,CD4-27PB2 VO - Plan:C04-288,Plan:CD4-288,CD4-288wp01 VO -A- CD4-210,CD4-210APB1,CD4-210APB1 VO -B- CD4-27,CD4-27PB3,CD4-27PB3 VO -0- Plan:C04-289,Plan:CD4-289,CD4-289wp02 VO - CD4-211,CD4-211,CD4-211 V2 -A- CD4-290,CD4-290,CD4-290 VO -9- Plan:CD4-295,Plan:CD4-295,CD4-295wp02 VO CD4-213,CD4-213,CD4-213 V4 --X- CD4-291,CD4-291,CD4-291 VO -X- Plan:CD4-93,Plan:CD4-93,CD4-93wp02b VO - CD4-213,CD4-213A,CD4-213A VO -0- CD4-291,CD4-291P81,C04-291P131 VO $ Plan:CD4-97,Plan:CD4-97,CD4-97wp08 VO -8- CD4-213,CD4-213BPB1,CD4-213BP81 VO CD4-292,CD4-292,CD4-292 VO -e_ Nanuk 2,Nanuk 2,Nanuk 2 V1 !? CD4-213,CD4-213BPB2,CD4-213BPB2 VO $ C�4-29gCDy-2$8,r,D4-�86 V -B- CD4-96Awp21 Sec ) Inc Azi TVD +N/-S +E/-W DLeg TFace : Target 1 ) 64.20 226.32 6793.00 -7063.87 -7291.75 0.00 0.00 s 0 12950 C D 4-9 6 Aw p 21 2 . JO 65.09 224.63 6801.39 -7076.29 -7304.38 9.00 -60.00 ,1 3 12989.60 65.09 224.63 6809.81 -7089.20 -7317.12 0.00 0.00 8856.58 12950 13100 12950.00 To 23034.20 4 13927,47 71.86 188.45 7163.87 -7855.60 -7692.63 3.65 -85.85 9697.53 5 14249.05 71.86 188.45 7263.97 -8157.89 -7737.53 0.00 0.00 10000.27 1.3100 13300 6 15128.98 79.75 157.69 7484.56 -8992.17 -7632.02 3.50 -79.41 10771.50 CD4-96 Heel DK 10Jun13 7 15222.34 83.00 157.69 7498.55 -9077.56 -7596.98 3.48 0.05 10843.64 Ifialko8 15242.34 83.00 157.69 7500.99 -9095.92 -7589,44 0.00 0.00 10859,15 13300 13500 rll 21 2014 9 15593.78 92.22 151.33 7515.64 -9412.35 -7438.53 3.18 -34.75 11120.56 10 15606.75 92.22 151.33 7515.14 -9423.72 -7432.31 0.00 0.00 11129.74 13500 13700 1, 16149.19 90.00 168.47 7504.55 -9931.11 -7246.68 3.18 97.16 11564.72 CD4-96 Intl 042114 DK .0BAL FILTER APPLIED: A 13 16185.64 89.85 168.80 7504.60 -9966.85 -7239.50 1.00 „0.00 „56.7, 13700 13900 13 168850.45 89.85 168.80 7506.38 -10619.00 -7110.37 0.00 0.00 12186.79 14 17019.19 89.36 165.46 7507.55 -10783.47 -7072.80 2.00 -98.33 12334.12 CD4-96 Intl DK 10Jun13 13900 14100 15 17179.64 89.42 168.67 7509.26 -10939.82 -7036.89 2.00 88.88 12474.14 Dam Worn Deem To Survey/Man Tool 16 18068.50 89.42 168.67 7518.23 -11811.32 -6862.26 0.00 0.00 13261.70 75.17 1046.95 CD,.GMo(C104-96) GTO-GC-5S1 41 00 14300 59.52 2669.69 CD4-96 WO1(C04-96) MWD.IFR-AKL/SSC ,7 18810.10 89.15 153.84 7527.55 -12511.56 -6624.63 2.00 -91.16 13867.21 CD4-96 Int3 DK 10Jun13 65.46 3020.56 000-96 MWD n i74C47'04740(004-96) '00.7047.0 18 23033.76 89.15 153.84 7590.55 -16302.13 -4762.64 0.00 0,00 16983.59 CD4-96 Toe DK 29May13 14.56 1205000 004-00 MWDCD4-06) MWD.IFR-AK.CADDC 14300 14700 1 50.00 0050.00 CD0-96A00047w021 1(Plan:CD4-060) MWD 1' 50.00 15222 74 COOA641w021(01an:CD4.40 MWD.IFA-A 5-CADDC 1 122.34 1672200 CD0-90Awp21(Plan:040-9610 MWD 14700 15000 1 rig v Tama T6 fru-o6ern t I."•WM wel wm IFA e4c,f4aSC CASING DETAILS 15000 15400 TVD MD Name Size 2368.87 2938.97 133/8"x 16" 13-3/8 15400 - 15800 6793.00 12950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.347"x 83/4"x 9-7/8" 7 15800 16100 7000.7,6 20003.7C ''/2 x 6 1/8" '1/2 16100 16500 16500 -----w 16800 0/360 16800 17200 17200 17900 -30/330 210 30 17900 18700 18700 19400 19400 20100 180 20100 20800 165 20800 21600 C D49C� 150 21600 22300 22300 23034 -60/300 60 rilill1111111 10 90 k r'N .------- • 10011 60 Alript.. -„,, ((((....!.0: -.4.,,, 411 A\go, 111 ll�\i►i�� o��\� \\ :,.,•:.,,,,z,-, .j"f469-41 4s, 1 ~ ■ � LKV. kli,.:• � '190/270 inaimi90 a,v,"„z110,._...avukik, viiig 1'irookt,s11,Ritateizzoozo.:1-...., illPdrioop�w�1�e���\mow 4 01 , g illtolysisirdkva---,,,wmenapt.,,,1_,.., � II)011$11,,v ‘` 9G _ =_V�w; 120/240/ �� �/1? ' 14, IIIII ' •1 120 Y D4-25PB1---- Aok,, , 4/1 , I i 0 f , .5 ..... ___, ...„4„,„, .... D4251-1I 'N-• 1 • �D42� 150/210 �At> 1!. 0 150 - 7 -180/180 .4- 0000.23403,02400 40 4- 004 $ 234 g C.D. $ 004301.034-4010.200301Av0 -8- w 234207150140 004-05.[0405,00441.520 i- 00000.200.10,200011003 -9- 004 -6- 004 -49- CM -0- 44 002-ae02v0 -o- 000 -X- 034C.D. 2 a $ Co. -0- 0W $ Ra CD4-2450P02 vo -& CD4 -& C04-210,04.210.4,01,00021.0.VO $ 044 -& CD. -& 000 94- 07.7 00403000000 CM 40 $ Cw $ CW 94 Co. -� C.A. tN6 $ Plan 0417050aw --8- C04-10.x-g5.Nano,55V1�t -I- $ 033-24.92 VO $ 100 -►f- 9 0.n.2 V1 44- 004290.004-205 C00448VTQ C04.3.4104.21...CD4010000 -X- CD 4- 01. 94 00 $ CD4966wa2 4 CDC 2040042020,004200*20 $ C tw a C3 } CD -tr C $ C -& CO 144 01102.004-01.401.004.2420511 '8' Mao 004104.Maw CIM-146.000032.401 VO $ 004Se,004206v61.004404PID V6 94- 004410,Plan 004410*,0D420042000 -& $ 401,004-01P00140160 Pe -}- Ran.004.7,Plan:C0.4-207.004297500200 coax, 14:36,April 21 2014 Easting(4000 Win) , 1 1 , 111 , , I , , I I 1 1 1 , , J , I , , 1 1 I 1 1 1 1 1 I 1 1 1 1 1 1 I I I 1 1 1 1 I I 1 1 , I 1 1 1 1 1 1 1 I 1 1 1 1 I I I _ AC wells ONLY - (NOT a Spider) _ CD4-304 _ CD4-208 CD4-301B CD4-I CD4-208PB1 - CD4-3P,CD4-:10 CD4-304PB - D4-3 ••�D4 Nanuq Pad CD4-301A _ _ volprit....... �I \� Z �✓ ��1� CD4-3c -ii 9 c _ , CD4-298 _ Z - (/ / CD- 2 :1\..4, - CD4- 0 ,4- Q',,4; 'OGD4-287wp02 CD4-2 �:J CD4-292 r. D440, :2 . ,-•a 4 D -�s�. -MD4-209 CD4-286wp01 CD, 93 .02b Nanuq 5 _ ',' 14-23 _ .. , j?PB1 _ ., - CD4-27P%3 - CD4-27 - CD4-97 E.08 CD4-295wp02 — CD4-21.IAPB1 D4-208A CD4-03' - CD4-96Awp21 CD4-210A _ Easting(4000 Win) ORIGINAL Sec .3 Inc Azi TVD 4N/-S +E/-W DLeg TFace : Target 1 0 64.20 226.32 6793.00 -7063.87 -7291.75 0.00 0.00 i 0 12950 CD4-96Awp21 2 65.09 224.63 6801.39 -7076.29 -7304.38 9.00 -60.00 I 3 129a9.60 65.09 224.63 6809.81 -7089.20 -7317.12 0.00 0.00 8030.58 12950 13100 12950.00 To 14200.00 4 13927.47 71.86 188.45 7163.87 -7855.60 -7692.63 3.65 -85.85 9697.53 5 14249.05 71.86 188.45 7263.97 -8157.89 -7737.53 0.00 0.00 10000.27 13100 13300 6 15128.98 79.75 157.69 7484.55 -8992.17 -7632.02 3.50 -79.41 10771.50 CD4-96 Heel DK 10Jun13 7 15222.34 83.00 157.69 7498.55 -9077.56 -7596.98 3.48 0.05 10843.64 8 15242.34 83.00 157.69 7500.99 -9095.92 -7589.44 0.00 0.00 10859.15 13300 13500 14:37,April 21 2014 9 15593.78 92.22 151.33 7515.64 -9412.35 -7438.53 3.18 -34.75 11120.56 10 15606.75 92.22 151.33 7515.14 -9423.72 -7432.31 0.00 0.00 11129.74 13500 13700 11 16149.19 90.00 168.47 7504.55 -9931.11 -7246.68 3.18 97.16 11564.72 CD4-96 Intl 042114 DK C LOBAL FILTER APPLIED: A 12 16185.64 89.85 166.60 7504.60 -9966.85 -7239.50 1.00 „4.66 „597.0, 13700 13900 13 16850.45 89.85 168.80 7506.38 -10619.00 -7110.37 0.00 0.00 12186.79 14 17019.19 89.36 165.46 7507.55 -10783.47 -7072.80 2.00 -98.33 12334.12 CD4-96 Intl DK 10Jun13 13900 14100 15 17179.64 89.42 168.67 7509.26 -10939.82 -7036.89 2.00 88.88 12474.14 08p1 From Depth TO Su7vey7P1an Ton! 16 18068.50 89.42 168.67 7518.23 -11811.32 -6862.26 0.00 0.00 13261.70 _ ___ 75.17 1045.95 CD0.96Gyro(CD1-99) O-V0 S 14100 -- - 14300 09.52 2869.69 C04-96 MW01(C131-96) Mwo.an,acnasc 17 18810.10 89.15 153.84 7527.55 -12511.56 -6624.63 200 -91.16 1386721 CD4961nn DK 10Jun13 65.46 3020.56 c00.96 MVO 11 I61C.TRPND(00496) 1740.106740 18 23033.76 89.15 153.84 7590.55 -16302.13 -4762.64 0.00 0.00 16983.59 CD4-96 Toe DK 29May13 14.94 12950.00 000.967430011(004-96) MW12.1Fe-29La3.3C 14300 14700 1' 50.00 14450.00 C124-99/11w021(Plan:C04-960.) 21240212400 1' 50.00 1522234 CW964wp21(Plan:0049001 MW12.1219-42•CADSC 1 122.14 1672134 C04962wp21(Plan:004968 MWD 14700 15000 1 1,7216 7128176 (11,16.4”.01 !N•Me. Mwn.41.AKs6nSC CASING DETAILS 15000 15400 TVD MD Name Size 2368.87 2938.97 13-3/8"x 16" 13-3/8 15400 15800 6793.00 12950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.347"x 8-3/4"x 9-7/8" 7 15800 16100 7500.65 20000.76 '112.,6 163" 41/2 16100 16500 16500 16800 0/360 16800 17200 225 17200 17900 -30/330 210 30 17900 18700 18700 19400 195 _ 19400 20100 180 20100 20800 165 20800 21600 150 21600 22300 13 22300 23034 -60/300 12i • 60 10 90 75 ii\ \ 60 '�: f. 4 �t iik -90/270 I . i 1 I 1 I I 11 90 3� 4 6 75 90 / • . ,,,, 11 _ 120/240 \ 120 50 .400000. 165 180 195 -150/210 210 150 225 -180/180 $ -s $ a $ 04.506.501 00 $ 3 $ -; a $ 04.50640240 $ 011�.0a�VI $ 244 $ 2.0wi580w $ $ 02.50640243 $ 044.12,004.12,000-7200 $ 70100 $ 44 44 9€ 409,502300 $ 04 00 $$ c $ 04 44 3 $ c 1916 $ P 7404800 $ 004.12, } c -9- 04 200 $ c 140 -44 c $ p .Ninth vI -- 04 9 94 $ 31;88.044-0.004-701205 $ 004860.421 $ c $ e $ $ c ;- c 0098.Co4ee v4 $ 044006.000-a2AP6+1.1000.z2A001 w $ c CO.-2136M w $ 4 CD4-2.1.0,4.26L1 co4. 1 v $ AL P!. 2u vm vo 004236.002206001.004008061ve 300210Plan 3002136004218a,20v0 $ 4.201W -roo n.n.c04507.PIM C04-267.014507.02 v0 3 Inc Azi TVD +N/-S +E/-W DLeg TFace : Target 1 D 64.20 226.32 6793.00 -7063.87 -7291.75 0.00 0.00 i 0 12950 CD4-96Awp21 2 ..0 65.09 224.63 6801.39 -7076.29 -7304.38 9.00 -60.00 I 3 12989.60 65.09 224.63 6809.81 -7089.20 -7317.12 0.00 0.00 8866.58 12950 13100 14200.00 To 15200.00 4 13927.47 71.86 188.45 7163.87 -7855.60 -7692.63 3.65 -85.85 9697.53 13100 13300 5 14249.05 71.86 188.45 7263.97 -8157.89 -7737.53 0.00 0,00 10000.27 6 15128.98 79.75 157.69 7484.55 -8992.17 -7632.02 3.50 -79.41 10771.50 CD4-96 Heel DK 10Jun13 7 15222.34 83.00 157.69 7498.55 -9077.56 -7596.98 3.48 0.05 10843.64 8 15242.34 83.00 157.69 7500.99 -9095.92 -7589.44 0.00 0.00 10859.15 13300 13500 14:38.A iil 21 2014 I 9 15593.78 92.22 151.33 7515.64 -9412.35 -7438.53 3.18 -34.75 11120.56 10 15606.75 92.22 151.33 7515.14 -9423.72 -7432.31 0.00 0.00 11129.74 13500 13700 11 16149.19 90.00 168.47 7504.55 -9931.11 -7246.68 3.18 97.16 11564.72 CD4-96 Intl 042114 DK 12 16185.64 89.85 168.80 7504.60 -9966.85 -7239.50 1.00 114.88 11597.01 13700 13900 LOBAL FILTER APPLIED: A ,3 16850.45 89.85 168.80 7506.38 -10619.00 -7110.37 0.00 0.00 12166.79 14 17019.19 89.36 165.46 7507.55 -10783.47 -7072.80 2.00 -98.33 12334.12 CD4-96 In DK 10Jun13 13900 14100 15 17179.64 89.42 168.67 7509.26 -10939.82 -7036.89 2.00 88.88 12474.14 Dop From Dept.To 0ur0e9040n Tool 16 18068.50 89.42 168.67 7518.23 -11811.32 -686226 0.00 0.00 13261.70 75.17 1045.95 C04-96 Gyro(C04-96) GVD-GC-SS 14100 14300 39.52 2669.69 C04-96 MWD 1(C04-96) MW041616-AK-CA5-SC 17 18810.10 89.15 153.84 7527.55 -12511.56 -6624.63 2.00 -91.16 13867.21 CD4-96 Int3 DK 10Jun13 65.46 3020.56 C04-96 MWD II OSC,79E6113(034-96) INCoTRENO 18 23033.76 89.15 153.84 7590.55 -16302.13 -4762.64 0.00 0.00 16983.59 C04-96 Toe DK 29May13 14300 14700 14.64 12950.00 004-96 MWO If(CDDn-AKL 4-96) MW•IFA2 SC 1 50.00 14450.00 C134-965w621(pan(C04-96A) MWD 1'50.00 1522294 C134A6Awp21(Pan'C04-96A) MWO4I551-A14-CA2 SC 1 D2.34 1672294 C04-96A,21(Maw 004.965) MWD J 14700 15000 1 n2 v 01m176 rn4Aw 46 1 me 465 MWn.lm-Ax.r42 SC CASING DETAILS 15000 15400 TVD MD Name Size 2368.87 2938.97 13-3/8"x 16" 13-3/8 15400 15800 6793.00 12950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.347'x 83/4"x 9-7/8" 7 15800 16100 7500.;0 20033.76 '1/¢,.61/8" '1/2 16100 16500 16500 16800 0/360 16800 17200 225 17200 17900 -30/330 210 30 17900 18700 18700 19400 / / 195 \ \\\., 19400 20100 �' 180 ��A 20100 20800 �j/��, 165 20800 21600 j150 _ 21600 22300 135 -- 22300 23034 60/300 i j. 12 60 10 i 90 k . oi.„--;----,, 75 w���\111\`Qol\\1� s ��� . �•� gam\. -90/270 �n��\�� \\ �`=�=` 90 .,..iiiikik mop ypynAiritlet:-1,1*----..--11tanniklibit--.....„.. 2' 10170 Millaw,g‘awitik---:-&-t-,,,,viraz-mi,i;ks--4.---- -„._ 4*Ifilltiyollgigatstvivirgima ....,..ez.„.„iit:_..., � -L-�- / ' 'I _, , „.„„---vv..,;,........„,.., .......:, / / / 11)11$0, ,� I' p /�� 1,; 1% I ' -:' 120/240 _. '1 120 4 P N : "IA1P, D4-25PBi-- - ..' Nj ----)- ___- 5 - 11011°0 V t. r Ilfr �D4-2� I\ -.5 /;` 95_ - -150/210 - �`1.- - 210 - - 150 -180/180 -A- p0 + p0 app -9- 004.27.004.27007. X00. + a $ 00 + 50 $ 00 '4- DD � p0. Nary -a- 00 -x- 044.4770,04010,C'04.2,w94 �- 00 2,. $ � CO. re1B2020 04 -9- 0120.CD4.205,Raw CP-205.004-205.02 00 -A- 00 -o- 004.219.pwa,04401.004.414454190 OO.r:04.1.00042400`° -o- ro C0 94 D -9- GO 20 $ 004.2,,.0049,,.504.27 W .a. 00 9( + pp. ,9,0 $ 50490 + + a 290 190 -x- C0442.�- °000.90201 a 0.",.20, C0.2130 VO -X $ 00 9921 ,.2 a $ 00 � -)} 4} 0044,C04,2130./.152,04-21300112'W -d- 004-25,..14-25.01.L04-25591004.22,90 vo -0- 004 W4i:44 co..CD ,W 9 can-C M"a4n=WM.C04.216.p°,9° 0042 "46,94 -K- 0042,644"GP.216004213.020 V0 -6- pp.- 1 % pp c' c°"°'0 CD0.2.7. Inc Azi TVD +N/-S .E/-W DLeg TFace : Target 1 1 64.20 226.32 6793.00 -7063.87 -7291.75 0.00 0.00 i 0 12950 CD4-96Awp21 2 2 65.09 224.63 6801.39 -7076.29 -7304.38 9.00 -60.00 I 3 12889.60 65.09 224.63 6809.81 -7089.20 -7317.12 0.00 0.00 88D0.58 12950 13100 15200.00 To 23034.20 4 13927.47 71.86 188.45 7163.87 -7855.60 -7692.63 3.65 -85.85 9697.53 5 14249.05 71.86 188.45 7263.97 -8157.89 -7737.53 0.00 0.00 10000.27 13100 13300 6 15128.98 79.75 157.69 7484.55 -8992.17 -7632.02 3.50 -79.41 10771.50 CD4-96 Heel DK 10Jun13 7 15222.34 83.00 157.69 7498.55 -9077.56 -7596.98 3.48 0.05 1083.64 8 15242.34 83.00 157.69 7500.99 -9095.92 -7589.44 0.00 0.00 10859.15 133009 15593.78 92.22 151.33 7515. -9412.35 -7438.53 3.18 13500 14:38,April 21 2014 11120.56 10 15606.75 92.22 151.33 7515.14 -9423.72 -7432.31 0.00 34,75 0.00 11129.74 13500 13700 1116149.19 90.00 168.47 7504.55 -9931.11 -7246.68 3.18 97.16 11564.72 CD4-96 Intl 042114 DK C LOBAL FILTER APPLIED: A 12 16185.64 89.85 168.80 7504.60 -9966.85 -7239.50 1.00 114.88 11597.01 13700 -- 13900 13 16850.45 89.85 168.80 7506.38 -10619.00 -7110.37 0.00 0.00 12186.79 14 17019.19 89.36 165.46 7507.55 -10783.47 -7072.80 2.00 -98.33 12334.12 CD4-96 Int2 DK 10Jun13 13900 14100 15 17179.64 89.42 168.67 7509.26 -10939.82 -7036.89 2.00 88.88 12474.14 030 From 03014.10 S0 023707 1007 16 18068.50 89.42 168.67 7518.23 -11811.32 -6862.26 0.00 0.00 13261.70 75.12 045.95 CD4-96GN0(CD4-96) GVITGCSS 14100 -_- 14300 39.52 2869.69 CD4-96 MWD I(CD4-96) MWDd621-A14{ODBC 17 18810.10 89.15 153.84 7527.55 -12511.56 -6624.63 2.00 -91.16 13867.21 CD4-96 Int3 DK 10Jun13 65.46 3020.50 CD4-96 MWD II INC.INEND(C00.96) INC4TAEND 18 23033.76 89.15 153.84 7590.55 -16302.13 -4762.64 0.00 0.00 16983.59 CD4-96 Toe DK 29May13 14,94 12950.00 CD4-96 MWC II(004-96) MW04I611-06LA2 SC 14300 14700 1 50.00 1445000 CD4-96Awp21(Plan:C120.96A) MWD 1 50.00 15222.34 C124-96.4,21(Plan:C0496A) MWD.IFN-Ax-CO2 SC (3'.34 12'72234 CD4-96AW021(Plan:CD4-01 Man.Me 0A) MWO ICA-e9-t'p=Sc 14700 15000 o7 v ma 76 `"°°CASING DETAILS " 15000 15400 TVD MD Name Size 2368.87 2938.97 13-3/8"x 16" 13-3/8 15400 - - 15800 6793.00 12950.01 9-5/8"x 12-1/4" 9-5/8 7498.55 15222.34T x 8-3/4"x 9-7/8" 7 1 5800 16100 7C00.CJ 2^0'\7.7C 4 1/2,.C l'0" 4 1/2 16100 16500 16500 ' 16800 0/360 16800 17200 450 17200 17900 -30/330 420 30 17900 18700 18700 19400 390 19400 20100 360 20100 20800 330 20800 21600 300 21600 22300 270 22300 23034 60/300r 60 • 4 t' -90/270 � ‘11tW. 90 -120/240 l 120 300 330 -150/210 420 150 450 -180/180 $ C04-03,C04-03,CD403 00 3- .209.004-209w 9 9 4 + Plan.C08.288.Plan' $ CW O5.C040500 i- 10,004.21000 $ } -� 4.- " N.W4-22.4524 VI -6- DD -X- 00 D.2104V0 � 2w - 00 9 0104,02.004402.ON.=03 -6- CO. C04-12 0 $ CD4 42121,004210400100 -9 CO. CW -6- 00. -$ F"an 00 32203240 $ 008-12.008-121081.002 279700 $ CD4.r;.0aR11..CD.211 02 $ CD. 94. co... -r CD 21 044"42119,5 $ FM. 004.v.0800 } 002- Nw05.WO.5 V1 9 C04.213.108413.CD4.213 04 $ Cw 00 $ CD. 1,0 C04-302.004-308.004004 01° 9 N.... 2.80.2 01 c0 9 00 042132,017.213400 4E C 43,00..25.00.a w� P.M.CD�4202,Coo O'00iP9 C0 $ oo.oe4_°o, 9 cD. i c04 $ coca.CD4.25u.C0.25u V0 9 wane.co..e.co...w -a. Cu.08,0416.004-.600 -o- 102'00 -o- mi-- 1 W a 004-2811,01 00 C04-208.CD8-208081.CO424°F81vs CO4219.Ran CD42138.00.2,m.,1a490 -6 C .30 95 ÷ Sv"C0 287.Fan00 2,7.004- 7.210295 �PoI � D-,2P8 f • 16:27,April 21 2014 C D 4-9 6 Aw p 21Name WELLBORE TARGET DETAILS(MAP CPORDINATES) TVDSS •W-S aE/-W Northing Easang ShapeNo oestne target data isavailab Quarter Mile View q�, 6 A Oe'2 Oa`�' Q,2)2 -"411..100‘ iri ti GLOM ,,,', , \CDA.30 000-0 1 Op 2g 'D'e'er • 2g2 Ly�O, GOAQotry , g, OA 7500 yQM / `' z vAs� Gv"2o `CD4-g• �A5 5 Nsn MZ, m IF 4 'El0000 c��'#46.. 1 a � • O • GOA -1143 It25005000— _ ow 00 oAA6.�P'a ;PC'Z,oP O -17500 -20000 -15000 -12500 -10000 -7500 -5000 -2500 0 2500 5000 West(-)/East(+) (2500 ft/in) ORIGINAL • 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 1 I I I I I I 1 I I I 1 I I I I I I I I I I I I I I I I I I I f l l l l l l l l ( I I I I I I I I i I I I i I I I I I I I t I I I I \ 6D4-25l I I I `.I I I I I l I I I 180 CP4-24 till 9l0' i III I I I I I I I I I I i i I I I I 1560 I I I I i I I I I I I I i I I I CD4 27 I I ti I i I I I t I I I I I ',\ I I I I I i I I i I I I I 1 (C Joest wel in poo ) i I I I I I I I i I i I I I I ti ! 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TRANSMITTAL LETTER CHECKLIST WELL NAME: ( 4✓/i/t j�U��r I ✓�� r Ci - q%I PTD: o21 aS /Development Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: 63)0'11/--- t UFS POOL: 6 LA-SIE l\/&T ✓ it)i A 6, 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 Logging also required for this well: Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 co v) co 0 0) O O O 0 _a CO C)) m ❑ O (I ) `p 06 a) c m o j NO 0 m c 0> 0 3 Q rb ° a co n 0 O L n cri V O m > c CO 3 L W C Wco o O O aC n n o m n CO CO O 0 co. ° O Ci,- > -c > L < co v) n W U 't V N o 4 c pQ Y a) 0 a)m m cO o aa) E O oo — E ° c -0 ._ m m 0 �- m P 'o 2 o > a) 3 > 3 0 r 0 m ami (1)o n 0 = m g co r O o -C 2 co a) a3is 0 0 n .- a) N nco) U (noa 0 0 3 3 m n 0 o a o o a< i 025 co > C L n 0 cos '.' 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CO 0) N- ,- N N N N N (N (N N N NCO CO CO CO CO CO CO CO CO CO I— U V R V N L O 0 m O N N d N U D re O O 0 0 CD CO O) Oo N a ' V C C V a) E CO N •N ca >. 0 E �� J E c c o Q W O E a s O. 0 a s 1 0 as a W a c9 a Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplrfy 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: Alpine Rig: Doyon 19 Date: August 26, 2014 Surface Data Logging End of Well Report CD4-96A CD4-96A PB1 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: ConocoPhillips Alaska, Inc. Rig: Doyon 19 Well: CD4-96A & CD4-96A PB1 Field: Alpine Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20673-01-00 (CD4-96A) 50-103-20673-70-00 (CD4-96A PB1) Sperry Job Number: AK-XX-0901388219 Job Start Date: 02 June 2014 Spud Date: 10 June 2014 Total Depth: 19296’ MD, 7556’ TVD (CD4-96A) 20050’ MD, 7561’ TVD (CD4-96A PB1) North Reference: True Declination: 18.78° Dip Angle: 80.77° Total Field Strength: 57576 nT Date Of Magnetic Data: 15 June 2014 Wellhead Coordinates N: North 70° 17’ 31.779” Wellhead Coordinates W: West 150° 59’ 22.031“ Drill Floor Elevation 36.65’ Ground Elevation: 18.90’ Permanent Datum: Mean Sea Level SDL Engineers: David McKechnie, Jeremy Tiegs, Tyler Dretke, Ashlee Charters Company Geologist: Jeff McBeth Company Representatives: Kenny Harding, Dan Lowe, Rick Bjorhus, Adam Dorr, Bob Finkbiner SSDS Unit Number: 115 DAILY SUMMARY 06/01/2014 SDL on location. Rig moved into position from CD1 to CD4 pad. Rigged up SDL unit. Prepared gas detection equipment for calibration and testing while the rig is displacing the well of brine with diesel at report time. 06/02/2014 Calibrated gas detection equipment and tested same with 10%, 20%, and 99% Methane. Gas equipment operational at 21:00 hrs. Nippled up BOP at report time. 06/03/2014 Nippled up BOP with MPD and function tested rams. Rigged up to test BOP. Tested same at report time. 06/04/2014 Finished testing BOP. Pulled 3-1/2" upper completion tubing free from seal assembly. Circulated bottoms up noting max gas of 1095 units. Mud weight equalized at 9.35 ppg. Broke circulation and monitored well on the trip tank. Static. Pulled out of the hole with tubing, laid down in singles while observing sufficient hole fill. Began changing out and testing upper 4-1/2" x 7" rams in preparation to pull 7" casing. Calibrated gas detection equipment at report time. Gas: The max gas was 1095 units at 13086’ MD and the average circulating background gas was 10 units. Fluids: There was no fluid lost downhole 06/05/2014 Calibrated and tested gas equipment while testing 7" RAMS. Speared 7" casing and released tie-back from seal assembly. Displaced diesel with sea water on back side out of range of the gas equipment. Began pulling 7" casing out of the hole and laying down in singles. Noted zero point drifting in gas calibration. Recalibrated. Tripped out of the hole with casing at ~6,450' MD at report time. Gas: There was no gas data to report Fluids: There was no fluid lost downhole 06/06/2014 Continued pulling out of the hole with 7" casing. Flow checked at 6865' MD. Static. Resumed pulling out of the hole to surface and laid down casing equipment. Rigged up to run 5" drill pipe and made up scraper cleanout BHA as per Baker. Picked up 5" drill pipe while running in the hole in singles on closed displacement, filled pipe every 20 stands to 11,000' MD at report time. Gas: The max gas was 53 units at 7717’ MD and the average background was 25 units. Fluids: There was no fluid lost downhole 06/07/2014 Continued tripping into the hole with scraper and tagged top of 7" liner at 13059' MD. Circulated bottoms up. Slip and cut drill line. Installed MPD Element. Began tripping out of the hole, installed super sliders. Gas: The max gas was 171 units at 7717’ MD and the average gas was 19 units. Fluids: There was no fluid lost downhole 06/08/2014 Continued tripping out of the hole to surface and laid down cleanout BHA. Made up Bridge Plug and ran in the hole to ~12,955' MD. Set Bridge Plug and tested to 2500 psi. Began displacement to 10.5 ppg Milling fluid at report time. Gas: The m gas was 16 units and the average gas was 8 units. Fluids: There was no fluid lost downhole 06/09/2014 Continued displacing sea water to Milling fluid. Max gas of 39 units encountered during displacement. Pumped Dry Job and pulled out of the hole to surface. Picked up Milling BHA and Whip Stock. Began running in the hole. Shallow test MWD. Tripping in to ~4250' MD at report time. Gas: The max gas was 39 units and the average gas was 2 units. Fluids: There was no fluid lost downhole Geology: There was no geology to report 06/10/2014 Continued running in the hole with W hipstock/Milling assembly to 12697' MD, filling pipe every 20 stands. Washed down to 12900' MD at 645 GPM. Began milling at 12935' MD, losing fluid over shakers during process. Occasionally took on fluid from trucks and Ball Mill. Milled ahead to 12958' MD. Pulled off bottom to 12924' MD and lowered flow rate to 88 GPM while changing shaker screens at report time. Gas: The max gas was 10 units at 12956’ MD and the average gas was 5 units. Fluids: There was no fluid lost downhole Geology: Geology consisted of 90% very fine grain unconsolidated sandstone and 10% siltstone with traces of silt, calcite and occasional bioclastic material. 06/11/2014 Changed out shaker screens. Noted vast improvement in performance and fluid management at milling rates of 511 GPM. Pumped bit balling sweep and returned to drilling. Milled out to 12977’ MD. Washed and reamed through window. Pulled out of the hole to 12861’ MD. Circulated and conditioned mud to 10.5 PPG. Performed Leak of Test to 16.6 PPG. Pulled out of hole to 12389’ MD. Monitored the well while slipping and cutting drill line. Pumped 35 bbl dry job and began pulling out of the hole. Laid down heavy weight drill pipe and preparing gas detection equipment for calibration and testing at report time. Gas: The max gas was 22 units at 12977’ MD and the average gas was 4 units. Fluids: There was no fluid lost downhole 06/12/2014 Continued laying down BHA. Performed 4 point calibration and testing on gas equipment while rig tested BOPE. Performed rig maintenance and waited on parts for accumulator at report time. Gas: The max gas was 5 units and the average gas was 1 unit. Fluids: There was no fluid lost downhole 06/13/2014 Repaired and tested accumulator. Made up BHA and began tripping in the hole. Ran in the hole to 1470' MD. Shallow pulse tested MWD. Noted 475 units of gas during test. Washing one stand through 13-3/8" and 9-5/8" liner lap with a background gas of 135 units at report time. Gas: The max gas was 475 units at 1470’ MD and the average gas was 5 units. Fluids: No gains or down hole losses to report 06/14/2014 Continued washing through liner lap and resumed tripping in the hole as per outlined tripping program, filling drill pipe every 20 stands to 12592' MD. Installed and tested RCD Element. Continued in the hole to 12895' MD. Displaced Milling fluid with LSND. On Bottom drilling at 18:18 hrs. Drilling ahead to 13088' MD at report time. Gas: The max gas was 139 units at 14737’ MD and the average gas was 24 units. Fluids: 11.36 bbls were gained during the trip in the hole. Geology: Geology consisted of 90% fine to very fine grain unconsolidated sandstone and 10% siltstone. 06/15/2014 Caught frequent spot samples while drilling ahead to TD at 13160' MD. (85% sandstone, 15% Siltstone. Circulated and conditioned the hole clean. Weighed up fluid from 10.5 ppg to 11 ppg. Monitored well - Static. Changed out RCD element and pumped 15 ppg dry job. Pulled out of the hole to surface. Laid down BHA. Monitoring well on the trip tank at report time. Gas: The max gas was 74 units at 13149’ MD and the average gas was 14 units. Fluids: There was no fluid lost downhole Geology: Geology consisted of 85% fine to very fine grain unconsolidated sandstone and 15% siltstone. 06/16/2014 Made up BHA #6 and ran in the hole to 1548’ MD. Shallow tested MWD and function tested reamer. Good tests. Continued running in the hole to 8145’ MD. Adjusted drill pipe/super slider placement to accommodate for RCD Element. Continued tripping in the hole to 12865’ MD. Slipped and cut drill line at report time. Gas: The max gas was 20 units at 12679’ MD and the average gas was 7 units. Fluids: There was no fluid lost downhole 06/17/2014 Ran in the hole through the window and downlinked to the MWD tools. Reamed down from 13122’ MD to 13160’ MD. Drilled from 13160’ to 13620’ MD, circulated bottoms up and began rigging up e-line. Gas: The max gas was 194 units at 13406’ MD and the average gas was 33 units. Fluids: There was no fluid lost downhole 06/18/2014 Ran in hole with E-Line and gyro tools, pulled and rigged down the wireline tools, drilled ahead to 14261’ MD. Gas: The max gas was 1362 units at 14113’ MD and the average gas was 87 units. Fluids: There was no fluid lost downhole 06/19/2014 Drilled from 14261’ MD to 15224’ MD. Reached TD at 23:40 Gas: The max gas was 2335 units at 15203’ MD and the average gas was 152 units. Fluids: There was no fluid lost downhole 06/20/2014 Circulated 2 bottoms up, circulated and conditioned the mud from 10.2 ppg to 10.7 ppg. Pulled out to the window and weighted up to 11.6. Continued to pull out of the hole. Gas: The max gas was 704 units and the average gas was 60 units. Fluids: There was no fluid lost downhole 06/21/2014 Continued to pull out of the hole and lay down BHA. Rigged up to run in the 7” liner. Began running in hole with 7” liner. Gas: The max gas was 7 units and the average gas was 2 units. Fluids: There was no fluid lost downhole 06/22/2014 Continued running in with 7” liner. Gas: The max gas was 20 units and the average gas was 7 units. Fluids: There was no fluid lost downhole 06/23/2014 Continued running in with 7” liner, rotated liner down from 14390’ MD to 15224’ MD. Circulated and reduced mud eight to 11.0 ppg, cemented per Schlumberger, saw 10 bbls of cement back to surface, rigged down the cement equipment. Pumped a 34 bbl spacer and displaced to seawater. Gas: The max gas was 458 units and the average gas was 63 units. Fluids: There was no fluid lost downhole 06/24/2014 Finished displacing well with 8.35 ppg seawater. Pulled out and laid down 5” drill pipe to 9008’ MD, lubricated rig and repaired hydraulic hose, continued to pull out of hole. Drained the stack and began rigging up to run 7” casing. Gas: The max gas was 55 units and the average gas was 3 units. Fluids: There was no fluid lost downhole 06/25/2014 Continued to run 7” casing tie-back, pumped 308 barrels of inhibited seawater and 170 barrels or diesel to freeze protect the well, stripped in and landed hanger at 12776’ MD. Gas: The max gas was 10 units and the average gas was 2 units. Fluids: No gains or down hole losses to report 06/26/2014 Continued to pick up 4" drill pipe, tested BOPE, rigged down test equipment, picked up 4" drill pipe and racked back into the derrick. Gas: The max gas was 4 units and the average gas was 1 unit. Fluids: No gains or down hole losses to report 06/27/2014 Continued to pick up 4" drill pipe and rack back into the derrick, made up BHA per Schlumberger. Began running in hole with 3.5" drill pipe. Shallow tested MWD equipment, test was good. Continued running in the hole while filling pipe every 20 stands. Calibrated gas equipment. Sample catcher arrived for production zone. Gas: No gas to report. Fluids: No gains or down hole losses to report 06/28/2014 Ran in the hole to 15109' MD. Tested casing to 3500 psi, test was good. Slipped and cut drill line. Displaced from seawater to 9.4ppg Mineral-Oil based mud. Drilled out shoe track and 20' of new formation to 15244' MD. W hile circulated up new footage saw 1493 units of gas, circulated and conditioned mud and performed a leak off test. Observed well for 30 minutes and saw that it was static. Installed RCD element and began drilling. Observed a max gas of 9902u. Once we circulated new footage the gas stabilized to an average of 1040 units. Drilled to 15367’ MD. Gas: The max gas was 9902 units and the average gas was 189 units. Fluids: No gains or down hole losses to report Geology: The lithology was 95% sandstone and 5% siltstone. The sandstone was brown to light brown, fine to very fine grained, round to sub-round and unconsolidated. The siltstone was light brown to dark brown. 06/29/2014 Circulated and conditioned while troubleshooting MWD tools, resumed drilling from 15365’ MD to 15391' MD, circulated and conditioned while troubleshooting MWD tools, resumed drilling from 15391' MD to 16691' MD. Gas: The max gas was 2563 units and the average gas was 969 units. Fluids: 55 barrels lost. Geology: Lithology was 100% sandstone. The sandstone was translucent to light cream and occasionally light gray to opaque, fine to very fine grained, round to sub-round, friable to unconsolidated, and had common Glauconite. 06/30/2014 Drilled from 16691' MD to 17029' MD. Schlumberger was unable to communicate with power steerable tool. Rotated off-bottom while switching modes. Drilled from 17029' MD to 17150' MD. At 17150’ MD, circulated gas out of well, observed a max gas of 9268 units. Shut the pumps down and flow checked the well. During the test, observed a gain of 10 barrels. Circulated and conditioned while troubleshooting power steerable downlink. At 22:40 circulated up a max gas of 8754 units. Drilled from 17150' MD to 17207' MD. Gas: The max gas was 9268 units and the average was 1242 units. Fluids: 25 barrels lost. Geology: Lithology was 90% sandstone and 10% siltstone. The sandstone was translucent to light cream, fine to very fine grained, round to sub-round, unconsolidated with abundant Glauconite. The siltstone was gray and very fine grained. 07/01/2014 Circulated and conditioned gas out of the hole, during this time gas decreased from 8039 units to 2000 units. Performed a dynamic flow check on pit 5 using MPD. ECD at the start was 10.35, decreasing to 10.28 at the end. Saw a gain of seven barrels. Drilled from 17207' MD to 17759' MD, troubleshoot downlinks to directional tool, while circulating observed a maximum reading of 9894 units. Gas: The max gas was 9894 units and the average was 4545 units. Fluids: 39 barrels lost Geology: Lithology was 90% sandstone and 10% siltstone. The sandstone was translucent to light tan, fine to very fine grained, round to sub-round, unconsolidated to friable with abundant Glauconite. The siltstone dark gray to gray. 07/02/2014 Circulated and conditioned hole while downlinking to the directional tool, cut the mud weight from 10.2ppg to 9.4ppg. Drilled from 17759' MD to 17774' MD, circulated and conditioned the mud while circulating out the 10.2ppg mud. Reamed from 17774’ MD to 17680' MD and then back to bottom encountered multiple tight spots. Drilled from 17774' MD to 18275' MD. Gas: The max gas was 7315 units and the average gas was 1162 units. Fluids: 205 barrels lost Geology: Lithology was 50% sandstone and 50% siltstone. The sandstone was translucent to light brown, fine to very fine grained, round to sub-round, unconsolidated to friable with abundant Glauconite. The siltstone was moderate brown to light brown and occasionally dark brown. Moderately friable and had trace Pyrite. 07/03/2014 Drilled from 18274' MD to 19282' MD. Gas: The max gas was 9226 units and the average was 2443 units. Fluids: 70 barrels lost downhole. Geology: The lithology 100% sandstone. The sandstone was translucent to light brown, fine to very fine grained, round to sub-round, unconsolidated to very friable, featureed scattered Glauconite and very rarely Pyrite. 07/04/2014 Drilled ahead from 19282' MD to 19946' MD. Weighted up from a 9.4 to 9.5ppg, circulated and conditioned while troubleshooting MWD. Gas: The max gas was 9145 units and the average was 963 units. Fluids: 100 barrels lost. Geology: The lithology was 100% sandstone. The sandstone was translucent to light brown, fine grained to very fine grained, round to sub-round, unconsolidated to very friable, trace Glauconite with rare pyrite. 07/05/2014 Troubleshot MWD tools. Drilled from 19947' MD to 20051’ MD, began to pack off. Washed and reamed, circulated bottoms up. During circulation, saw a max gas of 7794 units. Gas: The max gas was 7794 units and the average was 298 units. Fluids: 95 barrels lost Geology: The lithology was 80% sandstone and 20% siltstone. The lithology was translucent to light tan, fine to very fine grained, round to sub-round, unconsolidated to very friable, trace Glauconite with rare pyrite. 07/06/2014 Continued backreaming out of the hole at 190 GPM. Worked through tight spots at 17810’ MD and 17739’ MD with intermitted pack-offs. Circulated up mas gas of 600 units resulting from pack off bottoms up. Weighed fluid up from 9.5 ppg to 9.8 ppg from 08:30 to 11:30 while reciprocating pipe. Established weight and resumed backreaming out of the hole to 15200’ MD at 152 GPM noting an average hole fill of 14.7 bbls per set of 5 stands (11.78 bbls over calculated) for duration of the trip. Circulated and conditioned 3 bottoms up, losing an average of 7.25 bbls/hr for duration. Broke circulation and began running into the hole to 15500’ MD in preparation to weight mud system up to 10.4 ppg at report time. Total loss of 180 bbls observed over last 24 hours. Gas: The max gas was 600 units and the average was 72 units. Fluids: 180 barrels lost 07/07/2014 Continued to pump in the hole to 15500’ MD, circulate and condition while weighing up mud from 9.8 to 10.4 ppg. Broke circulation and attempted to monitor well. Noted excessive torque when attempting to rotate with pumps. Brought on pumps and established circulation. Stepped rates to 3.4 barrels per minute while attempting to work pipe free with no success. Cut mud weight from 10.8 to 9.4 ppg while attempting to free pipe. No success. Broke circulation and monitored well – Static. Circulate bottoms up at report time. 130 bbls lost last 24 hours. Gas: The max gas was 49 units and the average was 23 units. Fluids: 130 barrels lost 07/08/2014 Continued to circulate bottoms up. Observed 260 units of gas. Continued to circulate while attempting to pull string free without success. Noted slight well bore breathing while pulling on string. Circulated bottoms up and observed 2800 units of gas. Circulated gas from 03:20 to 05:00. Pumped 15 bbls of LVT and spotted same in open hole. Let LVT soak for one hour. Applied torque to the drillstring and attempted to jar the string free. Circulated and conditioned bottoms up while observing the well. Broke circulation and bled off pressure from MPD. Jarred string. Balanced chock and circulated bottoms up noting 7600 units of gas. Attempted to pull free while circulating and conditioned from 12:20 to 19:10. Circulated max gas of 8365 units at 19:35. Isotube sample was collected. Brought on mud from trucks and began displacing fluid from 9.2 to 10.8 ppg. Displaced 9.2 ppg at report time with a background gas of 87 units. Total loss of 30 bbls last 24 hours. Gas: The max gas was 8365 units and the average was 347 units. Fluids: 30 barrels lost 07/09/2014 Continued weighing 9.2 fluid to 10.8 ppg at 40 GPM and stepped rate to 2 barrels per minute, torque the string to 10K and backed out until normal weight was observed at surface. Broke circulation and monitored the well – Static. Rigged up and ran E-Line equipment in the holt to 15186’ MD. Fired E-Line string shots with no success. Pulled out of the hole with E-Line to surface and inspected tools. Rigged down E-line. Calibrated Gas Chromatograph. Circulate and condition mud to normal weight while working on E-Line tools at report time. Standing by to complete gas equipment calibration and testing upon breaking circulation. Gas: The max gas was 144 units and the average was 19 units. Fluids: 130 barrels lost 07/10/2014 Conditioned mud to 10.8 while E-line prepared tools. Ran in the hole with cutting tools to 15134’ MD. Attempted cut. No cut indication noted. Pulled out of the hole with E-line and laid down same. Circulated and conditioned at 2 barrels per minute. Ran in the hole with E-Line tools. Hung up on jars. Calibrated and tested gas detection equipment with 10%, 20%, and 99% methane. Worked past jars to 15134’ MD. Fired shot with no indications of successful cut. Pulled out of the hole with E-Line equipment and rigged down same in preparation to jar drillstring at report time. Gas: The max gas was 12 units and the average was 2 units. Fluids: 90 barrels lost 07/11/2014 Jarred string with no success. Inspected Derrick. Resumed jarring and inspected Derrick. Slip and cut drill line. Rigged up Wireline String Shot and ran in the hole with same. Fired shot at target depth of 15156’ MD with no sign of cutting at surface. Worked pipe and separated drillstring. Pulled out of the hole with E-Line and rigged down same. Tested Top Drive to 3500 PSI. Rotated drillstring without restriction. Circulated bottoms up with a background gas of 13 units at report time. 93 barrels of fluid lost last 24 hours. Gas: The max gas was 130 units and the average was 36 units. Fluids: 93 barrels lost 07/12/2014 Continued to circulate bottoms up at 2 barrels per minute. Monitored well – static. Pumped dry job and began pulling out of the hole with 3-1/2” drill pipe singles. Trip out of the hole and lay down singles at report time. 40 bbls lost last 24 hours. Gas: The max gas was 16 units and the average was 10 units. Fluids: 40 barrels lost 07/13/2014 Continued pulling out of the hole with 3-1/2” drill pipe to surface and lay down singles. Monitored the well. Observed slight drop. Tested BOPE. Made up fishing tools. Single in the hole with fish to 11410’ MD as per program at report time. 10 bbls of fluid lost last 24 hours Gas: The max gas was 8 units and the average was 2 units. Fluids: 24 barrels lost 07/14/2014 Continued running in the hole with fishing equipment and tagged fish at 11675’ MD. Established circulation and engaged fish. Attempted to jar free. Displaced 10.8 ppg fluid to 10.2 ppg and continued to work pipe. Ran in the hole with E-Line equipment at report time. 284 bbls lost last 24 hours. Gas: The max gas was 35 units and the average was 11 units. Fluids: 284 barrels lost 07/15/2014 Continued to run in the hole with E-Line Cutter to 11304’ MD. E-Line got stuck in fishing BHA. Lost E-Line BHA while attempting to pull free. Pulled remaining equipment to surface. Picked up Slickline and ran in the hole to retrieve fish. Unable to retrieve. Pulled out of the hole with Slickline and added 5’ Sub. Began running back in the hole with Slickline. Encountered 8500 units of gas. Collected Isotube gas sample. Circulated gas out at 2 barrels per minute at report time. No losses to report for last 24 hours. Gas: The max gas was 8579 units and the average was 260 units. Fluids: 0 barrels lost 07/16/2014 Ran in the hole with slickline to retrieve fish. Continued to circulate gas out to ~1200 units. Attempted to pull out fish. Pulled out of the hole to change out slickline tools. Re-ran slickline to fish out and pulled out of the hole to change tools. Ran in the hole with slickline to target at 11600’ MD, but was unable to retrieve the fish. Pulled out of the hole to modify slickline BHA. Ran into the hole with slickline. Gas: The max gas was 9185 units and the average was 797 units. Fluids: 25 barrels lost 07/17/2014 Continued to run into the hole with slickline to target. Engaged fish and began pulling out of the hole. Lost fish. Resumed pulling out of the hole with slickline. Changed out slickline tools and re- ran same. Engaged fish. Lost the fish. Rigged down slickline. Circulated and conditioned mud. Rigged up gooseneck and prepared to run into the hole with E-line. Gas: The max gas was 61 units and the average was 27 units. Fluids: 11 barrels lost 07/18/2014 Continued rigging up E-line and ran into the hole with same. Ran in hole to 11,700’ MD. Fired string shot. Successfully separated string. Observed 35,000 lb loss in string weight. Pulled out of the hole with E-line. Confirmed shot was fired. Circulated and conditioned, weighted up to 10.8 ppg at 4 barrels per minute. Flow checked. Static. Pump 13 ppg slug. Pulled out of the hole while inspecting drill pipe. Gas: The max gas was 28 units and the average was 11 units. Fluids: 5 barrels lost 07/19/2014 Continued pulling out of the hole at 1017’ MD while inspecting drill pipe. Pulled MPD element. Continued to pull out of the hole to surface. Laid down fishing BHA. Monitored well (static). Make up Baker fishing BHA. Ran into the hole with same to 11,428’ MD. Installed RCD element. Continued running in the hole with 4” drill pipe. Tag fish at 11,675’ MD. Step pump rate up to 3.5 barrels per minute. Circulated and conditioned mud with background gas of 10 units. Gas: The max gas was 28 units and the average was 10 units. Fluids: 14 barrels lost 07/20/2014 Circulated and conditioned at 3 barrels per minute. Ran in hole with slickline at 15,090’ MD. Attempted to latch on fish. Pulled out of the hole with slickline without fish. Re-ran slickline to 15,090’ MD. Attempted to latch on fish. Fish retrieved and pulled out of the hole with slickline and fish. Made up wireline tools. Tested and calibrated gas equipment with 10%, 20% and 99% methane. Prepared to run into the hole with wireline tools. Gas: The max gas was 61 units and the average was 18 units. Fluids: 11 barrels lost 07/21/2014 Made up wireline tools. Ran in the hole with same to 15,152’ MD. Could not work past 15,152’ MD. Fired explosives with no indication of shot fired. Attempted to pull out of the hole with wireline. Tool stuck. Worked pipe and pumps with no success in freeing wireline tool. Decision made to pull out of E-line rope socket. Pulled free from rope socket. Top of wireline fish at 15,152’ MD. Pulled out of hole with wireline from 15,152’ MD to 50’ MD. Rigged down wireline and tools. Circulated and conditioned mud. Pumped dry job. Pulled out of the hole to 10,690’ MD. Gas: The max gas was 63 units and the average was 18 units. Fluids: 76 barrels lost 07/22/2014 Continued to pull out of the hole to 1,000’ MD. Removed 4” MPD element. Continued tripping out of the hole from 1000’ MD to surface while inspecting 3-1/2” drill pipe. E-line tool was retrieved. Laid down tools. Made up Baker scraper assembly and tripped in with same to 2039’ MD. Slipped and cut drill line. Ran out of hole with scraper assembly to ~6000’ MD. Gas: The max gas was 10 units and the average was 7 units. Fluids: 13 barrels lost 07/23/2014 Continued to trip in the hole from ~6000’ MD to 14855’ MD, filled pipe every 20 stands. Set 4” RCD element. Continued to run in the hole to 15045’ MD. Washed down to 15157’ MD at 3-1/2 barrels per minute. Tagged top of fish and circulated bottoms up while reciprocating pipe. Noted bubbling in the possum belly with no notable gas. Bag tested gas equipment with good results. Broke circulation. Monitored the well. Static. Pumped 12.8 ppg dry job. Tripped out of the hole to 2980’ MD. Gas: The max gas was 16 units and the average was 9 units. Fluids: 20 barrels lost 07/24/2014 Continued to pull out of the hole from 2980’MD. Laid down scraper BHA. Made up cement retdainer and ran in the hole. Tagged fish at 15156’ MD. Performed injectivity test. Pumped 17 bbls of 15.8 ppg cement. Reverse circulated out excess cement and spacer. Tested retainer. Displaced 10.8 ppg mud to 9.6 ppg mud. Gas: The max gas was 51 units and the average was 9 units. Fluids: 48 barrels lost 07/25/2014 Continued to displace fluid and circulate until 9.6 ppg was achieved. Flow check. Static. Pumped 36 bbl dry job. Pulled out of the hole from 15156’ MD to surface on calculated hole fill and laid down BHA. Rig floor observed bag chunking. Removed bag chunks. Rigged down MPD equipment from stack for rig maintenance. Gas: The max gas was 51 units and the average was 9 units. Fluids: No barrels lost 07/26/2014 Removed rig element and installed new element. Rigged up MPD equipment. Test same. Rigged up to test BOPE. Gas: The max gas was 10 units and the average was 6 units. Fluids: No barrels lost 07/27/2014 Continued testing BOP. Made up whipstock BHA. Ran in hole with same to 1520' MD. Tested MWD tools. Good test. Continued running in the hole to 14,915' MD, filling pipe every 20 stands. Circulating and conditioning at report time. Gas: The max gas was 10 units and the average was 7 units. Fluids: No barrels lost 07/28/2014 – 08/03/2014 Sperry SDL was released from the site due to damage to the Top Drive and Derrick. Repairs have commenced and Sperry SDL will return when operations resume. Gas: No gas to report Fluids: No barrels lost 08/04/2014 Sperry SDL returned to location at 16:40 hrs. Ran in the hole with the whipstock and milling assembly to 15100’ MD. Began milling window from 15132’ MD to 15165’ MD, and then flow checked the well and observed a slight drop. Pumped out to 15022’ MD, installed the RCD element, and pumped out from 15022’ MD to 12766’ MD. Gas: The max gas was 12 units and the average was 5 units. Fluids: No barrels lost 08/05/2014 Pulled out from 12766’ MD to 1123’ MD and pulled out the RCD element. Continued to pull out of the hole and laid down the BHA as per Schlumberger and Baker. Picked up the 6.125” milling BHA and ran in the hole to 8623’ MD. Gas: The max gas was 4 units and the average was 3 units. Fluids: No barrels lost 08/06/2014 Continued running in the hole with the 6.125” milling BHA, performed a slip and cut to the drill line, serviced the top drive, and performed rig maintenance. Milled and reamed through the window and then circulated and conditioned fluids. Performed a flow check and began pulling out of the hole. Gas: The max gas was 20 units and the average was 6 units. Fluids: No barrels lost 08/07/2014 Continued pulling out of the hole and proceeded to lay down the BHA as per Sclumberger. Cleaned and cleared the rig floor and laid down 4” HWDP. Made up the mud motor BHA as per Schlumberger. Ran in the hole from 275’ MD to 9285’ MD. Gas: The max gas was 22 units and the average was 9 units. Fluids: No barrels lost 08/08/2014 Continued running in the hole, installed the RCD element, and continued to run in the hole. Broke circulation and conditioned fluids. Drilled from 15165’ MD to 15195’ MD and then pulled out of the top of the window. Performed a leak off test and ran back back to bottom. Drilled from 15195’ MD to 15265’ MD and then circulated. Once fluids were conditioned a flow check was performed and pumped a dry job followed with pulling out of the hole. Gas: The max gas was 4262 units and the average was 592 units. Fluids: No barrels lost 08/09/2014 Continued to pull out of the hole, tested the choke manifold, performed a flow check, inspected derrick, drained the BOPE stack, and began to testing BOPE. Gas: The max gas was 8 units and the average was 6 units. Fluids: No barrels lost 08/10/2014 Finished testing the BOPE and tested the plug. Installed the wear ring and blew down the lines. Made up the RSS BHA and ran in the hole. Shallow pulse tested the MWD equipment. Began singling in the hole with 3.5” drill pipe. Gas: The max gas was 435 units and the average was 119 units. Fluids: No barrels lost 08/11/2014 Continued to run in the hole and installed the ECD element when changing pipe dimensions. Circulated and conditioned the fluids and pumped a bottoms up. Sip and cut the drill line and serviced the top drive. Ran in the hole to 15265’ MD and drilled to 15363’ MD. Back reamed out to 15240’ MD and pulled out to the casing window. Ran back to bottom and drilled from 15363’ MD to 15592’ MD. Gas: The max gas was 1458 units and the average was 177 units. Fluids: No barrels lost Geology: Lithology was 90% sandstone and 10% siltstone. The sandstone was brown to light brown, fine to very fine grained, scattered lithic fragments, sub-round to round, friable to unconsolidated. The siltstone was light brown, very fine grained and friable. 08/12/2014 Drilled ahead through the production section from 15592’ MD to 17074’ MD. Gas: The max gas was 2915 units and the average was 1225 units. Fluids: No barrels lost Geology: Lithology was 95% sandstone and 5% siltstone. The sandstone was light brown to light tan, translucent to transparent, round to sub-round, fine to very fine grained, well sorted, composed of Quartz with abundant Glauconite. 08/13/2014 Drilled ahead through the production section from 17074’ MD to 18175’ MD. Gas: The max gas was 2644 units and the average was 876 units. Fluids: There was 23 bbls lost downhole. Geology: Lithology was 100% sandstone. The sandstone was light gray to light brown, translucent to transparent, sub-round to sub-angular, fine to very fine grained, well sorted, unconsolidated and composed of Quartz with common Glauconite. 08/14/2014 Drilled from 18175' to 19296', troubleshoot MWD tool, circulate bottoms-up. Gas: The max gas was 3700 units and the average was 961 units. Fluids: Daily downhole losses 23 bbls. Total losses from 8/13 to today are 46 bbls. Geology: Lithology was 100% sandstone. The sandstone was light gray to off-white, translucent to transparent, sub-round to sub-angular, fine to very fine grained, well sorted, unconsolidated and composed of Quartz with common Glauconite. 08/15/2014 Circulated and conditioned, ran back to bottom, began backreaming out of hole. Gas: The max gas was 3923 units and the average was 734 units. Fluids: Daily downhole losses 24 bbls. Total losses from 8/13 to today are 70 bbls total. 08/16/2014 Circulated and conditioned, ran back to bottom, began backreaming out of hole. Gas: The max gas was 3923 units and the average was 734 units. Fluids: Daily downhole losses 24 bbls. Total losses from 8/13 to today are 70 bbls total. 08/17/2014 Continued to backream out of the hole to 15354', pulled out to 15122', weighted up to 10.2 ppg, pulled out to 14931', installed RCD element, pulled out to 7992', pumped 13.2 ppg dry job, continued to pull out. Gas: The max gas was 95 units and the average was 18 units. Fluids: Daily downhole losses 26 bbls. Total losses from 8/13 to today are 96 bbls total. 08/18/2014 Continued to lay down 3.5” drill pipe, made up the liner hanger, ran in hole from 4279’ to 4377’ MD, circulated two liner volumes, continued to run in the hole to 15069’ MD, circulate and condition while picking up 4” heavy weight drill pipe. Gas: The max gas was 10 units and the average was 4 units. Fluids: Daily downhole losses 0 bbls. Total losses from 8/13 to today are 104 bbls total. 08/19/2014 Ran in the hole with liner to 15244’ MD. Observed tight spots at 15190’ MD, 15243’ MD and 15250’ MD. Could not work past 15244’ MD. Attempted to circulate with no returns, observed as surface. Decision was made to pull out of the hole into 7” casing. Established circulation and conditioned mud. Began pumping in the hole from 15063’ MD. Washed down to 17426’ MD, centrifuging as needed at report time. Gas: The max gas was 26 units and the average was 10 units. Fluids: Daily downhole losses 22 bbls. Total losses from 8/13 to today are 126 bbls total. 08/20/2014 Continued running in the hole to 19268’ MD on 4-1/2” drill pipe. Tagged bottom at 19293’ MD. Set liner hanger. Tested WIV. Released from liner after several attempts. Set liner hanger. Tested packer. Pulled out of the hole to 14935’ MD and confirmed release from liner. Displaced mineral oil based mud to sea water. Singling out of the hole with 4” drill pipe at report time. Gas: The max gas was 1200 units and the average was 233 units. Fluids: Daily downhole losses 17 bbls. Total losses from 8/13 to today are 143 bbls total. 08/21/2014 Continued pulling out of the hole to surface and laid down 4" drill pipe. Pulled RCD element and slip/cut drill line. Pulled wear ring and rigged up to run 3-1/2" tubing. Running in the hole with tubing to 1558' MD at report time. No losses to report. Gas: The max gas was 4 units and the average was 1 unit. Fluids: Daily downhole losses 0 bbls. Total losses from 8/13 to today are 143 bbls total. 08/22/2014 Continued running in the hole with 3-1/2" tubing, installing I-wire and cannon clamps testing I- wire every 25 joints. Tripping in to 13697' MD at report time. Gas: The max gas was 4 units and the average was 1 unit. Fluids: Daily downhole losses 0 bbls. Total losses from 8/13 to today are 143 bbls total. 12000 13000 14000 15000 16000 17000 18000 19000 20000 21000 22000 23000 24000 0 10 20 30 40 50 60 70 80 90 Me a s u r e d D e p t h Rig Days Prognosed Prognosed WELL NAME: CD4-96A & CD4-96A PB1 OPERATOR: ConocoPhillips Alaska, Inc. MUD CO: Mi Swaco RIG: Doyon 19 SPERRY JOB: AK-XX-0901388219 Days vs. Depth Sperry SDL reamains on location from previous well 28 May 2014 Sperry SDL services online 02 June 2014 LOCATION: Alpine AREA: North Slope Borough STATE: Alaska SPUD: 10 June 2014 TD: 14 August 2014 TD Window Mill 12977' MD, 6827.46' TVD Off Bot: 14:13 11 June 2014 Commenced 8.750" Window Mill Section On Bot: 14:50 10 June 2014 POOH for Rotary Steerable BHA Off Bot: 05:10 15 June 2014 TD Intermediate Hole Section 15224' MD, 7492' TVD Off Bot: 23:40 19 June 2014 Landed 7" Casing 15224' MD, 7492' TVD 24 June 2014 Commenced 6.125" Production Hole Section On Bot: 17:00 28 June 2014 POOH for RSS Tool Failure Off Bot: 12:00 05 July 2014 Stuck Pipe at Shoe 07 July 2014 RIH with Fishing Assembly 13 July 2014 Servicing Derrick and Top Drive 28 - 31 July 2014 Commenced 6.125" Production Hole Section On Bot: 15:10 11 Aug 2014 Landed Whipstock 15156 MD, 7587' TVD 4 Aug 2014 TD Production Hole Section 19296' MD, 7556' TVD Off Bot: 21:30 14 Aug 2014 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 19 HOLE SECTION:Intermediate 2 EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 AK-XX-0901388219 Alaska CD4-96A Alpine Conoco Phillips Alaska, Inc.North Slope Borough Tyler Dretke 19-Aug-2014 What went as, or better than, planned: Our gas equipment performed as expected. We never experienced any loss of data or downtime. Using a multi latch calibrations has improved the accuracy and validity of our gas measurements. Difficulties experienced: The pit sensors resolution and accuracy continues to be an issue. We continue to experience 5-10 barrel swings in pit volume over a matter of seconds. Recommendations: Installing our own pit sensors would increase the accuracy to which we can track volumes. It would also provide a back up to the rigs own sensors. Innovations and/or cost savings: N/A Surface Data Logging After Action Review WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:Doyon 19 HOLE SECTION: Production EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Tyler Dretke 19-Aug-2014 What went as, or better than, planned: Our communication with the pit watchers, ball mill and mud engineers continues to improve. We are all able to work together to accurately track hole volumes on an hourly basis. Difficulties experienced: Schlumberger continues to have issues sending Sperry live gamma, resistivity, and ECD data. This causes difficulty when interpreting lithology. Recommendations: Continue to stress the importance of this data. It greatly increases the accuracy of our logs and our ability to keep the client informed on changes in lithology. Innovations and/or cost savings: N/A AK-XX-0901388219 Alaska CD4-96A PB1 Alpine Conoco Phillips Alaska, Inc.North Slope Borough Surface Data Logging After Action Review CD4-96A & CD4-96A PB1 Conoco Phillips Alaska, Inc. Mi Swaco Doyon19 AK-XX-0901388219 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++ 4-Jun 12932 8.40 27 -------------4500 -Pull 3-1/2" Tubing - C/O BOP RAMS 5-Jun 13100 8.40 --------------4500 -Pull 7" casing out of the hole 6-Jun 13100 8.40 --------------4500 -RIH with clean out assembly 7-Jun 13100 8.40 --------------4500 -RIH with Bridge Plug 8-Jun 13100 10.50 44 9 26 13/15/15 9.5 44/35/31/26/13/12 -10.0 /90 -0.02 9.6 -.01/.08 300 60 Displace Sea Water to Milling Fluid 9-Jun 13100 10.50 48 11 30 13/16/17 4.6 52/41/37/30/15/14 1/-10.0 1/--0.01 8.9 -.01/.06 300 60 RIH with Whipstock/Milling Assembly 10-Jun 12952 10.50 50 9 36 19/21/22 5.7 54/45/40/34/14/13 1/-10.0 2/88 -0.02 9.8 3.0 .01/.08 300 60 Mill out Window 11-Jun 12965 10.50 48 10 33 17/19/21 6.1 53/43/37/30/17/16 1/-8.0 2/90 0.25 0.02 9.8 0.5 .01/.08 300 60 L/D BHA 12-Jun 12977 10.50 46 9 28 14/16/17 6.3 46/37/33/27/13/12 1/-8.0 2/90 0.25 0.02 9.9 0.5 .01/.08 300 60 Accumulator Maintenance 13-Jun 12977 10.50 47 10 30 15/17/19 6.1 50/40/35/27/15/13 1/-8.0 2/90 0.25 0.02 9.5 0.5 .01/.07 300 60 RIH with BHA to 1550' MD 14-Jun 13088 10.50 45 14 21 9/10/10 3.2 49/35/30/22/8/8 1/-10.0 3/88 tr 0.02 9.5 1.5 .01/.08 300 60 Drilling ahead 15-Jun 13160 11.00 43 11 20 9/9/10 4.1 42/31/26/20/7/7 1/2 11.0 3/87 tr 0.02 9.5 3.8 .01/.09 600 60 Lay down BHA / Monitor well 16-Jun 13160 10.70 48 11 20 9/10/10 3.4 42/31/27/21/7/7 1/2 11.0 3/87 tr 0.01 9.2 3.8 .01/.06 600 60 Cut & Slip Drill Line 17-Jun 13620 10.30 46 11 25 11/15/16 3.5 47/36/31/24 1/2 11.0 3/86 tr 0.02 9.6 6.5 .01/.13 550 56 E-Line 18-Jun 14090 10.20 45 13 25 12/16/18 3.5 51/38/33/26/12/10 1/2 12.0 3/85 tr 0.02 9.6 10.0 .01/.15 500 44 Drilling 19-Jun 15134 10.20 44 12 25 12/18/19 4.0 49/37/32/25/11/10 1/2 11.5 3/86 tr 0.02 9.7 13.8 .01/.15 550 60 TD 20-Jun 15224 11.60 44 11 25 10/14/16 2.8 47/36/31/24/10/9 1/2 15.0 3/82 tr 0.02 9.7 16.0 .01/.16 500 60 POOH 21-Jun 15224 11.50 50 12 26 11/13/14 2.7 50/38/32/25/11/10 1/2 16.0 3/82 tr 0.02 9.7 14.0 .01/.17 500 60 RIH w/Liner 22-Jun 15224 11.60 55 14 24 11/14/15 2.8 52/38/34/27/11/10 1/2 16.0 3/82 tr 0.02 9.6 15.0 .01/.17 550 60 RIH w/Liner 23-Jun 15224 8.40 27 -------------4500 -Displace to Seawater 24-Jun 15224 8.40 27 -------------4500 -R/U to run 7" Casing 25-Jun 15224 8.40 27 -------------4500 -P/U 4" DP 26-Jun 15224 8.40 27 -------------4500 -P/U 4" DP 27-Jun 15224 8.40 27 -------------4500 -R/U With 3.5" DP Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb mg/L ppb ASG 28-Jun 15224 9.40 48 14 8 7/10/2011 5.2 36/22/17/12/4/4 /2 14.0 81/19 1.38 1.79 415.0 -32500 1.05/119.16 2.7 Drilling Ahead 29-Jun 16499 9.3 52 15 12 11/14/14 4.8 42/27/22/16/8/8 /2 12.74 80/20 1.6 2.08 758 -32500 75.33/42.15 2.6 Drilling Ahead 30-Jun 17150 9.2 52 14 12 10/14/14 4.5 40/26/21/15/7/7 /2 10.78 80/20 1.5 1.95 762 -32000 66.56/42.02 2.6 Drilling Ahead 1-Jul 17759 9.4 50 16 14 12/16/17 4.6 46/30/24/17/9/8 /2 13.5 80/20 1.5 1.95 854 -32000 19.18/100.68 2.7 Circulating out Gas 2-Jul 18150 9.4 54 14 12 11/16/17 4.7 40/26/21/16/9/8 /2 14 78/22 1.5 1.95 920 -32000 57.58/61.02 2.7 Drilling Ahead 3-Jul 19145 9.4 53 13 12 10/13/14 4.6 38/25/20/15/8/7 /2 15 80/20 1.6 2.08 797 -32000 114.37/6.6 2.6 Drilling Ahead 4-Jul 19947 9.5 51 14 13 10/14/15 4.3 41/27/22/16/8/8 /2 13.96 80/20 1.3 2.08 823 -32000 0.6/120 2.6 Ciculate and Condition 5-Jul 20050 9.5 50 14 13 10/14/15 4.3 41/27/20/15/8/7 /2 13.96 80/20 1.5 1.95 833 -32250 5.97/119.06 2.7 BROOH 6-Jul 20050 9.8 50 14 13 1014/16 4.6 41/27/22/16/8/8 /2 15.32 80/20 1.5 1.95 810 -31250 17.18/126.74 2.7 Circulate 3 Bottoms Up 7-Jul 20050 9.4 49 13 11 8/13/13 4.7 37/24/18/13/6/6 /2 14 80/20 1.6 2.08 718 -31000 16.01/104.39 2.7 Circulate Bottoms Up 8-Jul 20050 9.2 50 13 12 9/14/14 4.8 38/25/20/14/7/7 /2 11.56 80/20 1.5 1.95 877 -31000 25.46/82.79 2.7 Weighing up to 10.8 9-Jul 20050 10.8 52 14 14 10/14/15 4.8 42/28/23/17/9/8 /2 21.76 79/21 1.50 1.95 906 -31,300 7.78/197.71 2.7 Pulling E-Line 10-Jul 20050 10.8 59 15 16 10/15/16 4.8 46/31/26/19/9/9 /2 20.76 80/20 1.60 2.08 876 -31500 84.01/123.11 2.7 R/D E-Line 11-Jul 20050 10.80 55 18 18 14/19/22 5.6 54/36/29/21/11/10 /2 23.5 80/20 1.50 1.95 1020 -31000 82.53/124.86 2.7 CBU 12-Jul 20050 10.80 51 17 12 10/15/16 5.8 46/29/22/18/8/7 /2 23.5 80/20 1.50 195.00 1002 -32000 85.47/121.39 2.7 POOH 13-Jul 20050 10.30 50 15 10 9/15/15 6.5 40/25/20/15/6/6 /2 16.0 82/18 1.60 2.08 757 -31000 20.07/156.6 2.7 RIH 14-Jul 20050 10.40 50 14 12 9/16/17 6.2 40/26/20/15/7/7 /2 14.0 81/19 1.50 1.95 824 -34000 35.04/126.34 3.6 RIH with Wireline 15-Jul 20050 10.40 49 14 15 11/18/18 6.4 43/29/22/16/8/8 /2 14.0 81/19 1.63 2.11 879 -31500 35.54/127.22 3.6 RIH with Slickline 14-Aug-2014 Remarks WELL NAME:LOCATION:Alpine OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:10-Jun-2014 SPERRY JOB:TD: W a t e r a n d O i l B a s e d M u d R e c o r d Date Depth Wt Vis PV YP Gels HTHP R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Alka POM Lime Elec Stab CaCl2 WPS LGS/HGS ASG Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%ml ppb volts ppb mg/L ppb ASG 16-Jul 20050 10.40 51 14 14 11/19/19 6.6 42/28/22/16/7/7 /2 14.0 81/19 1.60 2.08 854 -31000 35.63/127.4 3.6 RIH with Slickline 17-Jul 20050 10.40 57 17 16 12/24/25 6.8 50/33/27/20/10/10 /2 14.0 81/19 2.20 2.86 965 -32000 35.44/127.04 3.6 RIH with E-line 18-Jul 20050 10.80 54 15 14 11/21/21 7.0 44/29/23/16/8/8 /2 18.0 83/17 1.50 1.95 870 -31000 63.28/126.42 3.4 Pulling out of the hole with E-line 19-Jul 20050 10.80 57 16 16 11/24/25 7.0 48/32/24/17/8/8 /2 16.0 82/18 1.60 2.08 801 -30800 64.79/124.39 3.4 Circulate/condition 20-Jul 20050 10.80 53 19 15 15/25/26 7.2 53/34/27/19/10/10 /2 16.0 82/18 1.57 2.05 936.0 -31000 64.75/124.32 3.4 circulate and condition 21-Jul 20050 10.80 56 16 14 12/22/23 6.8 46/30/24/16/7/7 -/2 17.0 82/18 1.50 1.95 852.0 -31000 64.75/124.32 3.4 RIH w/ wireline 22-Jul 20050 10.80 55 16 16 13/25/26 6.6 48/32/25/18/9/9 -/2 17.0 82/18 1.45 1.89 995.0 -30500 64.85/124.49 3.4 POOH w/ wireline 23-Jul 20050 10.80 57 15 14 12/22/24 6.6 44/29/22/16/8/8 -/2 17.0 82/18 1.45 1.89 845.0 -31000 64.75/124.32 3.4 RIH, tagged fish, pumped dry job 24-Jul 20050 10.80 55 16 15 13/24/25 6.6 47/31/23/16/8/8 -/2 17.0 82/18 1.55 2.02 887.0 -31000 64.75/124.32 3.4 Cut MW t/9.6ppg 25-Jul 15158 9.60 52 14 11 12/16/17 5.2 39/25/20/14/7/7 -/2 10.5 76/24 1.30 1.69 701.0 -38000 59.87/56.84 3.2 R/D MPD 26-Jul 15158 9.60 53 13 14 12/14/14 5.3 40/27/20/13/7/7 -/2 10.5 76/24 1.30 1.69 725.0 -38000 59.87/56.84 3.2 Test BOPE 27-Jul 15158 9.60 60 13 9 9/12/14 5.2 35/22/17/11/6/5 NA/2 10.5 76/24 1.20 1.56 458.0 -40000 59.53/56.09 3.2 Testing MPD and BOPE 28-Jul 15158 9.60 55 12 11 10/18/19 5.2 35/23/17/12/6/6 NA/2 10.5 76/24 1.30 1.69 495.0 -40000 59.53/56.09 3.2 Servicing Top Drive 29-Jul 15158 9.60 54 12 13 12/20/21 5.2 37/25/19/14/6/6 NA/2 10.5 76/24 1.30 1.69 479.0 -40000 59.53/56.09 3.20 Servicing Top Drive 30-Jul 15158 9.60 48 10 10 9/16/18 5.2 30/20/15/11/5/5 NA/2 10.5 76/24 1.30 1.69 509.0 -40000 59.53/56.03 3.20 Servicing Derrick 31-Jul 15158 9.60 49 14 7 9/17/18 5.2 35/21/17/12/6/5 NA/NA 10.7 76/24 1.30 1.69 658.0 -40000 59.53/56.09 3.20 Servicing Derrick 1-Aug 15158 9.60 48 14 8 9/17/19 -36/22/18/13/6/5 NA/NA 10.7 76/24 1.20 1.56 603.0 -36000 60.19/57.62 3.20 TOH with Whipstock / Milling Assembly 2-Aug 15158 9.60 49 14 8 9/17/19 -36/22/18/13/6/5 NA/NA 10.7 76/24 1.20 1.56 611.0 -36000 60.19/57.62 3.20 RIH with Clean-out Assembly and Circulating 3-Aug 15158 9.60 52 15 10 9/16/16 -40/25/19/13/6/6 NA\2 10.7 80/20 1.20 1.56 602.0 -36000 --RIH with Whipstock / Milling Assembly 4-Aug 15158 9.60 50 16 9 9/16/16 -41/25/20/13/6/6 -12.0 77/23 1.90 2.47 706.0 -40000 1.89/118.97 2.90 TOH with Whipstock / Milling Assembly 5-Aug 15165 9.60 50 16 9 9/16/16 -41/25/20/13/6/6 -12.0 77/23 1.90 2.47 706.0 -40000 1.89/118.97 2.90 RIH with 2nd Milling Assembly 6-Aug 15165 9.60 51 16 10 9/16/17 -42/26/21/13/6/6 -12.0 77/23 1.80 2.34 701.0 -40000 1.89/118.97 2.90 TOH with Milling Assembly 7-Aug 15165 9.60 52 16 10 8/15/17 5.0 42/26/19/13/6/6 -13.0 79/21 1.55 2.02 740.0 -34000 12.49/114.67 2.90 RIH with Mud Motor Assembly 8-Aug 15265 9.60 57 17 11 8/17/19 -45/28/21/15/6/6 -14.0 80/20 1.45 1.89 699.0 -34000 12.49/114.67 2.90 TOH with Mud Motor Assembly 9-Aug 15265 9.60 53 16 9 9/18/20 -41/25/19/13/6/6 -14.0 80/20 1.50 1.95 749.0 -34000 12.49/114.67 2.90 Testing BOPE 10-Aug 15265 9.60 55 16 9 8/17/19 -41/25/19/13/6/6 -14.0 80/20 1.45 1.89 851.0 -33500 12.13/115.3 2.90 RIH 11-Aug 15415 9.60 56 12 9 8/14/15 5.0 33/21/16/11/5/4 -/2 13.9 81/19 1.50 1.95 749.0 -35000 69.47/60.63 2.70 Drilling Ahead 12-Aug 16851 9.60 50 13 8 7/13/14 3.2 34/21/15/10/4/4 -/2 14.5 81/19 1.35 1.76 536.0 -35000 41.35/87.01 2.80 Drilling Ahead 13-Aug 18060 9.60 52 16 9 7/14/15 3.4 41/25/19/13/5/5 -/2 14.0 81/19 1.50 1.95 418.0 -30000 2.91/127.07 2.90 Drilling Ahead 14-Aug 19296 9.60 55 16 9 7/11/14 3.4 41/25/19/12/4/4 -/2 14.0 81/19 1.35 1.76 487.0 -28000 1.31/129.77 2.90 TD 15-Aug 19296 9.60 64 19 8 7/13/15 3.5 46/27/20/13/4/4 -/2 15.0 82/18 1.40 1.82 408.0 -28000 57.88/76.69 2.80 BROOH 16-Aug 19296 10.20 66 21 9 9/15/17 3.4 51/30/23/15/5/5 -/2 18.0 84/16 1.40 1.82 610.0 -28000 15.34/154.3 2.90 POOH 17-Aug 19296 10.20 66 22 12 10/16/17 3.6 56/34/25/15/5/5 -/2 15.0 82/18 1.45 1.89 627.0 -28000 15.34/90.56 3.30 L/D DP 18-Aug 19296 10.20 72 19 10 8/16/17 3.7 48/29/22/15/4/4 -/2 15.0 82/18 1.40 1.82 476.0 -28000 15.34/90.56 3.30 P/U 4" HWDP 19-Aug 19296 10.20 65 18 9 7/14/15 3.4 45/27/20/13/4/4 -/2 15.0 82/18 1.40 1.82 456.0 -29000 15.89/69.03 3.30 RIH with Liner 20-Aug 19296 8.40 27 ---------------POOH Casing Record 7" Casing @ 15224' MD, 7491'TVD 20" Conductor @ 114' MD, 114'TVD 13.375" Casing @ 1566' MD, 1536'TVD 9.625" Casing @ 12935' MD, 10448'TVD W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 5 300 2 Smith XR+ Mill Tooth 8.75 12977 13160 183 6.10 0.074 30.0 25 60 2460 550 1-1-WT-A-E-I-NO-TD Pull out of hole for rotary Steerable 6 400 3 Mi616 PDC 8.75 13160 15224 2064 32.20 0.902 64.1 28 120 2750 650 0-1-WT-G-X-I-NO-TD TD Intermediate Section 7 500 4 Mdi513 PDC 6.125 15224 20050 4826 -0.296 ------Stuck in hole 15 700 5 Smith XR+ Mill Tooth 6.125 15165 15265 100 2.40 0.389 41.7 5 80 2640 200 1-1-CT-G-E-I-CT-TD Milling Bit 16 800 6 MDi513 PDC 6.125 15265 19296 4031 163.70 0.314 75.1 12 150 3450 193 1-1-CT-A-X-I-NO-DTF TD Production Section Alaska RIG:Doyon19 SPUD:10-Jun-2014 WELL NAME:CD4-96A & CD4-96A PB1 LOCATION:Alpine OPERATOR:Conoco Phillips Alaska, Inc.AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0901388219 TD:14-Aug-2014 Mi Swaco STATE: B i t R e c o r d . . * 24 hr Recap:Rig moved into position. Rigged up SDL unit. Preparing gas detection equipment for calibration and testing while Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 1-Jun-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 1 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - - - - - - Size 100% Gas In Air=10,000 Units-Connection 0 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min -Background (max) Trip Average - Mud Type Lst Type - ---- Depth in / out YP (lb/100ft2) - 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Displacing Brine PV - Footage - K. Harding D. Lowe ShClyst TuffGvlCoal cP - Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A N/A N/A Max @ ft Current - -- Date: Time: the rig is displacing the well of brine with diesel at report time. - in --Minimum Depth C-5n - - C-2 - - SPP (psi) Gallons/stroke-- TFABit Type Depth -- MBT 0' pH - 0 0 0 Siltst - - Units* Casing Summary Lithology (%) 00 0 Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap:Calibrated gas detection equipment and tested same with 10% 20% and 99% Methane. Gas equipment operational Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 2-Jun-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 2 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - - - - - - Size 100% Gas In Air=10,000 Units-Connection 0 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min -Background (max) Trip Average - Mud Type Lst Type - ---- Depth in / out YP (lb/100ft2) - 000 00 CementChtSilt C-4i C-4n 24 hr Max Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - N/U BOP PV - Footage - K. Harding D. Lowe ShClyst TuffGvlCoal cP - Gas Summary 0 0 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A N/A N/A Max @ ft Current - -- Date: Time: at 21:00 hrs. Nippling up BOP at report time. - in --Minimum Depth C-5n - - C-2 - - SPP (psi) Gallons/stroke-- TFABit Type Depth -- MBT 0' pH - 0 0 0 Siltst - - Units* Casing Summary Lithology (%) 00 0 Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 0 0 Cly 0 . . * 24 hr Recap: (max)(current) 0 0 Cly 0 Set AtSize Grade Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs 0 0 - - Units* Casing Summary Lithology (%) 0 MBT 0' pH - 0 0 0 Siltst - SPP (psi) Gallons/stroke-- TFABit Type Depth -- C-5n - - C-2 - in --Minimum Depth Time: - N/A N/A N/A Max @ ft Current - -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary 0 0 0 (current) R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP - - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Testing BOP PV 24 hr Max Weight 0 Hours C-3 00 CementChtSilt C-4i C-4n YP (lb/100ft2) - 000 - ---- Depth in / out Mud Type Lst Type Average --Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB 100% Gas In Air=10,000 Units-Connection 0 Condition - Bit # - - - - - - Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine ROP ROP (ft/hr) 4.23 @ Mud Data Depth 3-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l - Nippled up BOP with MPD and function tested rams. Rigged up to test BOP. Testing same at report time. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Finished testing BOP. Pulled 3-1/2" upper completion tubing free from seal assembly. Circulated bottoms up noting Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 54 4-Jun-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 4 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - - - - - - Size rams in preparation to pull 7" casing. Calibrating gas tetection equipment at report time. the hole with tubing, laying down in singles while observing sufficient hole fill. Began changing out and testing upper 4-1/2" x 7" 100% Gas In Air=10,000 Units-Connection 3822 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Type - ---- Depth in / out YP (lb/100ft2) - 6175 00 CementChtSilt C-4i C-4n 24 hr Max Weight 63 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Change/Test RAMS PV - Footage - R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP - Gas Summary 0 1796 920 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A N/A N/A Max @ ft Current - -- Date: Time: max gas of 1095 units. Mud weight equalized at 9.35 ppg. Broke circulation and monitored well on the trip tank. Static. Pulled out of 10 in --Minimum Depth C-5n 13086' - C-2 1095 - SPP (psi) Gallons/stroke-- TFABit Type Depth -- MBT 0' pH - 0 689 0 Siltst - - Units* Casing Summary Lithology (%) 7466 0 Unit Phone: 1099 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 6833 0 Cly 66419 . . * 24 hr Recap: (max)(current) - - Cly - Set AtSize Grade Unit Phone: - David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs - - - - Units* Casing Summary Lithology (%) - MBT 0' pH - - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -- C-5n - - C-2 - in --Minimum Depth Time: assembly. Displaced diesel with sea water on back side out of range of the gas equipment. Began pulling 7" casing out of the hole - N/A N/A N/A Max @ ft Current -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary - -- (current) R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP - - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - TOH W / 7" Casing PV 24 hr Max Weight - Hours C-3 -- CementChtSilt C-4i C-4n YP (lb/100ft2) - --- - ---- Depth in / out Mud Type Lst Type Average -0Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB 100% Gas In Air=10,000 Units-Connection - MD at report time. and laying down in singles. Noted zero point drifting in gas calibration. Recalibrated. Tripping out of the hole with casing at ~6,450' Condition - Bit # - - - - - - Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 5 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine ROP ROP (ft/hr) 4.23 @ Mud Data Depth 5-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - Chlorides mg/l - Calibrated and tested gas equipment while testing 7" RAMS. Speared 7" casing and released tie-back from seal Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued pulling out of the hole with 7" casing. Flow checked at 6865' MD. Static. Resumed pulling out of the hole Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 31 6-Jun-2014 12:00 AM Current Pump & Flow Data: - Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 6 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - - - - - - Size report time. Picking up 5" drill pipe while running in the hole in singles on closed displacement, filling pipe every 20 stands to 11,000' MD at 100% Gas In Air=10,000 Units-Connection 281 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min 13Background (max) Trip Average - Mud Type Lst Type - ---- Depth in / out YP (lb/100ft2) - 0100 -- CementChtSilt C-4i C-4n 24 hr Max Weight 28 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - RIH W/Cleanout Assembly PV - Footage - R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP - Gas Summary - 85 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A N/A N/A Max @ ft Current -- Date: Time: to surface and laid down casing equipment. Rigged up to run 5" drill pipe and made up scraper cleanout BHA as per baker. 25 in --Minimum Depth C-5n 7717' - C-2 53 SPP (psi) Gallons/stroke TFABit Type Depth -- MBT 0' pH - - 37 - Siltst - - Units* Casing Summary Lithology (%) 4190 - 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 269 - Cly 1401 . . * 24 hr Recap: (max)(current) 1168 - Cly 6089 Set AtSize Grade 90-670-4047Unit Phone: 135 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs 185 - - - Units* Casing Summary Lithology (%) 6 MBT 0' pH - - 219 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -- C-5n 7717' - C-2 171 in --Minimum Depth Time: cut drill line. Installed MPD Element. Began tripping out of the hole, installing super sliders. 19 N/A N/A N/A Max @ ft Current -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary - 537 130 (current) R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP - - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - TOH/Install Super Sliders PV 24 hr Max Weight 28 Hours C-3 -- CementChtSilt C-4i C-4n YP (lb/100ft2) - 3173 - Sea Water --- Depth in / out Mud Type Lst Type Average -13Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB 100% Gas In Air=10,000 Units-Connection 1337 Condition - Bit # - - - - - 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 7 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 34 Chlorides mg/l - Continued tripping into the hole with scraper and tagged top of 7" liner at 13059' MD. Circulated bottoms up. Slip and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued tripping out of the hole to surface and laid down cleanout BHA. Made up Bridge Plug and ran in the hole Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 300.00 2 8-Jun-2014 12:00 AM Current Pump & Flow Data: 60 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 8 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - 10.0 - - - 10.50 Size 100% Gas In Air=10,000 Units-Connection 37 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min 13Background (max) Trip Average - Mud Type Lst Type - Sea Water 9.5-26 Depth in / out YP (lb/100ft2) 9.60 030 -- CementChtSilt C-4i C-4n 24 hr Max Weight 1 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Displace to Mill Fluid PV - Footage - R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP 9 Gas Summary - 49 18 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) N/A N/A N/A Max @ ft Current -- Date: Time: to ~12,955' MD. Set Bridge Plug and tested to 2500 psi. Beginning displacement to 10.5 ppg Milling fluid at report time. 8 in --Minimum Depth C-5n - - C-2 16 SPP (psi) Gallons/stroke TFABit Type Depth -44 MBT 0' pH - - 17 - Siltst 300 72 Units* Casing Summary Lithology (%) 145 - 90-670-4047Unit Phone: 17 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 18 - Cly 152 . . * 24 hr Recap: (max)(current) 295 - Cly 950 Set AtSize Grade 90-670-4047Unit Phone: 38 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs 37 - - - Units* Casing Summary Lithology (%) 0 MBT 0' pH - - 29 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -48 C-5n 12900' - C-2 39 in --Minimum Depth Time: Job and pulled out of the hole to surface. Picked up Milling BHA and Whip Stock. Began running in the hole. Shallow test MWD. 2 N/A N/A N/A Max @ ft Current -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) Gas Summary - 76 33 (current) R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP 11 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - RIH W / Whip Stock PV 24 hr Max Weight 0 Hours C-3 -- CementChtSilt C-4i C-4n YP (lb/100ft2) 8.90 000 - Sea Water 4.6-30 Depth in / out Mud Type Lst Type Average -2Background (max) Trip -- Avg Min Comments RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB 100% Gas In Air=10,000 Units-Connection 251 Tripping in to ~4250' MD at report time. Condition - Bit # - 10.0 - 10.50 - 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 9 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 0 Chlorides mg/l 300.00 Continued displacing sea water to Milling fluid. Max gas of 39 units encountered during displacement. Pumped Dry Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued running in the hole with Whipstock/Milling assembly to 12697' MD, filling pipe every 20 stands. Washed Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 300.00 3 10-Jun-2014 12:00 AM Current Pump & Flow Data: 590 Max ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 10 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - 10.0 - 10.50 - 10.50 Size with traces of silt, calcite and occasional bioclastic material. changing shaker screens at report time. Lithology consists of 90% very fine grain unconsolidated sandstone and 10% siltstone from trucks and Ball Mill. Milled ahead to 12958' MD. Pulling off bottom to 12924' MD and lowering flow rate to 88 GPM while 100% Gas In Air=10,000 Units-Connection 16 Tools - API FL Chromatograph (ppm) --- WOB -- Avg Min Comments RPM ECD (ppg) ml/30min 5Background (max) Trip Average - Mud Type Lst 90% Type - Sea Water 5.7-36 Depth in / out YP (lb/100ft2) 9.80 000 -- CementChtSilt C-4i C-4n 24 hr Max Weight 5 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Milling out Window PV - Footage - R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 9 Gas Summary - 5 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 5.0 Flow In (gpm) Flow In (spm) 12935' 12958' 23' Max @ ft Current -3.0 Date: Time: down to 12900' MD at 645 GPM. Began milling at 12935' MD, losing fluid over shakers during process. Occasionally taking on fluid 5 in --Minimum Depth C-5n 12956' - C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 3.050 MBT 0' pH - - 0 - Siltst 203 48 Units* Casing Summary Lithology (%) 0 10% 158 - 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize Grade (max)(current) 27 - Cly 415 . . * 24 hr Recap: (max)(current) Surface Casing 51 - Cly 798 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 103 - 13.38'' - - Units* Casing Summary Lithology (%) 0 - MBT 0' pH - - 3 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 0.548 C-5n 12977' - C-2 22 in --Minimum Depth Time: 511 GPM. Pumped bit balling sweep and returned to drilling. Milled out to 12977' MD. Washed and reamed through window. 4 12958' 12977' 19' Max @ ft Current -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 9 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 10 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Lay Down Milling BHA PV 24 hr Max 68.0 Weight 4 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.80 000 - Milling Fluid 6.112977'33 Depth in / out Mud Type Lst Intermediate Casing Type Average -0Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 32 hole. Laying down heavy weight drill pipe and preparing gas detection equipment for calibration and testing at report time. of the hole to 12389' MD. Monitored the well while slipping and cutting drill line. Pumped 35 bbl dry job and began pulling out of the Pulled out of the hole to 12861' MD. Circulated and conditioned mud to 10.5 PPG. Performed Leak Off Test to 16.6 PPG. Pulled out 1565' 114' Condition - Bit # - 8.0 - 10.50 - 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 11 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 2 Chlorides mg/l 300.00 Changed out shaker screens. Noted vast imrovement in performance and fluid management at milling rates of Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued laying down BHA. Performed 4 point calibration and testing on gas equipment while rig tested BOPE. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 300.00 - 12-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 12 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # - 8.0 - 10.50 - 10.50 Size 1565' 114' 100% Gas In Air=10,000 Units-Connection - Tools - API FL Chromatograph (ppm) --- WOB Conductor Line -- Avg Min Comments - RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Intermediate Casing Type - Milling Fluid 6.312977'28 Depth in / out YP (lb/100ft2) 9.90 --- -- - CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Rig Maintenace PV - Footage - R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 9 40.0 Gas Summary - -- (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 12977' 12977' 0' Max @ ft Current -- Date: Time: Perfoming rig maintenance and waiting on parts for accumulator at report time. 1 in --Minimum Depth C-5n - - C-2 5 SPP (psi) Gallons/stroke TFABit Type Depth 0.546 - MBT 0' pH - - - - Siltst 13.38'' - - Units* Casing Summary Lithology (%) -36 - 90-670-4047Unit Phone: - David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 65.0 - Grade -12953' 20' 9.63'' (max)(current) Surface Casing - - Cly 45 . . * 24 hr Recap: (max)(current) Surface Casing 1477 - Cly 53995 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 36 - 13.38'' 461 108 Units* Casing Summary Lithology (%) - - MBT 0' pH 0.739 - 33 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 0.547 C-5n 1470' - C-2 475 in --Minimum Depth Time: Shallow pulse tested MWD. Noted 475 units of gas during test. Washing one stand through 13-3/8" and 9-5/8" liner lap with a 5 12977' 12977' 0' Max @ ft Current -- Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 42 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 10 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - TIH / Shallow Test MWD PV 24 hr Max 68.0 Weight - Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 --- - Milling Fluid 6.112977'30 Depth in / out Mud Type Lst Intermediate Casing Type Average 475135Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -12977' - WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 285 background gas of 135 units at report time. 1565' 114' Condition - Bit # 2 8.0 8.75 10.50 Smith XR+ Mill Tooth 10.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 13 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Jun-2014 12:00 AM Current Pump & Flow Data: 980 Max - Chlorides mg/l 300.00 Repaired and tested accumulator. Made up BHA and began tripping in the hole. Ran in the hole to 1470' MD. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued washing through liner lap and resumed tripping in the hole as per outlined tripping program, filling drill Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 300.00 22 14-Jun-2014 12:00 AM Current Pump & Flow Data: 2375 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 14 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # 2 10.0 8.75 10.50 Smith XR+ Mill Tooth 10.50 Size with LSND. On Bottom drilling at 18:18 hrs. Drilling ahead to 13088' MD at report time. 1565' 114' 100% Gas In Air=10,000 Units-Connection 117 Tools - API FL Chromatograph (ppm) -12977' - WOB Conductor Line -- Avg Min Comments - RPM ECD (ppg) ml/30min 41Background (max) Trip Average 139 Mud Type Lst 90% Intermediate Casing Type - LSND 3.213088'21 Depth in / out YP (lb/100ft2) 9.50 030 -- - CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 64 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV - Footage - R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 14 40.0 Gas Summary - 31 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 95.0 Flow In (gpm) Flow In (spm) 12977' 13088' 111' Max @ ft Current 13055'55.0 Date: Time: pipe every 20 stands to 12592' MD. Installed and tested RCD Element. Continued in the hole to 12895' MD. Diplaced Milling fluid 24 in --Minimum Depth C-5n 1580' 2.0 C-2 139 SPP (psi) Gallons/stroke TFABit Type Depth 1.545 - MBT 0' pH 0.739 - 17 - Siltst 13.38'' 558 132 Units* Casing Summary Lithology (%) 1 10% 1739 - 90-670-4047Unit Phone: 15 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 65.0 - Grade -12953' 20' 9.63'' (max)(current) Surface Casing 469 - Cly 14737 . . * 24 hr Recap: (max)(current) Surface Casing 322 - Cly 5291 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 15% 587 - 13.38'' - - Units* Casing Summary Lithology (%) 1 - MBT 0' pH - - 17 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 3.843 C-5n 13149' - C-2 74 in --Minimum Depth Time: and conditioned the hole clean. Weighed up fluid from 10.5 ppg to 11 ppg. Monitored well - Static. Changed out RCD element and 14 13088' 13160' 72' Max @ ft Current 13113'45.0 Date: Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 96.0 Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 42 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 11 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - L/D BHA - Monitor Well PV 24 hr Max 68.0 Weight 35 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.50 050 - LSND 4.113160'20 Depth in / out Mud Type Lst 85% Intermediate Casing Type Average 740Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) --- WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 177 pumped 15 ppg dry job. Pulled out of the hole to surface. Laid down BHA. Monitoring well on the trip tank at report time. 1565' 114' Condition - Bit # - 11.0 - 11.00 - 11.00 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 15 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 21 Chlorides mg/l 600.00 Caught frequent spot samples while drilling ahead to TD at 13160' MD. (85% sandstone, 15% Siltstone. Circulated Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Made up BHA #6 and ran in the hole to 1548' MD. Shallow Tested MWD and function tested reamer. Good tests. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 10 16-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 16 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # 6 11.0 8.75 11.00 Mi616 PDC 11.00 Size Continued tripping in the hole to 12865' MD. Slipping and cutting drill line at report time. 1565' 114' 100% Gas In Air=10,000 Units-Connection 61 Tools - API FL Chromatograph (ppm) -13160' - WOB Conductor Line -- Avg Min Comments - RPM ECD (ppg) ml/30min 0Background (max) Trip Average 20 Mud Type Lst Intermediate Casing Type - LSND 4.113160'20 Depth in / out YP (lb/100ft2) 9.50 000 -- - CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 10 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Slip / Cut Drill Line PV - Footage - R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 11 40.0 Gas Summary - 20 0 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 13160' 13160' 0' Max @ ft Current -- Date: Time: Continued running in the hole to 8145' MD. Adjusted drill pipe/Super Slider placement to accommodate for RCD Element. 7 in --Minimum Depth C-5n 12679' - C-2 20 SPP (psi) Gallons/stroke TFABit Type Depth 3.843 - MBT 0' pH 0.902 - 91 - Siltst 13.38'' - - Units* Casing Summary Lithology (%) 2146 - 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 65.0 - Grade -12953' 20' 9.63'' (max)(current) Surface Casing 76 - Cly 935 . . * 24 hr Recap:Ran in the hole through the window and downlinked to the MWD tools. Reamed down from 13122' MD to 13160' Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 102 17-Jun-2014 12:00 AM Current Pump & Flow Data: 881 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 17 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition - Bit # 6 11.0 8.75 10.30 Mi616 PDC 10.30 Size 1565' 114' 100% Gas In Air=10,000 Units209Connection 562 Tools - API FL Chromatograph (ppm) -13160' - WOB Conductor Line -- Avg Min Comments - RPM ECD (ppg) ml/30min 61Background (max) Trip Average - Mud Type Lst Intermediate Casing Type - LSND 3.513620'25 Depth in / out YP (lb/100ft2) 9.60 2312 -- - CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 155 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - E-Line PV - Footage - K. Harding / A. Dorr ShClyst TuffGvlCoal cP 11 40.0 Gas Summary - 130 23 (current) Avg to0' Yesterday's Depth: Current Depth: 24 Hour Progress: 120.0 Flow In (gpm) Flow In (spm) 13160' 13620' 460' Max @ ft Current -27.8 Date: Time: MD, drilled from 13160' to 13620', circulated bottoms up and began rigging up e-line. 33 in --Minimum Depth C-5n 13406' - C-2 194 SPP (psi) Gallons/stroke TFABit Type Depth 6.546 - MBT 0' pH 0.902 - 45 - Siltst 13.38'' 208 50 Units* Casing Summary Lithology (%) 102108 - 90-670-4047Unit Phone: 21 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters Set AtSize 65.0 - Grade -12953' 20' 9.63'' (max)(current) Surface Casing 1069 - Cly 16088 . . * 24 hr Recap: (max)(current) Surface Casing 7468 - Cly 75542 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 607 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 8410 - 13.38'' 646 154 Units* Casing Summary Lithology (%) 132 - MBT 14261' pH 0.902 - 1556 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 10.045 C-5n 14113' 69.2 C-2 1362 in --Minimum Depth Time: 87 13620' 14261' 641' Max @ ft Current 14188'73.8 Date: Avg to13125' Yesterday's Depth: Current Depth: 24 Hour Progress: 138.5 Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 2553 650 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 13 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Drilling PV 24 hr Max 68.0 Weight 787 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 7328472 - LSND 3.514090'25 Depth in / out Mud Type Lst Intermediate Casing Type Average -145Background (max) Trip 11.7311.85 Avg Min Comments - RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD API FL Chromatograph (ppm) -13160' - WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 8686 1565' 114' Condition - Bit # 6 12.0 8.75 10.25 Mi616 PDC 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.21 Doyon 19 Report For: Morning Report Report # 18 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Jun-2014 12:00 AM Current Pump & Flow Data: 2688 Max 804 Chlorides mg/l 500.00 Ran in hole with E-line and gyro tools, pulled and rigged down the wireline tools, drilled ahead to 14261' Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 14261 to 15224'. Reached TD at 23:40 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 550.00 1014 19-Jun-2014 12:00 AM Current Pump & Flow Data: 2983 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 19 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 12.20 Doyon 19 Report For: Condition - Bit # 6 11.5 8.75 10.30 Mi616 PDC 10.20 Size 1565' 114' 100% Gas In Air=10,000 Units-Connection 15280 Tools Gamma, Resistivity, ECD API FL Chromatograph (ppm) -13160' - WOB Conductor Line 11.7311.84 Avg Min Comments - RPM ECD (ppg) ml/30min 120Background (max) Trip Average - Mud Type Lst Intermediate Casing Type - LSND 4.015134'25 Depth in / out YP (lb/100ft2) 9.70 101369112 -- - CementChtSilt C-4i C-4n 24 hr Max 68.0 Weight 912 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - TD PV - Footage - K. Harding / A. Dorr ShClyst TuffGvlCoal cP 12 40.0 Gas Summary - 4716 1034 (current) Avg to14261' Yesterday's Depth: Current Depth: 24 Hour Progress: 97.5 Flow In (gpm) Flow In (spm) 14261' 15224' 963' Max @ ft Current 14755'67.4 Date: Time: 152 in --Minimum Depth C-5n 15203' - C-2 2335 SPP (psi) Gallons/stroke TFABit Type Depth 13.844 - MBT 15224' pH 0.902 - 1899 - Siltst 13.38'' 650 155 Units* Casing Summary Lithology (%) 1718203 - 90-670-4047Unit Phone: 1065 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters Set AtSize 65.0 - Grade -12953' 20' 9.63'' (max)(current) Surface Casing 13235 - Cly 102947 . . * 24 hr Recap: (max)(current) Surface Casing 4842 - Cly 35971 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 444 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 1328 - 13.38'' 121 29 Units* Casing Summary Lithology (%) 67 - MBT - pH 0.902 - 719 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.044 C-5n - - C-2 704 in --Minimum Depth Time: window and weighted up to 11.6. Continued to pull out of the hole. 60 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 1829 422 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 11 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - POOH PV 24 hr Max 68.0 Weight 209 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 7920267 - LSND 2.815134'25 Depth in / out Mud Type Lst Intermediate Casing Type Average -8Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -13160' - WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 5561 1565' 114' Condition - Bit # 6 16.0 8.75 11.45 Mi616 PDC 11.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 20 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Jun-2014 12:00 AM Current Pump & Flow Data: 265 Max 348 Chlorides mg/l 500.00 Circulated 2 bottoms up, circulated and conditioned the mud from 10.2ppg to 10.7ppg. Pulled out to the Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Surface Casing - - Cly 71 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 37 - 13.38'' - - Units* Casing Summary Lithology (%) - - MBT - pH 0.902 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 14.050 C-5n - - C-2 7 in --Minimum Depth Time: 7" liner. 3 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - -- (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 12 - Footage - Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Running 7" Liner PV 24 hr Max 68.0 Weight - Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.70 --- - LSND 2.715224'26 Depth in / out Mud Type Lst Intermediate Casing Type Average -0Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -13160' - WOB Conductor Line 100% Gas In Air=10,000 Units-Connection - 1565' 114' Condition - Bit # 6 16.0 8.75 11.45 Mi616 PDC 11.50 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 21 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - Chlorides mg/l 500.00 Continued to pull out of the hole and lay down BHA. Rigged up to run in with 7" liner. Began running in hole with 7 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Surface Casing 72 - Cly 897 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 11 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 269 - 13.38'' - - Units* Casing Summary Lithology (%) 3 - MBT - pH 0.902 - 12 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 15.055 C-5n - - C-2 20 in --Minimum Depth Time: 7 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 26 10 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 14 2064' Footage 32.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Running 7" Liner PV 24 hr Max 68.0 Weight 19 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 9.60 -10 - - LSND 2.815224'24 Depth in / out Mud Type Lst Intermediate Casing Type Average -8Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -13160' 15224' WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 60 1565' 114' Condition 0-1-WT-G-X-I-NO-TD Bit # 6 16.0 8.75 11.45 Mi616 PDC 11.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 22 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 19 Chlorides mg/l 550.00 Continued running in with 7" liner. 7 Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Surface Casing 2779 - Cly 36474 Set AtSize 65.0 - Grade -12953' 20' 9.63'' 90-670-4047Unit Phone: 100 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 4389 - 13.38'' - - Units* Casing Summary Lithology (%) 42 - MBT - pH 0.902 - 290 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 458 in --Minimum Depth Time: weight to 11.0ppg, cemented per Schumberger, saw 10 bbls of cement back to the surface, rigged down the cement equipment. 63 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 40.0 Gas Summary - 517 123 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP - 2064' Footage 32.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Displacing to Seawater PV 24 hr Max 68.0 Weight 354 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - 178721 - Brine -15224'- Depth in / out Mud Type Lst Intermediate Casing Type Average 4583Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -13160' 15224' WOB Conductor Line 100% Gas In Air=10,000 Units-Connection 2120 Pumped 34 bbl spacer and displaced to seawater. 1565' 114' Condition 0-1-WT-G-X-I-NO-TD Bit # 6 - 8.75 8.40 Mi616 PDC 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 23 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 290 Chlorides mg/l 4500.00 Continued running in with 7" liner, rotating liner down from 14390' to 15224'. Circulated and reduced mud we Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: (max)(current) Intermediate 1 Casing 7 - Cly 74 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 4389 - 9.63'' - - Units* Casing Summary Lithology (%) 42 - MBT - pH 0.902 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 55 in --Minimum Depth Time: rig and repaired hydraulic hose, continued to pull out. Drained the stack and began rigging up to run 7" casing. 3 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - -- (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 2064' Footage 32.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - R/U to Run 7" Casing PV 24 hr Max 40.0 Weight 354 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - 178721 - Brine -15224'- Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) -13160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 3 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 6 - 8.75 8.40 Mi616 PDC 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 24 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 24-Jun-2014 12:00 AM Current Pump & Flow Data: - Max 290 Chlorides mg/l 4500.00 Finished displacing well with 8.35ppg seawater. Pulled out and laid down 5" drill pipe to 9008', lubricated rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 369 0 3661582121 - (max)(current) Intermediate 1 Casing 19 - Cly 711 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters 52 - 9.63'' - - Units* Casing Summary Lithology (%) - - MBT - pH 0.902 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 10 in --Minimum Depth Time: freeze protect the well, stripped in and landed hanger at 12776'. 2 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - -- (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 2064' 6.125 0.296 Footage 32.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - P/U 4" DP PV 24 hr Max 40.0 Weight - Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - --- 120.0 Mdi513 PDC Brine - 15224' 15224'- Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 5 4 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 - 8.75 8.40 Mi616 PDC 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 25 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 25-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - Chlorides mg/l 4500.00 Continued to run 7" casing tie-back, pumped 308 barrels of inhibited seawater and 170 barrels of diesel to rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to pick up 4" drill pipe, tested BOPE, rigged down test equipment, picked up 4" drill pipe and rack back Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 4500.00 - 26-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 26 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 - 8.75 8.40 Mi616 PDC 8.40 Size 4 12953' 1565' 100% Gas In Air=10,000 Units-Connection - Tools - API FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - RPM ECD (ppg) ml/30min 0Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Brine - 15224' 15224'- Depth in / out YP (lb/100ft2) - --- -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - P/U 4" DP PV 2064' 6.125 0.296 Footage 32.20 K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 26.0 Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 15224' 15224' 0' Max @ ft Current -- Date: Time: back into the derrick. 1 in --Minimum Depth C-5n - - C-2 4 SPP (psi) Gallons/stroke TFABit Type Depth -27 - MBT - pH 0.902 - - - Siltst 9.63'' - - Units* Casing Summary Lithology (%) -35 - 90-670-4047Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing - - Cly 144 Bottoms Up Time 369 0 3661582121 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 380 0 3778582111 - (max)(current) Intermediate 1 Casing - - Cly - Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: - Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs - - 9.63'' - - Units* Casing Summary Lithology (%) - - MBT - pH 0.902 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 - in --Minimum Depth Time: running in hole with 3.5" drill pipe.. Shallow tested MWD equipment, test was good, continued running in the hole while filling - 15224' 15224' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - -- (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 2064' 6.125 0.296 Footage 32.20 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - P/U 4" DP PV 24 hr Max 40.0 Weight - Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - --- 120.0 Mdi513 PDC Brine - 15224' 15224'- Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip -- Avg Min Comments - RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection - 4 pipe every 20 stands. Calibrated gas equipment. Sample catcher arrived for production zone. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 - 8.75 8.40 Mi616 PDC 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 27 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 27-Jun-2014 12:00 AM Current Pump & Flow Data: - Max - Chlorides mg/l 4500.00 Continued to pick up 4" drill pipe and rack back into the derrick, made up BHA per Schlumberger, began p Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Lime Cor Solids (lb/bbl)% 1.79 14.0 Ran in the hole to 15109' MD, tested casing to 3500 psi, test was good, slipped and cut drill line, displaced from at Density (ppg) out (sec/qt) Viscosity 976 28-Jun-2014 12:00 AM Current Pump & Flow Data: 3000 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 28 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 9.40 Mi616 PDC 9.40 Size 4 the gas stabilized to an average of 1040 units. Drilled to 15367'. saw that it was static, installed RCD element, began drilling and observed a max gas of 9902u. Once we circulated new footage footage saw 1493 units of gas, circulated and conditioned mud and performed a leak off test, observed well for 30 minutes and 12953' 1565' 100% Gas In Air=10,000 Units9902Connection 118208 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 670Background (max) Trip Average - Mud Type Lst 95% Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 5.2 15224' 15244'8 Depth in / out YP (lb/100ft2) 1.38 2317025 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 1264 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - P/U 4" DP PV 2064' 6.125 0.296 Footage 32.20 K. Harding / D. Lowe ShClyst TuffGvlCoal cP 14 26.0 Gas Summary - 20780 3084 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: 180.4 Flow In (gpm) Flow In (spm) 15224' 15367' 143' Max @ ft Current 15226'92.9 Date: Time: seawater to 9.4ppg Mineral-Oil based mud, drilled out shoe track and 20' of new formation to 15244' MD, while circulating up new 189 in --Minimum Depth C-5n 15244' 76.0 C-2 9902 SPP (psi) Gallons/stroke TFABit Type Depth 4.348 - Oil / Water - Alkal 0.902 - 9271 - Siltst 9.63'' 193 46 Units* Casing Summary Lithology (%) 79 5% 12395 - 907-670-4047Unit Phone: 2872 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 114645 - Cly 469641 Bottoms Up Time (mins) 383 0 3803495112 83 Volumes Hole Volume (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Cor Solids (lb/bbl)% 2.08 12.7 Circulated and conditioned while troubleshooting MWD tools, resumed drilling from 15365 to 15391', cir Density (ppg) out (sec/qt) Viscosity 2581 - 29-Jun-2014 12:00 AM Current Pump & Flow Data: 2987 Max - ROP ROP (ft/hr) 4.23 @ Mud Data HTHP FL Avg Min Lime Depth Morning Report Report # 29 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 24 hr MaxAvg -15367' 96% Rig Activity: 10.74 Doyon 19 Report For: Tools Gamma, Resistivity, ECD 10.1610.55 Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 9.35 Mi616 PDC 9.30 Size 120.0 4 24 hours. 12953' 1565' 100% Gas In Air=10,000 Units-Connection 5253 Chromatograph (ppm) 28.013160' 15224' Surface Casing Comments - (max)(current) Mud RPM ECD (ppg) ml/30min 945Background - (max) Trip Mdi513 PDC Versapro 4.8 Average Lst 100% Intermediate 2 Casing Type 15244'12 Depth in / out YP (lb/100ft2) 6.125 0.296 Mud Type 129597122 -- CementChtSilt C-4i C-4n 4017 Hours C-3 Footage 15224' Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV 2064' K. Harding / D. Lowe ShClyst 40.0 Weight 1.60 WOB TuffGvlCoal cP 15 26.0 - Intermediate 1 Casing 32.20 - Gas Summary - 1009 181 (current) Yesterday's Depth: Current Depth: 24 Hour Progress: 127.1 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 15367' 16691' 1324' Max @ ft Current 16169'91.8 Date: circulated and conditioned while troubleshooting MWD tools, resumed drilling from 15391' to 16691'. 55 barrels were lost over 969 in --Minimum Depth C-5n 16139' 66.9 C-2 2563 TFABit Type Depth 4.052 - Oil / Water 16691' Alkal 0.902 472 - Siltst 264 9.63'' 189 45 Units* Casing Summary Lithology (%) 68.0 - Grade 83293 - 907-670-4047Unit Phone: 184 Tyler Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 15224' 13.38'' 7" 9051 - Cly 226612 Bottoms Up Time (mins) 410.9 50 4418537126.2 83 Volumes Hole Volume (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Hole Volume (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Cly 601322 Bottoms Up Time (mins) 420.44 49 4665551130.85 Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 15224' 13.38'' 7" 57593 100285 - 907-670-4047Unit Phone: 845 Tyler Dretke 186 45 Units* Casing Summary Lithology (%) 10% 68.0 - Grade 318 - Depth 4.052 - Oil / Water 17207' Alkal 0.902 9.63'' 17068' 91.0 C-2 9268 -Minimum Depth C-5n 2857 - Maximum drilled from 17029' to 17150'. At 17150, circulated gas out of well, observed a max gas of 9268 units, shut the pumps down and 1242 - 16691' 17207' 516' Max @ ft Current 16926'81.5 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 128.6 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke - 5852 897 (current) 26.0 - Intermediate 1 Casing 32.20 - Siltst 40.0 Weight 1.50 WOB TuffGvlCoal cP 14 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV 2064' C-3 Footage 15224' ShClyst C-4i C-4n Gas Summary 104 Volumes 149705141 -- YP (lb/100ft2) 6.125 0.296 Mud Type Hours in TFABit Type 90% Intermediate 2 Casing Type 17150'12 Depth in / out Cht Silt Mdi513 PDC Versapro 4.5 Average - (max) Trip (max)(current) Mud RPM ECD (ppg) ml/30min 3700Background Chromatograph (ppm) 28.013160' 15224' Surface Casing Comments - Lst Cement 100% Gas In Air=10,000 Units-Connection 35225 4 circulated up a max gas of 8754 units. Drilled from 17150' to 17207'. flow checked the well, gained 10 barrels, circulated and conditioned while troubleshooting power steerable downlink, at 22:40 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 9.20 Mi616 PDC 9.20 Size 120.0 Rig Activity: 10.63 Doyon 19 Report For: Tools Gamma, Resistivity, ECD 10.1510.56 K. Harding / D. Lowe North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 24 hr MaxAvg -16691' Depth Morning Report Report # 30 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips ROP ROP (ft/hr) 4.23 @ Mud Data HTHP FL Avg Min Lime 30-Jun-2014 12:00 AM Current Pump & Flow Data: 2958 Max - 96% - 5292 Density (ppg) out (sec/qt) Viscosity Cor Solids (lb/bbl)% 1.95 10.8 Driled from 16691' t o 17029'. Was unable to pwer steerable tool, rotated off-bottom while switching modes, cir 3306 . . * 24 hr Recap: Cor Solids (lb/bbl)% 1.95 13.5 Circulated and conditioned gas out of the hole, during this time gas decreased from 8039 units to 2000 units. rea 22197 Density (ppg) out (sec/qt) Viscosity - 27867 1-Jul-2014 12:00 AM Current Pump & Flow Data: 2932 Max - 96% ROP ROP (ft/hr) 4.23 @ Mud Data HTHP FL Avg Min Lime Depth Morning Report Report # 31 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 24 hr MaxAvg -17207' Rig Activity: 10.69 Doyon 19 Report For: Tools Gamma, Resistivity, ECD 10.3910.56 R. Bjorhus / D. Lowe Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 9.40 Mi616 PDC 9.40 Size 120.0 4 reading of 9894units of seven barrels. Drilled from 17207' to 17759', troubleshoot downlinks to directional tool, while circulating observed a maximum 12953' 1565' -Connection 187235 Comments - Lst Cement 100% Gas In Air=10,000 Units ECD (ppg) ml/30min 1855Background Chromatograph (ppm) 28.013160' (max) Trip (max)(current) Average - 90% Intermediate 2 Casing Type 17759'14 Depth in / out Cht Silt 0.296 Mud Type Hours in TFABit Type Mdi513 PDC Versapro 15224' 747 -- YP (lb/100ft2) 4.6 Mud RPM Gas Summary 110 Volumes 7364362 C-3 Footage 15224' ShClystSs Ratio C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV 2064' 40.0 Weight 1.50 WOB TuffGvlCoal cP 16 26.0 - Intermediate 1 Casing 32.20 - Siltst Surface Casing (current) C-4i Yesterday's Depth: Current Depth: 24 Hour Progress: 125.3 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 17207' 17759' 552' Max @ ft Current 17308'94.6 Date: Performed a dynamic flow check on pit 5 using MPD. ECD at the start was 10.35, decreasing to 10.28 at the end. Saw a gain 4545 --Minimum Depth C-5n 16924 - Maximum - 17759' - C-2 9894 Depth 4.050 - Oil / Water 17759' Alkal 0.902 9.63'' 6.125 1967 - 191 45 Units* Casing Summary Lithology (%) 10% 68.0 - Grade 319494 - 907-670-4047Unit Phone: 6761 Tyler DretkeReport By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 15224' 13.38'' 7" 138499 Cly 610788 Bottoms Up Time (mins) 431.1 59 4936567.15 136.04 Hole Volume (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 42474 6978 C-4n . . * 24 hr Recap: (lb/bbl)% 1.95 14.0 Circulated and conditioned hole while downlinking to the directional tool, cut the mud weight from 10.2ppg to 9.4ppg rea 4823 Density (ppg) out (sec/qt) Viscosity - 3952 2-Jul-2014 12:00 AM Current Pump & Flow Data: 2899 Max - 96%4.23 @ Mud Data HTHP FL Avg Min Lime Cor Solids Morning Report Report # 32 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips MWD Summary 24 hr MaxAvg -17207' Depth ROP ROP (ft/hr) R. Bjorhus / D. Lowe North Slope, AK Alpine Job No.: Daily Charges: Total Charges: 120.0 Rig Activity: 10.69 Doyon 19 Report For: Tools Gamma, Resistivity, ECD 10.3910.56 17680' and then back to bottom, encountered multiple tightspots, drilled from 17774' to 18275'. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75Mi616 PDC Size Comments - Lst Cement 100% Gas In Air=10,000 Units 589 ECD (ppg) ml/30min 1750Background Chromatograph (ppm) 28.013160' (max) Trip (max)(current) -7315Connection 18001'12 Depth in / out Cht Silt 4 9.409.40 0.296 Mud Type Hours in TFABit Type Mdi513 PDC Versapro 15224' -- YP (lb/100ft2) 4.7 Mud RPM C-3 Gas Summary 107 Volumes 6702052 Footage 15224' ShClyst 26.0 - Intermediate 1 Casing 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV 2064' 40.0 Weight 1.50 WOB TuffGvlCoal cP 14 - Siltst Surface Casing Intermediate 2 Casing C-4i 23081 Yesterday's Depth: Current Depth: 24 Hour Progress: 118.6 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 17759' 18274' 515' Max @ ft Current 18062'93.8 Date: Drilled from 17759' to 17774', circulated and conditioned the mud while circulating out the 10.2ppg mud, Reamed from 17774 to 1162Average Minimum Depth C-5n 3236 - Maximum -- 100.2 C-2 7315 (current) Alkal 0.902 9.63'' 6.125 18154' - 186 45 Annular Volume (bbls) Lag Correction (bbls) Depth 78/2254 - Oil / Water 17759' 68.0 - Grade Cly Drillstring Capacity (bbls) Type 907-670-4047Unit Phone: 2013 Tyler Dretke 759 Set AtSize 15224' 13.38'' 7" 25812 Units* Casing Summary Lithology (%) 10% Hole Volume (bbls) Report By:Logging Engineers:T. Dretke / J. Tiegs 58655 -- Bottoms Up Time (mins) 441.94 33 4721583.26 141.32 90% Bottoms Up Strokes 8339 1921 C-4n 553352 . . * 24 hr Recap: C-4n 572176 Bottoms Up Time (mins) 462.24 57 5168613151.2 100% Bottoms Up Strokes Hole Volume (bbls) Report By:Logging Engineers:T. Dretke / J. Tiegs 184819 12558 825 Set AtSize 15224' 13.38'' 7" 63459 Units* Casing Summary Lithology (%) Drillstring Capacity (bbls) Type 907-670-4047Unit Phone: 1139 Tyler Dretke 696 183 44 Annular Volume (bbls) Lag Correction (bbls) Depth 80/2053 - Oil / Water 19282' 18561' 18541' 73809226 (current) Alkal 0.902 9.63'' 6.125 68.0 148 Maximum 138229 115.0 C-2 2443Average 18274' 19282' 1008' Max @ ft Current 19028'91.4 Date: Yesterday's Depth: Current Depth: 24 Hour Progress: 120.1 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke C-4i 42773 C-5n 3652 1196 Siltst Surface Casing Intermediate 2 Casing - Cly 0% 2064' 40.0 Weight 1.60 WOB cP 13 Grade 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling Ahead PV 15224' ShClyst 26.0 - Intermediate 1 Casing Coal Volumes 3501488 Minimum Depth YP (lb/100ft2) 4.6 Mud RPM C-3 Gas Summary 117 Mud Type Hours in TFABit Type Mdi513 PDC Versapro 15224' Footage 19145'12 Depth in / out Cht Silt 4 9.509.40 0.296 -8753Connection (max) Trip (max)(current) ECD (ppg) ml/30min 1566Background Chromatograph (ppm) 28.013160' 100% Gas In Air=10,000 Units 329 170393 Tuff Comments - Lst CementGvl - Size - 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75Mi616 PDC Alpine Job No.: Daily Charges: Total Charges: 120.0 Rig Activity: Doyon 19 Report For: Tools 24 hr MaxAvg -18274' Depth ROP ROP (ft/hr) Gamma, Resistivity, ECD Morning Report Report # 33 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips R. Bjorhus / D. Lowe North Slope, AK @ Mud Data HTHP FL Avg Min Lime Cor Solids MWD Summary -- 3-Jul-2014 12:00 AM Current Pump & Flow Data: 2993 Max - 96%4.23 848 9718 Density (ppg) out (sec/qt) Viscosity (lb/bbl)% 2.08 15.0 Drilled from 18274' to 19282'. Lost 70 barrels downhole. rea 6539 . . * 24 hr Recap: (lb/bbl)% 2.08 14.0 Drilled ahead from 19282' to 19946'. Weighted up from a 9.4 to 9.5ppg, circulated and conditioned while rea 2140 Density (ppg) out (sec/qt) Viscosity - 3164 4-Jul-2014 12:00 AM Current Pump & Flow Data: 3345 Max - 96%4.23 @ Mud Data HTHP FL Avg Min Lime Cor Solids MWD Summary -- Morning Report Report # 34 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips R. Bjorhus / D. Lowe North Slope, AK 24 hr MaxAvg -18274' Depth ROP ROP (ft/hr) Gamma, Resistivity, ECD Alpine Job No.: Daily Charges: Total Charges: 120.0 Rig Activity: Doyon 19 Report For: Tools - 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 Comments - Lst CementGvl - 100% Gas In Air=10,000 Units 141 -- Tuff ECD (ppg) ml/30min 159Background Chromatograph (ppm) 28.013160' (max) Trip (max)(current) -9145Connection Depth in / out Cht Silt 4 9.509.50 0.296 Size Mi616 PDC Mud Type Hours in TFABit Type Mdi513 PDC Versapro19947' YP (lb/100ft2) 4.3 Mud RPM C-3 Gas Summary 119 155539 Minimum 15224' ShClyst 26.0 - Intermediate 1 Casing Coal 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circ and Condition PV Weight 1.30 WOB cP 14 Grade 15224' Footage 13 Siltst Surface Casing Intermediate 2 Casing - Cly 0% 40.0 C-4i 22032 C-5n 1990 649 Yesterday's Depth: Current Depth: 24 Hour Progress: 144.8 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke 19282' 19947' 665' Max @ ft Current 19359'72.2 Date: troubleshooting MWD. Lost 100 barrels downhole. 963Average Maximum -- - C-2 (current) Alkal 0.902 9.63'' 6.125 68.0 2064' 19475' - 3853 197 47 Annular Volume (bbls) Lag Correction (bbls) Depth 80/2051 - Oil / Water 19282' 907-670-4047Unit Phone: 613 Tyler Dretke 256 9145 - Units* Casing Summary Lithology (%) Drillstring Capacity (bbls) Type Volumes Depth -- Set AtSize 15224' 13.38'' 7" 36861 100% Bottoms Up Strokes Hole Volume (bbls) Report By:Logging Engineers:T. Dretke / J. Tiegs 74072 C-4n 619473 Bottoms Up Time (mins) 475.62 79 5508633.35 157.74 . . * 24 hr Recap: 589292 Bottoms Up Time (mins) 435.65 69 5010573.92 138.26 100% Bottoms Up Strokes Hole Volume (bbls) Report By:Logging Engineers:T. Dretke / J. Tiegs 22740 -- Set AtSize 15224' 13.38'' 7" 25464 Units* Casing Summary Lithology (%) Drillstring Capacity (bbls) Type Volumes Depth 907-670-4047Unit Phone: 335 Tyler Dretke 62 7794 - Depth 80/2051 - Oil / Water 19282' - - 2396 (current) Alkal 0.902 9.63'' 6.125 68.0 2064' Annular Volume (bbls) Lag Correction (bbls) Maximum -- - C-2 up. During circulation, saw a max gas of 7794 units. Lost 95 barrels in the last 24 hours. 298Average Current 20051'70.2 Date: 197 47 121.1 Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Max @ ft C-5n 1273 372 Yesterday's Depth: Current Depth: 24 Hour Progress: 19947' 20051' 104' C-4n Cly 0% 40.0 C-4i 14300 Footage 13 Siltst Surface Casing Intermediate 2 Casing - C-1 C-5i AK-AM-0901388219 - - Backream Out PV Weight 1.50 WOB Intermediate 1 Casing Coal 32.20 Ss Ratio cP 14 Grade 15224' 27128 Minimum YP (lb/100ft2) 4.3 Mud RPM C-3 Gas Summary 109 Mud Type Hours in TFABit Type Mdi513 PDC Versapro20050' 4 9.509.50 0.296 Size Mi616 PDC -Connection Depth in / out Cht Silt 15224' ShClyst 26.0 (current) 28.013160' (max) Trip (max) Tuff ECD (ppg) ml/30min 41Background Chromatograph (ppm) 100% Gas In Air=10,000 Units 26 -- Comments - Lst CementGvl -- - 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 Alpine Job No.: Daily Charges: Total Charges: 120.0 Rig Activity: Doyon 19 Report For: Tools 24 hr MaxAvg -18274' Depth ROP ROP (ft/hr) Gamma, Resistivity, ECD Morning Report Report # 35 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips R. Bjorhus / D. Lowe North Slope, AK @ Mud Data HTHP FL Avg Min Lime Cor Solids MWD Summary -- 5-Jul-2014 12:00 AM Current Pump & Flow Data: 3345 Max - 96%4.23 - 914 Density (ppg) out (sec/qt) Viscosity (lb/bbl)% 1.95 14.0 Troubleshot MWD tools, drilled from 19947' to 20051', began to pack off. Washed and reamed, circulated bottoms rea 570 . . * 24 hr Recap: Bottoms Up Time (mins) 477.73 69 4743636.5 158.77 Bottoms Up Strokes Hole Volume (bbls) Report By:Logging Engineers:D. McKechnie / J. Tiegs 3717 -- Set AtSize 15224' 13.38'' 7" 1525 Units* Casing Summary Lithology (%) Drillstring Capacity (bbls) Type Volumes Depth (current) 907-670-4047Unit Phone: 33 David McKechnie 15 600 - Depth 80/2050 - Oil / Water 20051' Footage 13 17765' - 123 Alkal 0.902 9.63'' 6.125 68.0 2064' Annular Volume (bbls) Lag Correction (bbls) Cly Maximum -- - C-2 intermittent pack-offs. Circulated up max gas of 600 unts resulting from pack off bottoms up. Weighed fluid up from 9.5 ppg to 72 15,500' MD in preparation to weigh mud system up to 10.4 ppg at report time. Total loss of 180 bbls observed over last 24 hours. Average Current -- Date: 195 46 - Flow In (gpm) Flow In (spm) Time: SPP (psi) Gallons/stroke Max @ ft 24 hr Max C-5n 55 30 Yesterday's Depth: Current Depth: 24 Hour Progress: 20050' 20050' 0' C-4i 637 C-4n 56832 Surface Casing Intermediate 2 Casing - Intermediate 1 Casing CoalClyst 26.0 40.0 C-1 C-5i AK-AM-0901388219 - - Circulate / Condition PV Weight 1.50 WOB Ss Ratio cP 14 Grade 15224' Mud Type Hours in Siltst 439 Minimum (lb/100ft2) 4.6 Mud RPM C-3 Gas Summary 103 32.20 TFABit Type Mdi513 PDC Versapro20050' 4 9.809.80 0.296 Size Mi616 PDC 600 Connection Depth in / out Cht Silt 15224' Sh (current) 28.013160' (max) Trip (max) Tuff ECD (ppg) ml/30min 31Background Chromatograph (ppm) 100% Gas In Air=10,000 Units 4 -- Comments - Lst CementGvl -- and conitioned 3 bottoms up, losing an average of 7.25 bbls/hr for duaration. Broke circulation and began running into the hole to at 152 gpm noting an average hole fill of 14.7 bbls per set of 5 stands (11.78 bbls over calculated) for duration of the trip. Circulated - 9.8 ppg from 08:30 to 11:30 while reciprocationg pipe. Established weight and resumed backreaming out of the hole to 15200' MD 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 8.75 Alpine Job No.: Daily Charges: Total Charges: 120.0 Rig Activity: Doyon 19 Report For: Tools Avg -20050' Depth ROP ROP (ft/hr) Gamma, Resistivity, ECD YP Morning Report Report # 36 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips R. Bjorhus / D. Lowe North Slope, AK @ Mud Data HTHP FL Avg Min Lime Cor Solids MWD Summary -- 6-Jul-2014 12:00 AM Current Pump & Flow Data: 2867 Max - 96%4.23 - 166 Density (ppg) out (sec/qt) Viscosity (lb/bbl)% 1.95 15.3 Continued backreaming out of the hole at 190 GPM. Worked through tight spots at 17810' MD and 17739' MD with rea 113 . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 103 (max)(current) Intermediate 1 Casing 114 - Cly 2807 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs 105 - 9.63'' 194 46 Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 7 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 4.049 C-5n 15435' - C-2 49 in --Minimum Depth Time: ppg. Broke circulation and attempted to monitor well. Noted excessive torque when attempting to rotate without pumps. Brought 23 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 17 0 (current) R. Bjorhus / D. Lowe ShClyst TuffGvlCoal cP 13 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulate Bottoms Up PV 24 hr Max 40.0 Weight 4 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.60 010 120.0 Mdi513 PDC Versapro 4.7 15224' 20050'11 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -14Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 67 4 Circulating bottoms up at report time. 130 bbls lost last 24 hours. Cut weight mud weight from 10.8 to 9.4 ppg while attempting to free pipe. No success. Broke circulation and monitored well - Static. on pumps and established circulation. Stepped rates to 3.4 barrels per minute while attempting to work pipe free with no success. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.0 8.75 9.40 Mi616 PDC 9.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 37 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Jul-2014 12:00 AM Current Pump & Flow Data: 2815 Max 5 Lime (lb/bbl) 2.08 Continued pumping in the hole to 15,500' MD, circulating and conditioning while weighing up mud from 9.8 to 10.4 rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued circulating bottoms up. Observed 260 units of gas. Continued circulating while attempting to pull string rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.95 1057 8-Jul-2014 12:00 AM Current Pump & Flow Data: 1263 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 38 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 11.6 8.75 9.20 Mi616 PDC 9.20 Size 4 Broke circulation and bled off pressure from MPD. Jarred string. Balanced choke and circulated bottoms up noting 7600 units of Applied torque to the drillstring and attempted to jar the string free. Circulated and conditioned bottoms up while observing the well gas. Circulated gas out from 03:20 to 05:00. Pumped 15 bbls of LVT and spotted same in open hole. Let LVT soak for 1 hour. 12953' 1565' 100% Gas In Air=10,000 Units-Connection 31375 Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 87Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 7.8 15224' 20050'12 Depth in / out YP (lb/100ft2) 1.50 3924043 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 1484 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Displace to 10.8 ppg PV 2064' 6.125 0.296 Footage 32.20 R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 13 26.0 Gas Summary - 5280 814 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: free without success. Noted slight well bore breathing while pulling on string. Circulated bottoms up and observed 2800 units of 347 gas. Attempted to pull free while circulating and conditioning from 12:20 to 19:10. Circulated max gas of 8365 units at 19:35. report time with a background gas of 87 units. Total loss of 30 bbls last 24 hours. Isotube sample collected. Brought on mud from trucks and began displacing fluid from 9.2 to 10.8 ppg. Displacing 9.2 ppg at in --Minimum Depth C-5n - - C-2 8365 SPP (psi) Gallons/stroke TFABit Type Depth 80/2050 - Oil / Water 20050' Alkal 0.902 - 2760 - Siltst 9.63'' 135 32 Units* Casing Summary Lithology (%) 11526687 - 90-670-4047Unit Phone: 814 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 48146 - Cly 579989 Bottoms Up Time (mins) 477.73 69 4743636158.77 148 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 148 (max)(current) Intermediate 1 Casing 526 - Cly 7659 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: 83 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / J. Tiegs 442 - 9.63'' 85 20 Units* Casing Summary Lithology (%) 12 - Oil / Water 20050' Alkal 0.902 - 145 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 79/2152 C-5n - - C-2 114 in --Minimum Depth Time: to 10K and backing out until nominal weight was observed at surface. Broke circulation and monitored the well - Static. Rigged up 19 circulation. 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 340 80 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 14 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Work On E-Line Equipment PV 24 hr Max 40.0 Weight 44 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.50 6326 120.0 Mdi513 PDC Versapro 4.8 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 891 4 weight while working on E-Line tools at report time. Standing by to complete gas equipment calibration and testing upon breaking surface and inspected tools. Rigged down E-line. Calibrated Gas Chromatograph. Circulating and condition mud to nominal and ran E-Line equipment in the hole to 15186' MD. Fired E-Line string shots with no success. Pulled out of the hole with E-Line to 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 21.8 8.75 10.40 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 39 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Jul-2014 12:00 AM Current Pump & Flow Data: 918 Max 70 Lime (lb/bbl) 1.95 Continued weighing 9.2 fluid to 10.8 ppg at 40 GPM and stepped rates to 2 barrels per minute, torqueing the string rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Conditioned mud to 10.8 while E-line prepared tools. Ran in the hole with cutting tools to 15134' MD. Attempted rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.08 7 10-Jul-2014 12:00 AM Current Pump & Flow Data: 0 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 40 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 20.8 8.75 10.80 Mi616 PDC 10.80 Size 4 equipment and rigged down same in preparation to jar drillstring at report time. 99% methane. Worked past jars to 15134' MD. Fired shot with no indications successful cut. Pulled out of the hole with E-Line minute. Ran in the hole with E-Line tools. Hung up on jars. Calibrated and tested gas detection equipment with 10%, 20% and 12953' 1565' 100% Gas In Air=10,000 Units-Connection 34 Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 6Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 4.8 15224' 20050'16 Depth in / out YP (lb/100ft2) 1.60 030 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 21 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Lay Down E-Line Tools PV 2064' 6.125 0.296 Footage 32.20 R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 15 26.0 Gas Summary - 21 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: cut. No cut indication noted. Pulled out of the hole with E-line and laid down same. Circulated and conditioned at 2 barrels per 2 in --Minimum Depth C-5n - - C-2 12 SPP (psi) Gallons/stroke TFABit Type Depth 80/2059 - Oil / Water 20050' Alkal 0.902 - 8 - Siltst 9.63'' 0 0 Units* Casing Summary Lithology (%) 0713 - 90-670-4047Unit Phone: 2 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 214 - Cly 8005 Bottoms Up Time (mins) 477.73 69 4743636158.77 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 237 (max)(current) Intermediate 1 Casing 329 - Cly 132 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: 2 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 2679 - 9.63'' 20 85 Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 80/2055 C-5n - - C-2 130 in --Minimum Depth Time: Rigged up Wireline String Shot and ran in the hole with same. Fired shot at target depth of 15156' MD with no sign of cutting at 36 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 5 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 18 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulate Bottoms Up PV 24 hr Max 40.0 Weight 70 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.50 000 120.0 Mdi513 PDC Versapro 5.6 15224' 20050'18 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -13Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 30 4 fluid lost last 24 hours. PSI. Rotated drillstring without restriction. Circulating bottoms up with a background gas of 13 units at report time. 93 barrels of surface. Wroked pipe and separated drillstring. Pulled out of the hole with E-Line and rigged down same. Tested Top Drive to 3500 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 23.5 8.75 10.80 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 41 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Jul-2014 12:00 AM Current Pump & Flow Data: 650 Max 8 Lime (lb/bbl) 1.95 Jarred string with no success. Inspected Derrick. Resumed jarring and inspected Derrick. Slip and cut drill line. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued circulating bottoms up at 2 barrels per minute. Monitored well - static. Pumped dry job and began pulling rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.95 0 12-Jul-2014 12:00 AM Current Pump & Flow Data: 650 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 42 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 23.5 8.75 10.80 Mi616 PDC 10.80 Size 4 12953' 1565' 100% Gas In Air=10,000 Units-Connection 8 Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 4Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 5.8 15224' 20050'12 Depth in / out YP (lb/100ft2) 1.50 000 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 1 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Trip Out Hole / 3-1/2" DP PV 2064' 6.125 0.296 Footage 32.20 R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 17 26.0 Gas Summary - 0 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: out of the hole with 3-1/2" drill pipe singles. Tripping out of the hole, laying down singles at report time. 40 bbls lost last 24 hours. 10 in --Minimum Depth C-5n - - C-2 16 SPP (psi) Gallons/stroke TFABit Type Depth 80/2051 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst 9.63'' 20 85 Units* Casing Summary Lithology (%) 061 - 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 19 - Cly 448 Bottoms Up Time (mins) 477.73 69 4743636158.77 237 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 237 (max)(current) Intermediate 1 Casing 0 - Cly 55 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 33 - 9.63'' - - Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1850 C-5n - - C-2 8 in --Minimum Depth Time: Observed slight drop. Tested BOPE. Made up fishing tools. Singling in the hole with fish to 11,410' MD as per program at report 2 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 0 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 15 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Tripping in Hole w/ Fish PV 24 hr Max 40.0 Weight 0 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.60 000 120.0 Mdi513 PDC Versapro 6.5 15224' 20050'10 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 0 4 time. 10 bbls of fluid lost last 24 hours. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 16.0 8.75 10.80 Mi616 PDC 10.30 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 43 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 0 Lime (lb/bbl) 2.08 Continued pulling out of the hole with 3-1/2" drill pipe to surface and laying down singles. Monitored the well. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 237 (max)(current) Intermediate 1 Casing 37 - Cly 2951 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 90-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 369 - 9.63'' - - Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 81/1950 C-5n - - C-2 35 in --Minimum Depth Time: engaged fish. Attempted to jar free. Displaced 10.8 ppg fluid to 10.2 ppg and continued to work pipe. Running in the hole with 11 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 0 0 (current) R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 14 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH W/ E-Line PV 24 hr Max 40.0 Weight 37 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.50 000 120.0 Mdi513 PDC Versapro 6.2 15224' 20050'12 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 8 4 E-Line equipment at report time. 284 bbls lost last 24 hours. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.0 8.75 10.40 Mi616 PDC 10.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 44 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 14-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 8 Lime (lb/bbl) 1.95 Continued running in the hole with fishing equipment and tagged fish at11675' MD. Established circulation and rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued running in the hole with E-Line Cutter to 11304' MD. E-Line stuck in fishing BHA. Lost E-Line BHA while rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.11 549 15-Jul-2014 12:00 AM Current Pump & Flow Data: 865 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 45 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.0 8.75 10.40 Mi616 PDC 10.40 Size 4 24 hours. units of gas. Collected Isotube gas sample. Circulating gas out at 2 barrels per minute at report time. No losses to report for last retrieve. Pulled out of the hole with Slickline and added 5' Sub. Began ranning back in the hole with Slickline. Encountered 8500 12953' 1565' 100% Gas In Air=10,000 Units-Connection 27378 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 8442Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 6.4 15224' 20050'15 Depth in / out YP (lb/100ft2) 1.63 08512 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 997 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH W/ Slickline for E-Line PV 2064' 6.125 0.296 Footage 32.20 R. Bjorhus / A. Dorr ShClyst TuffGvlCoal cP 14 26.0 Gas Summary - 4787 598 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: attempting to pull free. Pulled remaining equipment to surface. Picked up Slickline and ran in the hole to retrieve fish. Unable to 260 in --Minimum Depth C-5n - - C-2 8579 SPP (psi) Gallons/stroke TFABit Type Depth 81/1948 - Oil / Water 20050' Alkal 0.902 - 2248 - Siltst 9.63'' 88 20 Units* Casing Summary Lithology (%) 4621111 - 907-670-4047Unit Phone: 514 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 47739 - Cly 625905 Bottoms Up Time (mins) 477.73 69 4743636158.77 237 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 - (max)(current) Intermediate 1 Casing 66269 - Cly 622452 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 894 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 60518 - 9.63'' - - Units* Casing Summary Lithology (%) 273 - Oil / Water 20050' Alkal 0.902 - 3251 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 81/1951 C-5n - - C-2 9185 in --Minimum Depth Time: to pull on fish. Pulled out of the hole to change out slickline tools. Re-ran slickline to fish and pulled out of the hole to change tools. 797 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 4787 6163 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 14 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH W/ Slickline for E-Line PV 24 hr Max 40.0 Weight 4302 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.63 101570105 120.0 Mdi513 PDC Versapro 6.6 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -727Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 40276 4 BHA. Running in the hole with slickline at report time. 25 bbls of fluid lost last 24 hours. Ran in the hole with slickline to target at 11600' MD, but was unable to retrieve the fish. Pulled out of the hole to modify slickline 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.0 8.75 10.40 Mi616 PDC 10.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 46 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 16-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 2796 Lime (lb/bbl) 2.08 Resumed running in the hole with Slickline to retrieve fish. Continued circulating gas out to 1200~ units. Attempted rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued running in the hole with Slickline to target. Engaged fish and began pulling out of the hole. Lost fish. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.86 56 17-Jul-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 47 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.0 8.75 10.40 Mi616 PDC 10.40 Size 4 preparing to run in the hole with E-Line at report time. 11 bbls of fluid lost over last 24 hours. successfully. Rigged down slickline. Circulated and conditioned mud. Max gas of 61 units noted. Rigging up gooseneck and 12953' 1565' 100% Gas In Air=10,000 Units-Connection 231 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 11Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 6.8 15224' 20050'16 Depth in / out YP (lb/100ft2) 2.20 245220 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 33 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH with E-Line PV 2064' 6.125 0.296 Footage 32.20 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 17 26.0 Gas Summary - 164 58 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: Resumed pulling out of the hole with slickline. Changed out slickline tools and re-ran same. Engaged fish and pulled out 27 in --Minimum Depth C-5n - - C-2 61 SPP (psi) Gallons/stroke TFABit Type Depth 81/1957 - Oil / Water 20050' Alkal 0.902 - 58 - Siltst 9.63'' - - Units* Casing Summary Lithology (%) 15711 - 907-670-4047Unit Phone: 66 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 163 - Cly 3476 Bottoms Up Time (mins) 477.73 69 4743636158.77 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 - (max)(current) Intermediate 1 Casing 95 - Cly 1136 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 33 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 127 - 9.63'' - - Units* Casing Summary Lithology (%) 1 - Oil / Water 20050' Alkal 0.902 - 16 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 83/1754 C-5n - - C-2 28 in --Minimum Depth Time: Successfully separated string. Observed 35,000 lb. loss in string weight. Pulled out of the hole with E-line. Confirmed shot was 11 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 53 26 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 15 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Tripping Out Hole PV 24 hr Max 40.0 Weight 3 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.50 141 120.0 Mdi513 PDC Versapro 7.0 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -8Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 70 4 Pulling out of the hole while inspecting drill pipe at report time. 5 bbls lost over last 24 hours fired. Circulated and conditioned, weighting up to 10.8 ppg at 4 barrels per minute. Flow checked. Static. Pump 13 ppg slug. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 18.01 8.75 10.80 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 48 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 18-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 4 Lime (lb/bbl) 1.95 Continued rigging up E-line and running in the hole with same. Ran in hole to 11,700' MD. Fired string shot. rig Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued pulling out of the hole to 1017' MD while inspecting drill pipe. Pulled MPD element. Continued pulling out f Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.08 15 19-Jul-2014 12:00 AM Current Pump & Flow Data: 778 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 49 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 16.01 8.75 10.80 Mi616 PDC 10.80 Size 4 for the last 24 hours. to 3.5 barrels per minute. Circulating and conditioning at report time with a background gas of 10 units. 14 barrels lost to the hole 11,429' MD. Installed RCD element. Continued running in the hole with 4" drill pipe. Tag fish at 11,675' MD. Step pump rates up 12953' 1565' 100% Gas In Air=10,000 Units-Connection 2578 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 10Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 7.0 15224' 20050'16 Depth in / out YP (lb/100ft2) 1.60 5135 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 27 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulate/Condition PV 2064' 6.125 0.296 Footage 32.20 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 16 26.0 Gas Summary - 2567 1035 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: of the hole to surface. Laid down fishing BHA. Monitored well (static). Made up Baker fishing BHA. Ran in the hole with same to 10 in --Minimum Depth C-5n - - C-2 28 SPP (psi) Gallons/stroke TFABit Type Depth 82/1857 - Oil / Water 20050' Alkal 0.902 - 2580 - Siltst 9.63'' 127 30 Units* Casing Summary Lithology (%) 12180 - 907-670-4047Unit Phone: 1024 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 5147 - Cly 10825 Bottoms Up Time (mins) 477.73 69 4743636158.77 158 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 - (max)(current) Intermediate 1 Casing 146 - Cly 5436 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 3 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 947 - 9.63'' - - Units* Casing Summary Lithology (%) 1 - Oil / Water 20050' Alkal 0.902 - 12 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1853 C-5n - - C-2 61 in --Minimum Depth Time: latch on fish. Pulled out of the hole with slickline without fish. Re-ran slickline to 15,090' MD. Attempted to latch on fish. Fish 18 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 26 5 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 19 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Rig Up Wireline PV 24 hr Max 40.0 Weight 23 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.58 030 120.0 Mdi513 PDC Versapro 7.2 15224' 20050'15 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -10Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 88 4 20%, and 99% Methane. Preparing to run into the hole with wireline tool at report time. 11 bbls lost to formation for the last 24 hours. retrieved and pulled out of the hole with slickline and fish. Made up wireline tools. Tested and calibrated gas equipment with 10%, 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 16.01 8.75 10.80 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 50 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 12 Lime (lb/bbl) 2.05 Continued circulating and conditioning at 3 barrels per minute. Ran in hole with slickline to 15,090' MD. Attempted to f Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 225 (max)(current) Intermediate 1 Casing 188 - Cly 5121 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 790 - 9.63'' 85 21 Units* Casing Summary Lithology (%) 1 - Oil / Water 20050' Alkal 0.902 - 12 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1856 C-5n - - C-2 63 in --Minimum Depth Time: with no indication of shot fired. Attempted to pull out of hole with wireline. Tool stuck. Worked pipe and pumps with no success in 18 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 22 0 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 16 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Pulling out of hole PV 24 hr Max 40.0 Weight 26 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.50 020 120.0 Mdi513 PDC Versapro 6.8 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 107 4 dry job. Pulling out of the hole to 10,690' MD at report time. 76 barrels lost to formation last 24 hours. 15,120' MD. Pulled out of hole with wireline from 15,120' to 50'. Rigged down wireline and tools. Circulate and condition. Pump freeing wireline tool. Decision made to pull out of E-line rope socket. Pulled free from rope socket. Top of wireline fish at 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 17.01 8.75 10.80 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 51 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 21-Jul-2014 12:00 AM Current Pump & Flow Data: 23 Max 16 Lime (lb/bbl) 1.95 Made up wireline tools. Ran in the hole with same to 15,152' MD. Could not work past 15,152' MD. Fired explosives Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued pulling out of the hole to 1,000’ MD. Removed 4” MPD element. Continued tripping out of the hole from Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.89 0 22-Jul-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 52 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 17.01 8.75 10.80 Mi616 PDC 10.80 Size 4 last 24 hours. and tripped in with same to 2039’ MD. Slip and cut drill line. Running in hole with scraper assembly to ~6000' MD. 13 barrels lost 12953' 1565' 100% Gas In Air=10,000 Units-Connection 5 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 8Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 6.6 15224' 20050'16 Depth in / out YP (lb/100ft2) 1.45 000 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH w/ Scraper Asmbly PV 2064' 6.125 0.296 Footage 32.20 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 16 26.0 Gas Summary - 0 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: 1000’ to surface while inspecting 3-1/2” drill pipe. E-Line tool was retrieved. Laid down tools. Made up Baker Scraper assembly 7 in --Minimum Depth C-5n - - C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 82/1855 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst 9.63'' - - Units* Casing Summary Lithology (%) 044 - 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 0 - Cly 112 Bottoms Up Time (mins) 477.73 69 4743636158.77 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 477.73 69 4743636158.77 - (max)(current) Intermediate 1 Casing 32 - Cly 618 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 156 - 9.63'' - - Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1857 C-5n - - C-2 16 in --Minimum Depth Time: Continued running in the hole to 15045’ MD. Washed down to 15157’ MD at 3-1/2” barrels per minute. Tagged top of fish and 9 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 5 0 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 15 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - POOH w/Scraper PV 24 hr Max 40.0 Weight 4 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.45 000 120.0 Mdi513 PDC Versapro 6.6 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 24 4 20 bbls lost last 24 hours. with good results. Broke circulation. Monitored the well. Static. Pumped 12.8 ppg dry job. Began tripping out of the hole to 2980’ MD. circulated bottoms up while reciprocating pipe. Noted bubbling in the possum belly with no notable gas.Bag tested gas equipment 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 17.01 8.75 10.80 Mi616 PDC 10.80 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 53 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 23-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 6 Lime (lb/bbl) 1.89 Continued tripping in the hole from ~6000’ MD to 14855’ MD, filling pipe every 20 stands. Set 4” RCD element. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued pulling out of the hole from 2980’ MD. Laid down scraper BHA. Make up cement retainer and run in hole. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 2.02 0 24-Jul-2014 12:00 AM Current Pump & Flow Data: 2868 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 54 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 17.01 8.75 10.80 Mi616 PDC 10.80 Size 4 and spacer. Tested retainer. Displacing 10.8 ppg mud to 9.6 ppg mud at report time. 48 bbls lost last 24 hours. 12953' 1565' 100% Gas In Air=10,000 Units-Connection 24 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 6Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 6.6 15224' 20050'15 Depth in / out YP (lb/100ft2) 1.55 000 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Displacing to 9.6 ppg PV 2064' 6.125 0.296 Footage 32.20 K. Harding / D. Lowe ShClyst TuffGvlCoal cP 16 26.0 Gas Summary - 0 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: Tagged fish at 15,156' MD. Performed injectivity test. Pumped 17 bbls of 15.8 ppg cement. Reverse circulated out excess cement 9 in --Minimum Depth C-5n - - C-2 51 SPP (psi) Gallons/stroke TFABit Type Depth 82/1855 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst 9.63'' 244 58 Units* Casing Summary Lithology (%) 0107 - 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 84 - Cly 5149 Bottoms Up Time (mins) 477.73 69 4743636158.77 82 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap:Continued to displace fluid and circulate until 9.6 ppg was achieved. Flow check. Static. Pump 36 bbl dry job. Pulled Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.69 2 25-Jul-2014 12:00 AM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 55 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 10.54 8.75 9.60 Mi616 PDC 9.60 Size 4 chunks. Rigging down MPD equipment from stack for rig maintenance at report time. 12953' 1565' 100% Gas In Air=10,000 Units-Connection 25 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 4Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 5.2 15224' 20050'11 Depth in / out YP (lb/100ft2) 1.30 000 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 5 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - R/D MPD Equipment PV 2064' 6.125 0.296 Footage 32.20 K. Harding / D. Lowe ShClyst TuffGvlCoal cP 14 26.0 Gas Summary - 0 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: out of hole from 15150' MD to surface on calculated hole fill and laid down BHA. Rig floor observed bag chunking. Removed bag 9 in --Minimum Depth C-5n - - C-2 51 SPP (psi) Gallons/stroke TFABit Type Depth 76/2452 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst 9.63'' - - Units* Casing Summary Lithology (%) 0363 - 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 74 - Cly 5081 Bottoms Up Time (mins) 402 -3991514112 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 402 -3991514112 - (max)(current) Intermediate 1 Casing 0 - Cly 62 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters 40 - 9.63'' - - Units* Casing Summary Lithology (%) 0 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 76/2453 C-5n - - C-2 10 in --Minimum Depth Time: report time. No losses to report. 6 20050' 20050' 0' Max @ ft Current -- Date: Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 0 0 (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP 13 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Test BOP PV 24 hr Max 40.0 Weight 0 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.30 000 120.0 Mdi513 PDC Versapro 5.3 15224' 20050'14 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -3Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 0 4 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 10.54 8.75 9.60 Mi616 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 56 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 26-Jul-2014 12:00 AM Current Pump & Flow Data: - Max 0 Lime (lb/bbl) 1.69 Removed rig element and installed new element. Rig up MPD equipment. Test same. Rigging up to test BOPE at Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued testing BOP. Made up whipstock BHA. Ran in hole with same to 1520' MD. Tested MWD tools. Good test. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.56 1 27-Jul-2014 12:00 AM Current Pump & Flow Data: 2550 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 57 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 10.45 8.75 9.60 Mi616 PDC 9.60 Size 4 12953' 1565' 100% Gas In Air=10,000 Units-Connection 10 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min 7Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 5.2 15224' 20050'9 Depth in / out YP (lb/100ft2) 1.20 000 -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulate and condition PV 2064' 6.125 0.296 Footage 32.20 K. Harding / D. Lowe ShClyst TuffGvlCoal cP 13 26.0 Gas Summary - 0 0 (current) Avg to20050' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 20050' 20050' 0' Max @ ft Current -- Date: Time: Continued running in the hole to 14,915' MD, filling pipe every 20 stands. Circulating and conditioning at report time. 7 in --Minimum Depth C-5n - - C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 76/2460 - Oil / Water 20050' Alkal 0.902 - 0 - Siltst 9.63'' 211 50 Units* Casing Summary Lithology (%) 046 - 907-670-4047Unit Phone: 0 David McKechnie Maximum Report By:Logging Engineers:D. McKechnie / A. Charters Set AtSize 68.0 - Grade -15224' 13.38'' 7" (max)(current) Intermediate 1 Casing 0 - Cly 104 Bottoms Up Time (mins) 402 -3991514112 80 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 362 -3596468106 169 (max)(current) Intermediate 1 Casing 8 - Cly 312 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 119 - 9.63'' 73 17 Units* Casing Summary Lithology (%) 0 - Oil / Water - Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 77/2350 C-5n - - C-2 12 in --Minimum Depth Time: to 15165', flow checked the well and observed slight drop, pump out to 15022', installed RCD element, pumped out from 15022' 5 15132' 15165' 33' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 0 0 (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP 16 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - POOH PV 24 hr Max 40.0 Weight 1 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.90 000 120.0 Mdi513 PDC Versapro 5.0 15224' 15165'9 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 7 4 to 12766'. 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 12.00 8.75 9.60 Mi616 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 58 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 4-Aug-2014 23:59 PM Current Pump & Flow Data: 202 Max 0 Lime (lb/bbl) 2.47 SDL arrived on location at 16:40 hrs. Ran in hole with the whipstock to 15100', began milling window from 15132' Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 362 -3596468106 169 (max)(current) Intermediate 1 Casing 0 - Cly 201 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 152 - 9.63'' 73 17 Units* Casing Summary Lithology (%) 0 - Oil / Water - Alkal 0.902 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 77/2350 C-5n - - C-2 4 in --Minimum Depth Time: Schlumberger and Baker. Picked up tools and began running in the hole with 6.125" starter mill. Ran in hole to 8623'. 3 15165' 15165' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 0 0 (current) R. Bjorhus/A. Dorr ShClyst TuffGvlCoal cP 16 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH PV 24 hr Max 40.0 Weight 0 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.90 000 120.0 Mdi513 PDC Versapro - 15224' 15165'9 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 0 4 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 12.00 8.75 9.60 Mi616 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 59 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 5-Aug-2014 23:59 PM Current Pump & Flow Data: 202 Max 0 Lime (lb/bbl) 2.47 Pulled out from 12766' to 1123', pulled RCD element, continued pulling out to surface. Laid down BHA per Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 362 -3596468106 169 (max)(current) Intermediate 1 Casing 28 - Cly 766 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 78 - 9.63'' 86 21 Units* Casing Summary Lithology (%) 0 - Oil / Water - Alkal 0.902 - 8 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 77/2351 C-5n - - C-2 20 in --Minimum Depth Time: performed rig maintenance, reamed through the window. Circulated and conditioned, performed a flow check, began pulling out. 6 15165' 15165' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 5 0 (current) R. Bjorhus/A. Dorr ShClyst TuffGvlCoal cP 16 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - POOH PV 24 hr Max 40.0 Weight 0 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.80 000 120.0 Mdi513 PDC Versapro - 15224' 15165'10 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -6Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 10 4 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 12.00 8.75 9.60 Mi616 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 60 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 6-Aug-2014 23:59 PM Current Pump & Flow Data: 91 Max 0 Lime (lb/bbl) 2.34 Continued running in the hole with the 6.125" mill, slipped and cut the drill line, serviced the top drive and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 362 -3596468106 169 (max)(current) Intermediate 1 Casing 135 - Cly 1270 Set AtSize 68.0 - Grade -15224' 13.38'' 7" 907-670-4047Unit Phone: 0 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 166 - 9.63'' 86 21 Units* Casing Summary Lithology (%) 1 - Oil / Water - Alkal 0.902 - 13 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 77/2351 C-5n - - C-2 22 in --Minimum Depth Time: Make up the BHA with mud motor assembly per Schlumberger, Run in hole from 275' to 9285'. 9 15165' 15165' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 20 0 (current) R. Bjorhus/A. Dorr ShClyst TuffGvlCoal cP 16 2064' 6.125 0.296 Footage 32.20 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH w/ mud motor BHA PV 24 hr Max 40.0 Weight 13 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.80 020 120.0 Mdi513 PDC Versapro - 15224' 15165'10 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -17Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 104 4 12953' 1565' Condition 0-1-WT-G-X-I-NO-TD Bit # 3 12.00 8.75 9.60 Mi616 PDC 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 61 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 7-Aug-2014 23:59 PM Current Pump & Flow Data: 91 Max 10 Lime (lb/bbl) 2.34 Continue pulling out of the hole, lay down the BHA per Schlumberger, clean and clear rig floor, lay down 4" HWDP, Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued running in the hole, Installed the RCD Element, continued running in hole, broke circulation and Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.89 562 8-Aug-2014 23:59 PM Current Pump & Flow Data: 178 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 62 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Condition 0-1-WT-G-X-I-NO-TD Bit # 3 14.00 8.75 9.60 Mi616 PDC 9.60 Size 4 drilled from 15195' to 15265'. Circuated and condtioned, performed flow check, pumped dry job and began pulling out. 12953' 1565' 100% Gas In Air=10,000 Units-Connection 6575 Tools - HTHP FL Chromatograph (ppm) 28.013160' 15224' WOB Surface Casing - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min 4Background (max) Trip Average - Mud Type Lst 100% Intermediate 2 Casing Type 120.0 Mdi513 PDC Versapro 5.2 15224' 15165'11 Depth in / out YP (lb/100ft2) 1.45 1211515 -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight 901 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - POOH PV 2064' 6.125 0.296 Footage 32.20 R. Bjorhus/A. Dorr ShClyst TuffGvlCoal cP 17 26.0 Gas Summary - 987 135 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: 137.4 Flow In (gpm) Flow In (spm) 15165' 15265' 100' Max @ ft Current 15246'54.0 Date: Time: conditioned, drilled from 15165' to 15195', pulled out to the top of the window, performed leak off test, ran back to bottom and 592 in --Minimum Depth C-5n - - C-2 4262 SPP (psi) Gallons/stroke TFABit Type Depth 80/2057 - Oil / Water - Alkal 0.902 - 527 - Siltst 9.63'' 76 18 Units* Casing Summary Lithology (%) 5623347 - 907-670-4047Unit Phone: 121 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 68.0 - Grade -15128' 13.38'' 7" (max)(current) Intermediate 1 Casing 13206 - Cly 440863 Bottoms Up Time (mins) 362 -3596468106 169 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 362 -3596468106 105 (max)(current) Intermediate 1 Casing 32 - Cly 102 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: - T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 50 - 9.63'' - - Units* Casing Summary Lithology (%) 6 - Oil / Water - Alkal 0.389 - 12 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 80/2053 C-5n - - C-2 8 in --Minimum Depth Time: stack and began testing BOPE. 6 15265' 15265' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 13 - (current) A. Dorr / B. Finkbiner ShClyst TuffGvlCoal cP 17 100' Footage 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Test BOPE PV 24 hr Max 40.0 Weight 16 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.50 -8 - Versapro 5.415265'9 Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -4Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 13 12953' 1565' ConditionBit # 5 14.00 6.125 9.60 Smith Milltooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 63 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 9-Aug-2014 23:59 PM Current Pump & Flow Data: - Max 7 Lime (lb/bbl) 1.95 Continued to pull out of the hole, tested choke manifold, performed flow check, inspected derrick, drained the Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Finished testing the BOPE, pulled the test plug and installed the wear ring, blew down the lines and began making Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.89 241 10-Aug-2014 23:59 PM Current Pump & Flow Data: - Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 64 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 14.00 6.125 9.60 Smith Milltooth 9.60 Size 6 12953' 1565' 100% Gas In Air=10,000 Units-Connection 859 Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min 197Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type Smith PDC Versapro 5.4 15265' 15265'9 Depth in / out YP (lb/100ft2) 1.45 6508 -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight 347 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - RIH PV 100' 6.125 0.314 Footage 0.00 2.42 A. Dorr / B. Finkbiner ShClyst TuffGvlCoal cP 16 26.0 Gas Summary - 152 26 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 15265' 15265' 0' Max @ ft Current -- Date: Time: the BHA, shallow pulse tested the MWD equipment. Began singling in the hole with 3.5" DP. 119 in --Minimum Depth C-5n - - C-2 435 SPP (psi) Gallons/stroke TFABit Type Depth 80/2055 - Oil / Water - Alkal 0.389 - 76 - Siltst 9.63'' - - Units* Casing Summary Lithology (%) 254737 - 907-670-4047Unit Phone: 22 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 68.0 - Grade -15128' 13.38'' 7" (max)(current) Intermediate 1 Casing 1603 - Cly 42237 Bottoms Up Time (mins) 362 -3596468106 105 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 412 0 4094529117 91 (max)(current) Intermediate 1 Casing 4036 - Cly 124013 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: 54 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 10% 14492 - 9.63'' 190 45 Units* Casing Summary Lithology (%) 44 - Oil / Water 15592' Alkal 0.389 - 189 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 81/1956 C-5n 15265' 82.9 C-2 1458 in --Minimum Depth Time: line and serviced rig and top drive, ran in the hole to 15159', washed and reamed down to 15265', drilled to 15363', back reamed 177 15265' 15592' 327' Max @ ft Current 15318'76.1 Date: Avg to15265' Yesterday's Depth: Current Depth: 24 Hour Progress: 122.8 Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 639 61 (current) A. Dorr / B. Finkbiner ShClyst TuffGvlCoal cP 12 100' 6.125 0.314 Footage 0.00 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling PV 24 hr Max 40.0 Weight 656 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.50 159517 Smith PDC Versapro 5.0 15265' 15415'9 Depth in / out Mud Type Lst 90% Intermediate 2 Casing Type Average -70Background (max) Trip -9.88 Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units140Connection 2093 6 out to 15240' and pulled out to the window. Ran back to bottom and drilled from 15363' to 15592'. 12953' 1565' ConditionBit # 5 13.86 6.125 9.60 Smith Milltooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.76 Doyon 19 Report For: Morning Report Report # 65 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 11-Aug-2014 23:59 PM Current Pump & Flow Data: 3257 Max 419 Lime (lb/bbl) 1.95 Continued to run in the hole, installed ECD element, circulated and conditioned bottoms up, slipped and cut drill Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 442 40 4801574132 104 (max)(current) Intermediate 1 Casing 7755 - Cly 242374 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: 146 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 5% 106489 - 9.63'' 186 44 Units* Casing Summary Lithology (%) 199 - Oil / Water 15592' Alkal 0.389 - 390 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 81/1950 C-5n 16670' 60.4 C-2 2915 in --Minimum Depth Time: 1225 15592' 17074' 1482' Max @ ft Current 17019'89.1 Date: Avg to15265' Yesterday's Depth: Current Depth: 24 Hour Progress: 126.4 Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 834 170 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 13 100' 6.125 0.314 Footage 0.00 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling PV 24 hr Max 40.0 Weight 3789 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.35 7542884 Smith PDC Versapro 3.2 15265' 16851'8 Depth in / out Mud Type Lst 95% Intermediate 2 Casing Type Average -985Background (max) Trip -9.88 Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 4227 6 12953' 1565' ConditionBit # 5 14.50 6.125 9.65 Smith Milltooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.76 Doyon 19 Report For: Morning Report Report # 66 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 12-Aug-2014 23:59 PM Current Pump & Flow Data: 3128 Max 2105 Lime (lb/bbl) 1.76 Drilled from 15592 to 17074'. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 466 34 4970609143 108 (max)(current) Intermediate 1 Casing 6863 - Cly 215307 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: 126 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 74825 - 9.63'' 195 46 Units* Casing Summary Lithology (%) 155 - Oil / Water 18175' Alkal 0.389 - 362 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 81/1952 C-5n 17889' 78.0 C-2 2644 in --Minimum Depth Time: 876 17074' 18175' 1101' Max @ ft Current 17774'79.1 Date: Avg to15265' Yesterday's Depth: Current Depth: 24 Hour Progress: 120.0 Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 744 151 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 16 100' 6.125 0.314 Footage 0.00 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Drilling PV 24 hr Max 40.0 Weight 2741 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.50 7133879 Smith PDC Versapro 3.4 15265' 16851'9 Depth in / out Mud Type Lst 100% Intermediate 2 Casing Type Average -880Background (max) Trip -10.68 Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 3791 6 12953' 1565' ConditionBit # 5 14.00 6.125 9.70 Smith Milltooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 67 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 13-Aug-2014 23:59 PM Current Pump & Flow Data: 3446 Max 1551 Lime (lb/bbl) 1.95 Drilled from 17074 to 18175'. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Drilled from 18175' to 19296', troubleshoot MWD tool, circulate bottoms-up. Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.76 1747 14-Aug-2014 23:59 PM Current Pump & Flow Data: 3220 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 68 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 14.00 6.125 9.65 Smith Milltooth 9.60 Size 6 12953' 1565' 100% Gas In Air=10,000 Units-Connection 5205 Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing -10.89 Avg Min Comments - Mud RPM ECD (ppg) ml/30min 1242Background (max) Trip Average - Mud Type Lst 100% Intermediate 2 Casing Type Smith PDC Versapro 3.4 15265' 19296'9 19296' Depth in / out YP (lb/100ft2) 1.35 7838191 -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight 9029 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulating PV 100' 6.125 0.314 Footage 0.00 4031' 2.42 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 16 26.0 Gas Summary - 998 202 (current) Avg to15265' Yesterday's Depth: Current Depth: 24 Hour Progress: 146.6 Flow In (gpm) Flow In (spm) 18175' 19296' 1121' Max @ ft Current 19003'81.6 Date: Time: 961 in --Minimum Depth C-5n 19285' - C-2 3700 SPP (psi) Gallons/stroke TFABit Type Depth 81/1955 - Oil / Water 19296' Alkal 0.389 - 538 - Siltst 9.63'' 186 44 Units* Casing Summary Lithology (%) 19080709 - 907-670-4047Unit Phone: 160 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 68.0 - Grade -15128' 13.38'' 7" (max)(current) Intermediate 1 Casing 3013 - Cly 304003 Bottoms Up Time (mins) 490 24 5054645154 115 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 490 24 5054645154 115 (max)(current) Intermediate 1 Casing 10122 - Cly 320171 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: 181 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 73258 - 9.63'' 182 43 Units* Casing Summary Lithology (%) 131 - Oil / Water 19296' Alkal 0.389 - 607 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1864 C-5n - - C-2 3923 in --Minimum Depth Time: 734 19296' 19296' 0' Max @ ft Current -- Date: Avg to15265' Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 1115 200 (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 19 100' 6.125 0.314 Footage 0.00 4031' 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Circulating PV 24 hr Max 40.0 Weight 2198 Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.40 6328463 Smith PDC Versapro 3.5 15265' 19296'8 19296' Depth in / out Mud Type Lst 100% Intermediate 2 Casing Type Average -81Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools Gamma, Resistivity, ECD HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 5933 6 12953' 1565' ConditionBit # 5 15.00 6.125 9.70 Smith Milltooth 9.60 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 69 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 15-Aug-2014 23:59 PM Current Pump & Flow Data: 3128 Max 1258 Lime (lb/bbl) 1.82 Circulated and conditioned, ran back to bottom, began back reaming out of hole. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to backream out of the hole to 15354', pulled out to 15122', weighted up to 10.2 ppg, pulled out to 14931' Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.82 34 16-Aug-2014 23:59 PM Current Pump & Flow Data: 235 Max - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 70 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 16.11 6.125 10.20 Smith Milltooth 10.20 Size 6 12953' 1565' 100% Gas In Air=10,000 Units-Connection 291 Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min 8Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type Smith PDC Versapro 3.4 15265' 19296'9 19296' Depth in / out YP (lb/100ft2) 1.40 8186 -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight 36 Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - POOH PV 100' 6.125 0.314 Footage 0.00 4031' 2.42 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 21 26.0 Gas Summary - 115 36 (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 19296' 19296' 0' Max @ ft Current -- Date: Time: installed RCD element, pulled out to 7992', pumped 13.2 ppg dry job, continued to pull out. 18 in --Minimum Depth C-5n - - C-2 95 SPP (psi) Gallons/stroke TFABit Type Depth 84/1666 - Oil / Water - Alkal 0.389 - 44 - Siltst 9.63'' 80 19 Units* Casing Summary Lithology (%) 6611 - 907-670-4047Unit Phone: 43 T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs Set AtSize 68.0 - Grade -15128' 13.38'' 7" (max)(current) Intermediate 1 Casing 361 - Cly 6619 Bottoms Up Time (mins) 490 24 5054645154 115 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 490 24 5054645154 115 (max)(current) Intermediate 1 Casing - - Cly 14 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: - T. Dretke Maximum Report By:Logging Engineers:T. Dretke / J. Tiegs 8 - 9.63'' - - Units* Casing Summary Lithology (%) - - Oil / Water - Alkal 0.389 - - - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1866 C-5n - - C-2 2 in --Minimum Depth Time: Ran in the hole with 4.5" tubing to 4292', attempted to make up the seal bore extension (seals stuck in the seal bore), laid down 1 19296' 19296' 0' Max @ ft Current -- Date: Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - -- (current) K. Harding / A. Dorr ShClyst TuffGvlCoal cP 22 100' 6.125 0.314 Footage 0.00 4031' 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - L/D DP PV 24 hr Max 40.0 Weight - Hours C-3 -- - CementCht Silt C-4i C-4n YP (lb/100ft2) 1.45 --- Smith PDC Versapro 3.6 15265' 19296'12 19296' Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -0Background (max) Trip - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection - 6 liner hanger and seal bore extension. 12953' 1565' ConditionBit # 5 15.00 6.125 10.20 Smith Milltooth 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 71 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 17-Aug-2014 23:59 PM Current Pump & Flow Data: - Max - Lime (lb/bbl) 1.89 Continued to pull out of the hole, removed MPD element, laid down the BHA, rigged up the tools to run 4.5" tubing Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued to lay down 3.5" drill pipe, made up the liner hanger, ran in hole from 4279' to 4377', circulated two Density (ppg) out (sec/qt) Viscosity Cor Solids % Lime (lb/bbl) 1.82 - 18-Aug-2014 23:59 PM Current Pump & Flow Data: 53 Max 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 72 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 15.00 6.125 10.20 Smith Milltooth 10.20 Size 6 12953' 1565' 100% Gas In Air=10,000 Units-Connection - Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing - - Avg Min Comments - Mud RPM ECD (ppg) ml/30min 3Background (max) Trip Average - Mud Type Lst Intermediate 2 Casing Type Smith PDC Versapro 3.7 15265' 19296'10 19296' Depth in / out YP (lb/100ft2) 1.40 --- -- - CementCht Silt C-4i C-4n 24 hr Max 40.0 Weight - Hours C-3 Ss Ratio C-1 C-5i AK-AM-0901388219 - - P/U 4" HWDP PV 100' 6.125 0.314 Footage 0.00 4031' 2.42 K. Harding / A. Dorr ShClyst TuffGvlCoal cP 19 26.0 Gas Summary - -- (current) Avg to - Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 19296' 19296' 0' Max @ ft Current -- Date: Time: liner volumes, continued to run in the hole to 15069', circulate and condition while picking up 4" heavy weight drill pipe. 4 in --Minimum Depth C-5n - - C-2 10 SPP (psi) Gallons/stroke TFABit Type Depth 82/1872 - Oil / Water - Alkal 0.389 - - - Siltst 9.63'' 85 20 Units* Casing Summary Lithology (%) -8 - 907-670-4047Unit Phone: - T. Dretke Maximum Report By:Logging Engineers:T. Dretke / A. Charters Set AtSize 68.0 - Grade -15128' 13.38'' 7" (max)(current) Intermediate 1 Casing - - Cly 90 Bottoms Up Time (mins) 334 24 5301509175 178 Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes . . * 24 hr Recap: Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 380.75 24 3780569188.72 252 (max)(current) Intermediate 1 Casing 32 - Cly 2288 Set AtSize 68.0 - Grade -15128' 13.38'' 7" 907-670-4047Unit Phone: 0 D. McKechnie Maximum Report By:Logging Engineers:A. Charters / D. McKechnie 568 - 9.63'' 63 15 Units* Casing Summary Lithology (%) 0 - Oil / Water - Alkal 0.389 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth 82/1865 C-5n - - C-2 26 in --Minimum Depth Time: work past 15244' MD. Attempted to circulate with no returns observed as surface. Decision was made to pull out of the hole into 7" 10 19296' 19296' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 26.0 Gas Summary - 6 0 (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP 18 100' 6.125 0.314 Footage 0.00 4031' 2.42 Ss Ratio C-1 C-5i AK-AM-0901388219 - - Washing Down W/ Liner PV 24 hr Max 40.0 Weight 6 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) 1.40 000 Smith PDC Versapro 3.4 15265' 19296'9 19296' Depth in / out Mud Type Lst Intermediate 2 Casing Type Average -17Background (max) Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - HTHP FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 15 6 centrifuging as needed at report time. casing. Established circulation and conditioned mud. Began pumping in the hole from 15063' MD. Washing down to 17426' MD 12953' 1565' ConditionBit # 5 15.00 6.125 10.20 Smith Milltooth 10.20 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 73 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 19-Aug-2014 23:59 PM Current Pump & Flow Data: 567 Max 4 Lime (lb/bbl) 1.82 Ran in the hole with liner to 15244' MD. Observed tight spots at 15190', 15237', 15243' and 15250' MD. Could not MD Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap: 7"15128'Intermediate 2 Casing 26.0 -- Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 380.75 24 3780569188.72 252 (max)(current) Intermediate 1 Casing 2736 - Cly 114353 Set AtSize 68.0 - Grade -19293' 13.38'' 4-1/2" 907-670-4047Unit Phone: 38 D. McKechnie Maximum Report By:Logging Engineers:A. Charters / D. McKechnie 22523 - 9.63'' - - Units* Casing Summary Lithology (%) 39 - MBT - PH 0.389 - 143 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 1200 in --Minimum Depth Time: Tested WIV. Released from liner after several attempts. Set liner hanger. Tested packer. Pulled out of the hole to 14935' MD and 233 19296' 19296' 0' Max @ ft Current -- Date: Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) - Gas Summary - 286 44 (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 100' 6.125 0.314 Footage 0.00 4031' 2.42 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - POOH W/ 4" Drill Pipe PV 24 hr Max 40.0 Weight 610 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - 128213 Smith PDC Seawater - 15265' 19296'- 19296' Depth in / out Mud Type Lst Production Liner Type Average -1Background (max)Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 1641 6 confirmed release from liner. Displaced mineral oil based mud to sea water. Singling out of the hole with 4" drill pipe at report time. 12953' 1565' ConditionBit # 5 - 6.125 8.40 Smith Milltooth 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 74 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 20-Aug-2014 23:59 PM Current Pump & Flow Data: - Max 417 Chlorides mg/l - Continued running in the hole to 19268' MD on 4-1/2" drill pipe. Tagged bottom at 19293' MD. Set liner hanger. Tested WIV. Released from liner after several attempts. Set liner hanger. Tested packer. Pulled out of the hole to 14935' MD and Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued pulling out of the hole to surface and laid down 4" drill pipe. Pulled RCD element and slip/cut drill line. Pulled wear ring and rigged up to run 3-1/2" tubing. Running in the hole with tubing to 1558' MD at report time. No losses to report. Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - 0 21-Aug-2014 23:59 PM Current Pump & Flow Data: - Max 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 75 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 - 6.125 8.40 Smith Milltooth 8.40 Size 6 12953' 1565' 100% Gas In Air=10,000 Units-Connection 0 Tools - API FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min 1Background (max)Trip Average - Mud Type Lst Production Liner Type Smith PDC Seawater - 15265' 19296'- 19296' Depth in / out YP (lb/100ft2) - 000 -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight 0 Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - RIH With 3-1/2" Tubing PV 100' 6.125 0.314 Footage 0.00 4031' 2.42 K. Harding / D. Lowe ShClyst TuffGvlCoal cP - - Gas Summary - 0 0 (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 19296' 19296' 0' Max @ ft Current -- Date: Time: Pulled wear ring and rigged up to run 3-1/2" tubing. Running in the hole with tubing to 1558' MD at report time. No losses to report. 1 in --Minimum Depth C-5n - - C-2 4 SPP (psi) Gallons/stroke TFABit Type Depth -27 - MBT - PH 0.389 - 0 - Siltst 9.63'' - - Units* Casing Summary Lithology (%) 06 - 907-670-4047Unit Phone: 0 D. McKechnie Maximum Report By:Logging Engineers:A. Charters / D. McKechnie Set AtSize 68.0 - Grade -19293' 13.38'' 4-1/2" (max)(current) Intermediate 1 Casing 0 - Cly 33 Bottoms Up Time (mins) 41.07 -40854.62 13.5 - Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 7"15128'Intermediate 2 Casing 26.0 -- . . * 24 hr Recap: 7"15128'Intermediate 2 Casing 26.0 -- Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (mins) 361 -3585480119 - (max)(current) Intermediate 1 Casing 0 - Cly 33 Set AtSize 68.0 - Grade -19293' 13.38'' 4-1/2" 907-670-4047Unit Phone: 0 D. McKechnie Maximum Report By:Logging Engineers:A. Charters / D. McKechnie 5 - 9.63'' - - Units* Casing Summary Lithology (%) 0 - MBT - PH 0.389 - 0 - Siltst SPP (psi) Gallons/stroke TFABit Type Depth -27 C-5n - - C-2 6 in --Minimum Depth Time: Tripping in to 13697' MD at report time. 2 19296' 19296' 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 (current) K. Harding / D. Lowe ShClyst TuffGvlCoal cP - 100' 6.125 0.314 Footage 0.00 4031' 2.42 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - RIH With 3-1/2" Tubing PV 24 hr Max 40.0 Weight 0 Hours C-3 -- - CementChtSilt C-4i C-4n YP (lb/100ft2) - 000 Smith PDC Seawater - 15265' 19296'- 19296' Depth in / out Mud Type Lst Production Liner Type Average -0Background (max)Trip -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min Tools - API FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing 100% Gas In Air=10,000 Units-Connection 0 6 12953' 1565' ConditionBit # 5 - 6.125 8.40 Smith Milltooth 8.40 Size Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: Morning Report Report # 76 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth 22-Aug-2014 23:59 PM Current Pump & Flow Data: - Max 0 Chlorides mg/l - Continued running in the hole with 3-1/2" tubing, installing I-wire and cannon clamps testing I-wire every 25 joints. Tripping in to 13697' MD at report time. Density (ppg) out (sec/qt) Viscosity Cor Solids % . . * 24 hr Recap:Continued running in the hole with 3-1/2" tubing to 15002' MD. Pressure tested seals Pulled out of the hole to 14924' MD and pumped corrosion inhibited brine. Sheared SOV. Began rigging down MPD equipment. Rigged down Flow Line Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l - - 23-Aug-2014 23:59 PM Current Pump & Flow Data: - Max 1-1-CT-A-X-I-NO-DTF - ROP ROP (ft/hr) 4.23 @ Mud Data Depth Morning Report Report # 77 Customer: Well: Area: Location: Rig: CD4-96A ConocoPhillips North Slope, AK Alpine Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: - Doyon 19 Report For: ConditionBit # 5 - 6.125 - Smith Milltooth - Size 6 and bell nipple. Rigged up to nipple down BOP stack. Rigging down SDL equipment at report time. 12953' 1565' 100% Gas In Air=10,000 Units-Connection - Tools - API FL Chromatograph (ppm) 15165' 15265' WOB Surface Casing -- Avg Min Comments - Mud RPM ECD (ppg) ml/30min -Background (max)Trip Average - Mud Type Lst Production Liner Type Smith PDC -- 15265' 19296'- 19296' Depth in / out YP (lb/100ft2) - --- -- - CementChtSilt C-4i C-4n 24 hr Max 40.0 Weight - Hours C-3 Ss (ppb Eq) C-1 C-5i AK-AM-0901388219 - - Nipple Down BOP PV 100' 6.125 0.314 Footage 0.00 4031' 2.42 K. Harding / D. Lowe ShClyst TuffGvlCoal cP - - Gas Summary - -- (current) Avg to- Yesterday's Depth: Current Depth: 24 Hour Progress: - Flow In (gpm) Flow In (spm) 19296' 19296' 0' Max @ ft Current -- Date: Time: 14924' MD and pumped corrosion inhibited brine. Sheared SOV. Began rigging down MPD equipment. Rigged down Flow Line - in --Minimum Depth C-5n - - C-2 - SPP (psi) Gallons/stroke TFABit Type Depth -- - MBT - PH 0.389 - - - Siltst 9.63'' - - Units* Casing Summary Lithology (%) -- - 907-670-4047Unit Phone: - D. McKechnie Maximum Report By:Logging Engineers:A. Charters / D. McKechnie Set AtSize 68.0 - Grade -19293' 13.38'' 4-1/2" (max)(current) Intermediate 1 Casing - - Cly - Bottoms Up Time (mins) ------ Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes 7"15128'Intermediate 2 Casing 26.0 -- WELL INFORMATION Created On : Aug 28 2014 Customer :Conoco Phillips Alaska, Inc. Well Name :CD4-96A Job Number :AK-XX-0901388219 Rig Name :Doyon19 Field Name :Alpine Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 36.80 0.00 0.00 36.80 0.00 N 0.00 E 0.00 0.00 75.32 0.12 214.58 75.32 0.03 S 0.02 W 0.04 0.31 104.55 0.19 179.56 104.55 0.11 S 0.04 W 0.11 0.39 144.37 0.04 280.72 144.37 0.17 S 0.05 W 0.18 0.51 241.06 0.41 229.08 241.06 0.39 S 0.35 W 0.47 0.40 333.50 0.51 232.63 333.50 0.86 S 0.92 W 1.08 0.11 423.96 0.76 273.71 423.95 1.06 S 1.84 W 1.54 0.56 520.36 1.79 306.49 520.33 0.13 S 3.69 W 1.16 1.27 612.19 2.95 333.58 612.08 2.84 N 5.90 W -1.08 1.72 703.41 2.13 339.50 703.21 6.53 N 7.53 W -4.16 0.94 797.65 2.47 331.34 797.37 9.96 N 9.12 W -7.00 0.50 855.62 1.96 316.94 855.30 11.78 N 10.40 W -8.39 1.30 950.35 1.65 246.75 949.99 12.42 N 12.76 W -8.35 2.21 1017.27 4.25 216.67 1,016.82 10.05 N 15.12 W -5.41 4.39 1046.10 5.62 215.32 1,045.54 8.04 N 16.58 W -3.07 4.77 1139.67 9.20 213.97 1,138.32 1.90 S 23.41 W 8.39 3.83 1233.36 14.14 215.28 1,230.04 17.47 S 34.21 W 26.35 5.28 1326.99 19.56 216.77 1,319.62 39.37 S 50.21 W 51.87 5.81 1377.22 22.22 214.85 1,366.54 53.91 S 60.67 W 68.75 5.47 1422.26 24.40 213.70 1,407.91 68.64 S 70.70 W 85.70 4.94 1472.21 26.21 211.32 1,453.06 86.64 S 82.16 W 106.20 4.16 1516.77 27.68 209.02 1,492.79 104.10 S 92.30 W 125.80 4.04 1567.27 30.11 205.13 1,537.00 125.83 S 103.37 W 149.76 6.08 1611.16 33.09 204.16 1,574.38 146.74 S 112.95 W 172.52 6.89 1631.32 34.02 203.59 1,591.18 156.93 S 117.46 W 183.56 4.87 1705.49 37.52 205.83 1,651.35 196.28 S 135.61 W 226.43 5.04 1749.43 39.66 204.96 1,685.69 221.04 S 147.36 W 253.49 5.02 1799.40 41.07 205.18 1,723.77 250.36 S 161.07 W 285.47 2.84 1893.90 45.79 206.76 1,792.38 308.72 S 189.55 W 349.48 5.12 1988.14 46.53 206.88 1,857.65 369.38 S 220.22 W 416.31 0.79 INSITE V8.1.0 Page 1Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2082.27 46.35 206.41 1,922.52 430.35 S 250.81 W 483.40 0.41 2177.28 48.36 207.09 1,986.88 492.75 S 282.27 W 552.12 2.18 2273.16 53.76 207.18 2,047.12 559.09 S 316.27 W 625.34 5.63 2322.18 56.04 208.88 2,075.30 594.49 S 335.12 W 664.59 5.45 2365.77 57.89 209.54 2,099.07 626.38 S 352.95 W 700.21 4.43 2460.71 60.25 210.00 2,147.86 697.06 S 393.39 W 779.39 2.52 2554.60 60.50 211.91 2,194.28 767.05 S 435.37 W 858.34 1.79 2649.85 61.88 215.06 2,240.19 836.64 S 481.42 W 938.05 3.24 2742.86 63.23 219.26 2,283.07 902.38 S 531.28 W 1015.14 4.26 2837.37 63.96 224.05 2,325.12 965.60 S 587.52 W 1091.58 4.60 2869.84 64.39 225.42 2,339.26 986.36 S 608.09 W 1117.28 4.02 2965.61 64.93 230.95 2,380.28 1,044.03 S 672.58 W 1190.71 5.25 3020.73 65.46 228.71 2,403.40 1,076.30 S 710.80 W 1232.41 3.81 3114.99 66.20 228.12 2,442.00 1,133.38 S 775.13 W 1305.23 0.97 3209.60 66.52 229.05 2,479.94 1,190.71 S 840.12 W 1378.48 0.96 3303.50 66.16 228.43 2,517.62 1,247.43 S 904.78 W 1451.05 0.72 3397.99 64.30 228.94 2,557.21 1,304.08 S 969.21 W 1523.49 2.03 3491.63 64.66 228.61 2,597.55 1,359.77 S 1,032.77 W 1594.76 0.50 3586.27 64.39 228.48 2,638.26 1,416.33 S 1,096.80 W 1667.01 0.31 3680.38 64.59 228.30 2,678.79 1,472.73 S 1,160.31 W 1738.95 0.27 3774.89 64.50 228.51 2,719.41 1,529.38 S 1,224.13 W 1811.22 0.22 3869.26 64.53 227.91 2,760.01 1,586.15 S 1,287.64 W 1883.52 0.57 3963.72 64.41 227.14 2,800.72 1,643.71 S 1,350.51 W 1956.39 0.75 4061.51 64.30 226.49 2,843.05 1,704.04 S 1,414.79 W 2032.32 0.61 4159.70 64.61 226.66 2,885.39 1,764.94 S 1,479.13 W 2108.81 0.35 4254.11 64.15 226.96 2,926.21 1,823.20 S 1,541.19 W 2182.14 0.57 4347.74 63.04 226.53 2,967.85 1,880.66 S 1,602.27 W 2254.42 1.25 4442.50 61.89 225.90 3,011.66 1,938.80 S 1,662.93 W 2327.23 1.35 4536.09 60.62 225.68 3,056.66 1,996.02 S 1,721.75 W 2398.64 1.37 4632.01 59.12 225.96 3,104.81 2,053.83 S 1,781.24 W 2470.82 1.58 4727.18 59.45 225.96 3,153.42 2,110.71 S 1,840.06 W 2541.90 0.35 4821.01 59.37 225.92 3,201.17 2,166.88 S 1,898.10 W 2612.09 0.09 4915.29 59.38 227.17 3,249.20 2,222.68 S 1,956.99 W 2682.16 1.14 5010.08 60.25 227.14 3,296.86 2,278.40 S 2,017.07 W 2752.49 0.92 5109.39 61.83 227.50 3,344.94 2,337.30 S 2,080.95 W 2826.93 1.62 5203.58 64.83 227.59 3,387.21 2,394.10 S 2,143.04 W 2898.87 3.19 5299.56 64.66 226.40 3,428.17 2,453.31 S 2,206.52 W 2973.50 1.14 5392.87 63.31 226.51 3,469.09 2,511.08 S 2,267.30 W 3045.99 1.45 5486.09 63.57 226.24 3,510.77 2,568.61 S 2,327.66 W 3118.13 0.38 5580.38 63.54 225.13 3,552.77 2,627.58 S 2,388.06 W 3191.68 1.05 5674.61 62.82 226.05 3,595.28 2,686.43 S 2,448.13 W 3265.00 1.16 5769.13 62.64 226.64 3,638.59 2,744.43 S 2,508.92 W 3337.71 0.59 5863.51 62.69 226.90 3,681.93 2,801.85 S 2,570.00 W 3409.96 0.25 5958.90 62.77 226.20 3,725.63 2,860.16 S 2,631.56 W 3483.19 0.66 6053.79 62.47 226.20 3,769.27 2,918.48 S 2,692.37 W 3556.22 0.32 INSITE V8.1.0 Page 2Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6146.64 62.60 227.14 3,812.10 2,975.02 S 2,752.30 W 3627.28 0.91 6240.58 62.50 227.55 3,855.40 3,031.50 S 2,813.61 W 3698.69 0.40 6336.26 62.65 228.39 3,899.47 3,088.36 S 2,876.69 W 3770.95 0.79 6430.58 62.80 227.96 3,942.69 3,144.27 S 2,939.16 W 3842.13 0.44 6523.57 62.58 228.74 3,985.36 3,199.18 S 3,000.90 W 3912.15 0.78 6617.74 62.04 229.16 4,029.12 3,253.94 S 3,063.78 W 3982.34 0.70 6712.46 63.21 228.93 4,072.67 3,309.07 S 3,127.31 W 4053.07 1.25 6807.18 64.99 230.03 4,114.04 3,364.42 S 3,192.08 W 4124.36 2.15 6901.57 66.76 229.83 4,152.62 3,419.87 S 3,258.00 W 4196.07 1.89 6995.55 66.41 230.49 4,189.97 3,475.12 S 3,324.22 W 4267.66 0.74 7090.90 64.90 230.38 4,229.27 3,530.46 S 3,391.18 W 4339.55 1.59 7185.57 66.20 230.38 4,268.46 3,585.41 S 3,457.57 W 4410.91 1.37 7279.26 66.23 230.13 4,306.24 3,640.23 S 3,523.49 W 4482.01 0.25 7372.88 66.19 230.38 4,344.01 3,695.00 S 3,589.35 W 4553.05 0.25 7468.22 66.20 229.97 4,382.49 3,750.86 S 3,656.35 W 4625.45 0.39 7561.95 66.09 229.06 4,420.40 3,806.52 S 3,721.54 W 4697.15 0.90 7656.89 66.15 227.79 4,458.83 3,864.12 S 3,786.49 W 4770.66 1.22 7749.14 65.59 227.45 4,496.55 3,920.87 S 3,848.68 W 4842.56 0.69 7844.14 64.30 227.03 4,536.78 3,979.30 S 3,911.86 W 4916.36 1.42 7938.86 64.08 227.23 4,578.02 4,037.31 S 3,974.36 W 4989.56 0.30 8032.81 64.14 226.83 4,619.04 4,094.92 S 4,036.20 W 5062.20 0.39 8125.50 64.11 227.04 4,659.49 4,151.87 S 4,097.13 W 5133.94 0.21 8222.02 63.80 227.20 4,701.87 4,210.88 S 4,160.67 W 5208.40 0.35 8313.92 63.12 227.26 4,742.93 4,266.71 S 4,221.03 W 5278.91 0.74 8411.28 62.18 227.06 4,787.66 4,325.50 S 4,284.44 W 5353.13 0.98 8503.41 62.08 227.39 4,830.73 4,380.81 S 4,344.22 W 5422.98 0.33 8600.42 62.67 227.20 4,875.71 4,439.11 S 4,407.38 W 5496.64 0.63 8691.17 64.04 227.41 4,916.41 4,494.11 S 4,466.99 W 5566.15 1.52 8790.02 63.59 227.25 4,960.03 4,554.23 S 4,532.22 W 5642.14 0.48 8882.67 62.03 227.12 5,002.36 4,610.24 S 4,592.67 W 5712.85 1.69 8976.21 62.04 227.42 5,046.23 4,666.30 S 4,653.35 W 5783.68 0.28 9071.00 61.95 227.15 5,090.73 4,723.07 S 4,714.85 W 5855.41 0.27 9165.30 62.79 227.13 5,134.47 4,779.90 S 4,776.09 W 5927.13 0.89 9258.78 62.00 227.07 5,177.78 4,836.29 S 4,836.77 W 5998.27 0.85 9353.22 62.03 227.12 5,222.10 4,893.06 S 4,897.86 W 6069.89 0.06 9447.52 62.02 227.58 5,266.33 4,949.49 S 4,959.11 W 6141.22 0.43 9541.95 62.38 227.04 5,310.37 5,006.12 S 5,020.51 W 6212.80 0.63 9636.02 62.29 227.14 5,354.05 5,062.85 S 5,081.53 W 6284.36 0.13 9730.64 62.31 227.38 5,398.03 5,119.71 S 5,143.06 W 6356.18 0.23 9825.32 62.82 227.30 5,441.66 5,176.65 S 5,204.85 W 6428.17 0.54 9919.47 63.85 227.56 5,483.91 5,233.57 S 5,266.81 W 6500.17 1.12 10013.65 63.81 227.33 5,525.45 5,290.73 S 5,329.08 W 6572.50 0.22 10109.47 63.92 226.77 5,567.65 5,349.34 S 5,392.04 W 6646.41 0.54 10202.84 63.88 226.62 5,608.73 5,406.85 S 5,453.06 W 6718.72 0.15 10298.09 63.81 227.01 5,650.72 5,465.36 S 5,515.40 W 6792.36 0.37 INSITE V8.1.0 Page 3Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10390.13 63.74 227.21 5,691.39 5,521.56 S 5,575.89 W 6863.26 0.21 10483.60 63.96 227.44 5,732.58 5,578.43 S 5,637.58 W 6935.14 0.32 10579.65 63.75 228.62 5,774.91 5,636.09 S 5,701.68 W 7008.46 1.12 10675.73 62.80 229.21 5,818.12 5,692.49 S 5,766.36 W 7080.73 1.13 10768.32 63.34 230.34 5,860.05 5,745.79 S 5,829.39 W 7149.57 1.23 10862.66 63.66 231.38 5,902.15 5,799.08 S 5,894.87 W 7219.08 1.04 10957.11 64.49 231.37 5,943.44 5,852.11 S 5,961.23 W 7288.58 0.88 11051.39 66.41 231.89 5,982.61 5,905.34 S 6,028.47 W 7358.52 2.10 11145.65 67.42 232.61 6,019.57 5,958.42 S 6,097.03 W 7428.69 1.28 11240.19 66.98 231.89 6,056.20 6,011.77 S 6,165.94 W 7499.23 0.84 11334.03 66.53 231.07 6,093.24 6,065.47 S 6,233.40 W 7569.68 0.94 11428.50 66.27 229.72 6,131.06 6,120.66 S 6,300.10 W 7641.35 1.34 11522.09 67.92 229.41 6,167.49 6,176.57 S 6,365.71 W 7713.42 1.79 11618.23 68.21 228.84 6,203.40 6,234.93 S 6,433.14 W 7788.34 0.63 11709.22 66.54 228.38 6,238.40 6,290.46 S 6,496.15 W 7859.31 1.89 11806.82 64.65 227.67 6,278.73 6,349.89 S 6,562.23 W 7934.88 2.05 11902.08 64.98 226.79 6,319.27 6,408.43 S 6,625.51 W 8008.81 0.90 11995.01 64.86 225.87 6,358.66 6,466.55 S 6,686.39 W 8081.67 0.91 12089.38 64.07 225.87 6,399.34 6,525.84 S 6,747.51 W 8155.71 0.84 12183.80 62.22 225.46 6,441.99 6,584.70 S 6,807.76 W 8229.11 2.00 12278.58 62.36 224.48 6,486.06 6,644.07 S 6,867.06 W 8302.71 0.93 12372.96 63.01 224.46 6,529.37 6,703.91 S 6,925.80 W 8376.62 0.69 12466.15 63.04 224.54 6,571.64 6,763.15 S 6,984.01 W 8449.80 0.08 12560.81 62.61 224.86 6,614.87 6,823.00 S 7,043.25 W 8523.86 0.54 12655.36 61.95 225.25 6,658.85 6,882.13 S 7,102.49 W 8597.23 0.79 12750.08 62.27 226.26 6,703.16 6,940.54 S 7,162.46 W 8670.11 1.00 12843.46 63.21 226.42 6,745.93 6,997.85 S 7,222.51 W 8741.95 1.02 12937.76 64.14 226.31 6,787.75 7,056.17 S 7,283.68 W 8815.08 0.99 12950.00 63.54 226.00 6,793.15 7,063.78 S 7,291.60 W 8824.61 5.40 13000.00 63.89 225.34 6,815.29 7,095.11 S 7,323.67 W 8863.67 1.38 13050.00 64.25 225.40 6,837.15 7,126.70 S 7,355.67 W 8902.97 0.73 13100.00 64.13 225.38 6,858.92 7,158.31 S 7,387.72 W 8942.29 0.24 13150.00 65.19 223.99 6,880.32 7,190.44 S 7,419.49 W 8982.04 3.29 13200.00 66.20 222.89 6,900.90 7,223.52 S 7,450.82 W 9022.58 2.85 13250.00 66.97 221.37 6,920.77 7,257.55 S 7,481.60 W 9063.87 3.19 13300.00 67.39 219.68 6,940.17 7,292.58 S 7,511.54 W 9105.89 3.23 13350.00 67.54 217.54 6,959.33 7,328.67 S 7,540.36 W 9148.61 3.96 13400.00 66.96 215.39 6,978.67 7,365.75 S 7,567.76 W 9191.88 4.13 13465.21 67.53 212.48 7,003.90 7,415.63 S 7,601.32 W 9249.18 4.21 13560.91 68.34 210.30 7,039.85 7,491.34 S 7,647.51 W 9334.80 2.27 13654.68 69.01 203.92 7,073.98 7,569.05 S 7,687.28 W 9420.54 6.38 13700.47 68.91 199.71 7,090.43 7,608.71 S 7,703.16 W 9463.06 8.58 13748.25 69.13 196.13 7,107.54 7,651.15 S 7,716.88 W 9507.65 7.01 13798.47 69.79 194.58 7,125.16 7,696.50 S 7,729.33 W 9554.67 3.17 13843.43 69.77 191.80 7,140.70 7,737.57 S 7,738.96 W 9596.79 5.80 INSITE V8.1.0 Page 4Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13892.22 70.19 189.78 7,157.41 7,782.60 S 7,747.54 W 9642.42 3.98 13937.58 71.10 188.49 7,172.44 7,824.85 S 7,754.33 W 9684.88 3.35 13986.39 71.07 186.42 7,188.26 7,870.63 S 7,760.32 W 9730.50 4.01 14032.29 70.92 185.22 7,203.21 7,913.80 S 7,764.72 W 9773.18 2.49 14126.12 71.40 181.77 7,233.52 8,002.43 S 7,770.13 W 9859.76 3.52 14220.43 71.92 178.71 7,263.20 8,091.93 S 7,770.50 W 9945.79 3.13 14315.67 72.54 176.02 7,292.27 8,182.52 S 7,766.33 W 10031.57 2.77 14409.52 74.45 174.84 7,318.93 8,272.21 S 7,759.16 W 10115.66 2.37 14503.54 77.35 176.58 7,341.84 8,363.13 S 7,752.34 W 10201.02 3.57 14598.40 76.68 175.26 7,363.15 8,455.33 S 7,745.77 W 10287.68 1.53 14693.07 75.36 171.48 7,386.03 8,546.56 S 7,735.17 W 10372.28 4.12 14787.08 75.52 167.79 7,409.67 8,636.05 S 7,718.80 W 10453.59 3.80 14881.67 75.70 165.45 7,433.18 8,725.18 S 7,697.60 W 10533.20 2.40 14975.07 77.57 165.52 7,454.77 8,813.14 S 7,674.83 W 10611.26 2.00 15069.85 79.46 163.22 7,473.65 8,902.58 S 7,649.80 W 10690.09 3.10 15132.00 81.16 162.43 7,484.11 8,961.11 S 7,631.71 W 10741.20 3.01 15145.00 82.00 163.25 7,486.01 8,973.39 S 7,627.92 W 10751.93 8.98 15164.10 82.33 163.11 7,488.61 8,991.51 S 7,622.44 W 10767.78 1.87 15216.01 90.21 162.73 7,491.99 9,040.98 S 7,607.24 W 10811.01 15.20 15251.68 92.21 162.47 7,491.24 9,075.01 S 7,596.57 W 10840.69 5.65 15343.82 88.76 161.64 7,490.46 9,162.65 S 7,568.19 W 10916.86 3.85 15438.85 86.71 161.76 7,494.21 9,252.80 S 7,538.38 W 10995.04 2.16 15532.67 86.74 165.34 7,499.57 9,342.62 S 7,511.86 W 11073.82 3.81 15628.21 87.01 165.20 7,504.78 9,434.88 S 7,487.60 W 11155.58 0.32 15722.62 86.40 164.05 7,510.21 9,525.76 S 7,462.61 W 11235.81 1.38 15816.83 89.62 162.31 7,513.48 9,615.87 S 7,435.37 W 11314.67 3.88 15911.98 88.49 160.01 7,515.05 9,705.90 S 7,404.65 W 11392.48 2.69 16005.98 88.35 160.30 7,517.64 9,794.28 S 7,372.75 W 11468.38 0.34 16100.28 89.25 160.38 7,519.61 9,883.07 S 7,341.03 W 11544.71 0.96 16194.91 89.18 160.54 7,520.91 9,972.24 S 7,309.39 W 11621.43 0.18 16289.78 90.00 161.54 7,521.59 10,061.96 S 7,278.56 W 11698.92 1.36 16384.30 90.00 162.38 7,521.59 10,151.83 S 7,249.29 W 11776.98 0.89 16479.19 89.96 163.78 7,521.62 10,242.61 S 7,221.68 W 11856.38 1.48 16572.63 89.96 166.63 7,521.69 10,332.94 S 7,197.82 W 11936.40 3.05 16667.87 89.49 170.89 7,522.15 10,426.33 S 7,179.26 W 12020.84 4.50 16761.84 89.31 174.30 7,523.13 10,519.50 S 7,167.15 W 12106.88 3.63 16856.15 89.55 175.27 7,524.07 10,613.41 S 7,158.58 W 12194.62 1.06 16950.99 89.62 178.08 7,524.76 10,708.08 S 7,153.08 W 12283.96 2.96 17048.48 89.72 179.52 7,525.32 10,805.55 S 7,151.04 W 12376.94 1.48 17142.94 88.08 177.10 7,527.13 10,899.94 S 7,148.25 W 12466.76 3.09 17238.30 89.66 177.20 7,529.01 10,995.16 S 7,143.51 W 12556.84 1.66 17333.23 87.26 176.64 7,531.56 11,089.91 S 7,138.41 W 12646.36 2.60 17400.10 88.22 174.43 7,534.20 11,156.52 S 7,133.21 W 12708.84 3.60 17425.96 89.90 173.39 7,534.62 11,182.23 S 7,130.47 W 12732.75 7.64 17520.69 88.94 167.78 7,535.58 11,275.64 S 7,114.98 W 12818.08 6.01 INSITE V8.1.0 Page 5Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 17615.57 89.00 164.40 7,537.29 11,367.71 S 7,092.18 W 12900.06 3.56 17710.57 88.15 162.25 7,539.65 11,458.68 S 7,064.93 W 12979.75 2.43 17805.68 90.07 159.71 7,541.13 11,548.58 S 7,033.94 W 13057.35 3.35 17898.11 89.69 160.26 7,541.32 11,635.42 S 7,002.30 W 13131.84 0.72 17993.33 90.65 165.47 7,541.04 11,726.38 S 6,974.26 W 13211.30 5.56 18087.60 90.45 165.20 7,540.14 11,817.58 S 6,950.40 W 13292.14 0.36 18181.67 88.73 166.42 7,540.81 11,908.77 S 6,927.34 W 13373.22 2.24 18276.40 87.73 169.28 7,543.74 12,001.32 S 6,907.41 W 13456.47 3.20 18370.88 88.63 171.31 7,546.74 12,094.40 S 6,891.49 W 13541.35 2.35 18465.75 88.42 172.93 7,549.18 12,188.34 S 6,878.49 W 13627.88 1.72 18560.26 89.38 171.37 7,550.99 12,281.94 S 6,865.58 W 13714.11 1.94 18655.50 89.31 167.40 7,552.08 12,375.53 S 6,848.05 W 13799.03 4.17 18750.73 89.24 165.70 7,553.29 12,468.13 S 6,825.90 W 13881.71 1.79 18844.07 89.90 153.92 7,553.99 12,555.58 S 6,793.74 W 13956.64 12.64 18939.60 89.79 148.19 7,554.25 12,639.14 S 6,747.53 W 14023.90 6.00 19032.31 89.31 144.01 7,554.98 12,716.07 S 6,695.83 W 14083.25 4.54 19127.75 90.65 142.73 7,555.01 12,792.66 S 6,638.89 W 14140.81 1.94 19234.83 89.04 145.46 7,555.30 12,879.38 S 6,576.10 W 14206.45 2.96 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 196.28 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 19,234.83 feet is 14,461.11 feet along 207.05 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 V8.1.0 Page 6Job No:AK-XX-0901388219 Well Name:CD4-96A Survey Report WELL INFORMATION Created On : Aug 28 2014 Customer :Conoco Phillips Alaska, Inc. Well Name :CD4-96A PB1 Job Number :-XX-0901388219 Rig Name :Doyon19 Field Name :Alpine Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 36.80 0.00 0.00 36.80 0.00 N 0.00 E 0.00 0.00 75.32 0.12 214.58 75.32 0.03 S 0.02 W 0.04 0.31 104.55 0.19 179.56 104.55 0.11 S 0.04 W 0.11 0.39 144.37 0.04 280.72 144.37 0.17 S 0.05 W 0.18 0.51 241.06 0.41 229.08 241.06 0.39 S 0.35 W 0.47 0.40 333.50 0.51 232.63 333.50 0.86 S 0.92 W 1.08 0.11 423.96 0.76 273.71 423.95 1.06 S 1.84 W 1.54 0.56 520.36 1.79 306.49 520.33 0.13 S 3.69 W 1.16 1.27 612.19 2.95 333.58 612.08 2.84 N 5.90 W -1.08 1.72 703.41 2.13 339.50 703.21 6.53 N 7.53 W -4.16 0.94 797.65 2.47 331.34 797.37 9.96 N 9.12 W -7.00 0.50 855.62 1.96 316.94 855.30 11.78 N 10.40 W -8.39 1.30 950.35 1.65 246.75 949.99 12.42 N 12.76 W -8.35 2.21 1017.27 4.25 216.67 1,016.82 10.05 N 15.12 W -5.41 4.39 1046.10 5.62 215.32 1,045.54 8.04 N 16.58 W -3.07 4.77 1139.67 9.20 213.97 1,138.32 1.90 S 23.41 W 8.39 3.83 1233.36 14.14 215.28 1,230.04 17.47 S 34.21 W 26.35 5.28 1326.99 19.56 216.77 1,319.62 39.37 S 50.21 W 51.87 5.81 1377.22 22.22 214.85 1,366.54 53.91 S 60.67 W 68.75 5.47 1422.26 24.40 213.70 1,407.91 68.64 S 70.70 W 85.70 4.94 1472.21 26.21 211.32 1,453.06 86.64 S 82.16 W 106.20 4.16 1516.77 27.68 209.02 1,492.79 104.10 S 92.30 W 125.80 4.04 1567.27 30.11 205.13 1,537.00 125.83 S 103.37 W 149.76 6.08 1611.16 33.09 204.16 1,574.38 146.74 S 112.95 W 172.52 6.89 1631.32 34.02 203.59 1,591.18 156.93 S 117.46 W 183.56 4.87 1705.49 37.52 205.83 1,651.35 196.28 S 135.61 W 226.43 5.04 1749.43 39.66 204.96 1,685.69 221.04 S 147.36 W 253.49 5.02 1799.40 41.07 205.18 1,723.77 250.36 S 161.07 W 285.47 2.84 1893.90 45.79 206.76 1,792.38 308.72 S 189.55 W 349.48 5.12 INSITE V8.1.0 Page 1Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 1988.14 46.53 206.88 1,857.65 369.38 S 220.22 W 416.31 0.79 2082.27 46.35 206.41 1,922.52 430.35 S 250.81 W 483.40 0.41 2177.28 48.36 207.09 1,986.88 492.75 S 282.27 W 552.12 2.18 2273.16 53.76 207.18 2,047.12 559.09 S 316.27 W 625.34 5.63 2322.18 56.04 208.88 2,075.30 594.49 S 335.12 W 664.59 5.45 2365.77 57.89 209.54 2,099.07 626.38 S 352.95 W 700.21 4.43 2460.71 60.25 210.00 2,147.86 697.06 S 393.39 W 779.39 2.52 2554.60 60.50 211.91 2,194.28 767.05 S 435.37 W 858.34 1.79 2649.85 61.88 215.06 2,240.19 836.64 S 481.42 W 938.05 3.24 2742.86 63.23 219.26 2,283.07 902.38 S 531.28 W 1015.14 4.26 2837.37 63.96 224.05 2,325.12 965.60 S 587.52 W 1091.58 4.60 2869.84 64.39 225.42 2,339.26 986.36 S 608.09 W 1117.28 4.02 2965.61 64.93 230.95 2,380.28 1,044.03 S 672.58 W 1190.71 5.25 3020.73 65.46 228.71 2,403.40 1,076.30 S 710.80 W 1232.41 3.81 3114.99 66.20 228.12 2,442.00 1,133.38 S 775.13 W 1305.23 0.97 3209.60 66.52 229.05 2,479.94 1,190.71 S 840.12 W 1378.48 0.96 3303.50 66.16 228.43 2,517.62 1,247.43 S 904.78 W 1451.05 0.72 3397.99 64.30 228.94 2,557.21 1,304.08 S 969.21 W 1523.49 2.03 3491.63 64.66 228.61 2,597.55 1,359.77 S 1,032.77 W 1594.76 0.50 3586.27 64.39 228.48 2,638.26 1,416.33 S 1,096.80 W 1667.01 0.31 3680.38 64.59 228.30 2,678.79 1,472.73 S 1,160.31 W 1738.95 0.27 3774.89 64.50 228.51 2,719.41 1,529.38 S 1,224.13 W 1811.22 0.22 3869.26 64.53 227.91 2,760.01 1,586.15 S 1,287.64 W 1883.52 0.57 3963.72 64.41 227.14 2,800.72 1,643.71 S 1,350.51 W 1956.39 0.75 4061.51 64.30 226.49 2,843.05 1,704.04 S 1,414.79 W 2032.32 0.61 4159.70 64.61 226.66 2,885.39 1,764.94 S 1,479.13 W 2108.81 0.35 4254.11 64.15 226.96 2,926.21 1,823.20 S 1,541.19 W 2182.14 0.57 4347.74 63.04 226.53 2,967.85 1,880.66 S 1,602.27 W 2254.42 1.25 4442.50 61.89 225.90 3,011.66 1,938.80 S 1,662.93 W 2327.23 1.35 4536.09 60.62 225.68 3,056.66 1,996.02 S 1,721.75 W 2398.64 1.37 4632.01 59.12 225.96 3,104.81 2,053.83 S 1,781.24 W 2470.82 1.58 4727.18 59.45 225.96 3,153.42 2,110.71 S 1,840.06 W 2541.90 0.35 4821.01 59.37 225.92 3,201.17 2,166.88 S 1,898.10 W 2612.09 0.09 4915.29 59.38 227.17 3,249.20 2,222.68 S 1,956.99 W 2682.16 1.14 5010.08 60.25 227.14 3,296.86 2,278.40 S 2,017.07 W 2752.49 0.92 5109.39 61.83 227.50 3,344.94 2,337.30 S 2,080.95 W 2826.93 1.62 5203.58 64.83 227.59 3,387.21 2,394.10 S 2,143.04 W 2898.87 3.19 5299.56 64.66 226.40 3,428.17 2,453.31 S 2,206.52 W 2973.50 1.14 5392.87 63.31 226.51 3,469.09 2,511.08 S 2,267.30 W 3045.99 1.45 5486.09 63.57 226.24 3,510.77 2,568.61 S 2,327.66 W 3118.13 0.38 5580.38 63.54 225.13 3,552.77 2,627.58 S 2,388.06 W 3191.68 1.05 5674.61 62.82 226.05 3,595.28 2,686.43 S 2,448.13 W 3265.00 1.16 5769.13 62.64 226.64 3,638.59 2,744.43 S 2,508.92 W 3337.71 0.59 5863.51 62.69 226.90 3,681.93 2,801.85 S 2,570.00 W 3409.96 0.25 5958.90 62.77 226.20 3,725.63 2,860.16 S 2,631.56 W 3483.19 0.66 INSITE V8.1.0 Page 2Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 6053.79 62.47 226.20 3,769.27 2,918.48 S 2,692.37 W 3556.22 0.32 6146.64 62.60 227.14 3,812.10 2,975.02 S 2,752.30 W 3627.28 0.91 6240.58 62.50 227.55 3,855.40 3,031.50 S 2,813.61 W 3698.69 0.40 6336.26 62.65 228.39 3,899.47 3,088.36 S 2,876.69 W 3770.95 0.79 6430.58 62.80 227.96 3,942.69 3,144.27 S 2,939.16 W 3842.13 0.44 6523.57 62.58 228.74 3,985.36 3,199.18 S 3,000.90 W 3912.15 0.78 6617.74 62.04 229.16 4,029.12 3,253.94 S 3,063.78 W 3982.34 0.70 6712.46 63.21 228.93 4,072.67 3,309.07 S 3,127.31 W 4053.07 1.25 6807.18 64.99 230.03 4,114.04 3,364.42 S 3,192.08 W 4124.36 2.15 6901.57 66.76 229.83 4,152.62 3,419.87 S 3,258.00 W 4196.07 1.89 6995.55 66.41 230.49 4,189.97 3,475.12 S 3,324.22 W 4267.66 0.74 7090.90 64.90 230.38 4,229.27 3,530.46 S 3,391.18 W 4339.55 1.59 7185.57 66.20 230.38 4,268.46 3,585.41 S 3,457.57 W 4410.91 1.37 7279.26 66.23 230.13 4,306.24 3,640.23 S 3,523.49 W 4482.01 0.25 7372.88 66.19 230.38 4,344.01 3,695.00 S 3,589.35 W 4553.05 0.25 7468.22 66.20 229.97 4,382.49 3,750.86 S 3,656.35 W 4625.45 0.39 7561.95 66.09 229.06 4,420.40 3,806.52 S 3,721.54 W 4697.15 0.90 7656.89 66.15 227.79 4,458.83 3,864.12 S 3,786.49 W 4770.66 1.22 7749.14 65.59 227.45 4,496.55 3,920.87 S 3,848.68 W 4842.56 0.69 7844.14 64.30 227.03 4,536.78 3,979.30 S 3,911.86 W 4916.36 1.42 7938.86 64.08 227.23 4,578.02 4,037.31 S 3,974.36 W 4989.56 0.30 8032.81 64.14 226.83 4,619.04 4,094.92 S 4,036.20 W 5062.20 0.39 8125.50 64.11 227.04 4,659.49 4,151.87 S 4,097.13 W 5133.94 0.21 8222.02 63.80 227.20 4,701.87 4,210.88 S 4,160.67 W 5208.40 0.35 8313.92 63.12 227.26 4,742.93 4,266.71 S 4,221.03 W 5278.91 0.74 8411.28 62.18 227.06 4,787.66 4,325.50 S 4,284.44 W 5353.13 0.98 8503.41 62.08 227.39 4,830.73 4,380.81 S 4,344.22 W 5422.98 0.33 8600.42 62.67 227.20 4,875.71 4,439.11 S 4,407.38 W 5496.64 0.63 8691.17 64.04 227.41 4,916.41 4,494.11 S 4,466.99 W 5566.15 1.52 8790.02 63.59 227.25 4,960.03 4,554.23 S 4,532.22 W 5642.14 0.48 8882.67 62.03 227.12 5,002.36 4,610.24 S 4,592.67 W 5712.85 1.69 8976.21 62.04 227.42 5,046.23 4,666.30 S 4,653.35 W 5783.68 0.28 9071.00 61.95 227.15 5,090.73 4,723.07 S 4,714.85 W 5855.41 0.27 9165.30 62.79 227.13 5,134.47 4,779.90 S 4,776.09 W 5927.13 0.89 9258.78 62.00 227.07 5,177.78 4,836.29 S 4,836.77 W 5998.27 0.85 9353.22 62.03 227.12 5,222.10 4,893.06 S 4,897.86 W 6069.89 0.06 9447.52 62.02 227.58 5,266.33 4,949.49 S 4,959.11 W 6141.22 0.43 9541.95 62.38 227.04 5,310.37 5,006.12 S 5,020.51 W 6212.80 0.63 9636.02 62.29 227.14 5,354.05 5,062.85 S 5,081.53 W 6284.36 0.13 9730.64 62.31 227.38 5,398.03 5,119.71 S 5,143.06 W 6356.18 0.23 9825.32 62.82 227.30 5,441.66 5,176.65 S 5,204.85 W 6428.17 0.54 9919.47 63.85 227.56 5,483.91 5,233.57 S 5,266.81 W 6500.17 1.12 10013.65 63.81 227.33 5,525.45 5,290.73 S 5,329.08 W 6572.50 0.22 10109.47 63.92 226.77 5,567.65 5,349.34 S 5,392.04 W 6646.41 0.54 10202.84 63.88 226.62 5,608.73 5,406.85 S 5,453.06 W 6718.72 0.15 INSITE V8.1.0 Page 3Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 10298.09 63.81 227.01 5,650.72 5,465.36 S 5,515.40 W 6792.36 0.37 10390.13 63.74 227.21 5,691.39 5,521.56 S 5,575.89 W 6863.26 0.21 10483.60 63.96 227.44 5,732.58 5,578.43 S 5,637.58 W 6935.14 0.32 10579.65 63.75 228.62 5,774.91 5,636.09 S 5,701.68 W 7008.46 1.12 10675.73 62.80 229.21 5,818.12 5,692.49 S 5,766.36 W 7080.73 1.13 10768.32 63.34 230.34 5,860.05 5,745.79 S 5,829.39 W 7149.57 1.23 10862.66 63.66 231.38 5,902.15 5,799.08 S 5,894.87 W 7219.08 1.04 10957.11 64.49 231.37 5,943.44 5,852.11 S 5,961.23 W 7288.58 0.88 11051.39 66.41 231.89 5,982.61 5,905.34 S 6,028.47 W 7358.52 2.10 11145.65 67.42 232.61 6,019.57 5,958.42 S 6,097.03 W 7428.69 1.28 11240.19 66.98 231.89 6,056.20 6,011.77 S 6,165.94 W 7499.23 0.84 11334.03 66.53 231.07 6,093.24 6,065.47 S 6,233.40 W 7569.68 0.94 11428.50 66.27 229.72 6,131.06 6,120.66 S 6,300.10 W 7641.35 1.34 11522.09 67.92 229.41 6,167.49 6,176.57 S 6,365.71 W 7713.42 1.79 11618.23 68.21 228.84 6,203.40 6,234.93 S 6,433.14 W 7788.34 0.63 11709.22 66.54 228.38 6,238.40 6,290.46 S 6,496.15 W 7859.31 1.89 11806.82 64.65 227.67 6,278.73 6,349.89 S 6,562.23 W 7934.88 2.05 11902.08 64.98 226.79 6,319.27 6,408.43 S 6,625.51 W 8008.81 0.90 11995.01 64.86 225.87 6,358.66 6,466.55 S 6,686.39 W 8081.67 0.91 12089.38 64.07 225.87 6,399.34 6,525.84 S 6,747.51 W 8155.71 0.84 12183.80 62.22 225.46 6,441.99 6,584.70 S 6,807.76 W 8229.11 2.00 12278.58 62.36 224.48 6,486.06 6,644.07 S 6,867.06 W 8302.71 0.93 12372.96 63.01 224.46 6,529.37 6,703.91 S 6,925.80 W 8376.62 0.69 12466.15 63.04 224.54 6,571.64 6,763.15 S 6,984.01 W 8449.80 0.08 12560.81 62.61 224.86 6,614.87 6,823.00 S 7,043.25 W 8523.86 0.54 12655.36 61.95 225.25 6,658.85 6,882.13 S 7,102.49 W 8597.23 0.79 12750.08 62.27 226.26 6,703.16 6,940.54 S 7,162.46 W 8670.11 1.00 12843.46 63.21 226.42 6,745.93 6,997.85 S 7,222.51 W 8741.95 1.02 12937.76 64.14 226.31 6,787.75 7,056.17 S 7,283.68 W 8815.08 0.99 12950.00 63.54 226.00 6,793.15 7,063.78 S 7,291.60 W 8824.61 5.40 13000.00 63.89 225.34 6,815.29 7,095.11 S 7,323.67 W 8863.67 1.38 13050.00 64.25 225.40 6,837.15 7,126.70 S 7,355.67 W 8902.97 0.73 13100.00 64.13 225.38 6,858.92 7,158.31 S 7,387.72 W 8942.29 0.24 13150.00 65.19 223.99 6,880.32 7,190.44 S 7,419.49 W 8982.04 3.29 13200.00 66.20 222.89 6,900.90 7,223.52 S 7,450.82 W 9022.58 2.85 13250.00 66.97 221.37 6,920.77 7,257.55 S 7,481.60 W 9063.87 3.19 13300.00 67.39 219.68 6,940.17 7,292.58 S 7,511.54 W 9105.89 3.23 13350.00 67.54 217.54 6,959.33 7,328.67 S 7,540.36 W 9148.61 3.96 13400.00 66.96 215.39 6,978.67 7,365.75 S 7,567.76 W 9191.88 4.13 13465.21 67.53 212.48 7,003.90 7,415.63 S 7,601.32 W 9249.18 4.21 13560.91 68.34 210.30 7,039.85 7,491.34 S 7,647.51 W 9334.80 2.27 13654.68 69.01 203.92 7,073.98 7,569.05 S 7,687.28 W 9420.54 6.38 13700.47 68.91 199.71 7,090.43 7,608.71 S 7,703.16 W 9463.06 8.58 13748.25 69.13 196.13 7,107.54 7,651.15 S 7,716.88 W 9507.65 7.01 13798.47 69.79 194.58 7,125.16 7,696.50 S 7,729.33 W 9554.67 3.17 INSITE V8.1.0 Page 4Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 13843.43 69.77 191.80 7,140.70 7,737.57 S 7,738.96 W 9596.79 5.80 13892.22 70.19 189.78 7,157.41 7,782.60 S 7,747.54 W 9642.42 3.98 13937.58 71.10 188.49 7,172.44 7,824.85 S 7,754.33 W 9684.88 3.35 13986.39 71.07 186.42 7,188.26 7,870.63 S 7,760.32 W 9730.50 4.01 14032.29 70.92 185.22 7,203.21 7,913.80 S 7,764.72 W 9773.18 2.49 14126.12 71.40 181.77 7,233.52 8,002.43 S 7,770.13 W 9859.76 3.52 14220.43 71.92 178.71 7,263.20 8,091.93 S 7,770.50 W 9945.79 3.13 14315.67 72.54 176.02 7,292.27 8,182.52 S 7,766.33 W 10031.57 2.77 14409.52 74.45 174.84 7,318.93 8,272.21 S 7,759.16 W 10115.66 2.37 14503.54 77.35 176.58 7,341.84 8,363.13 S 7,752.34 W 10201.02 3.57 14598.40 76.68 175.26 7,363.15 8,455.33 S 7,745.77 W 10287.68 1.53 14693.07 75.36 171.48 7,386.03 8,546.56 S 7,735.17 W 10372.28 4.12 14787.08 75.52 167.79 7,409.67 8,636.05 S 7,718.80 W 10453.59 3.80 14881.67 75.70 165.45 7,433.18 8,725.18 S 7,697.60 W 10533.20 2.40 14975.07 77.57 165.52 7,454.77 8,813.14 S 7,674.83 W 10611.26 2.00 15069.85 79.46 163.22 7,473.65 8,902.58 S 7,649.80 W 10690.09 3.10 15165.32 82.07 162.01 7,488.97 8,992.50 S 7,621.64 W 10768.51 3.01 15253.21 84.68 159.32 7,499.11 9,074.86 S 7,592.74 W 10839.47 4.25 15346.63 88.84 158.23 7,504.39 9,161.78 S 7,558.98 W 10913.44 4.60 15443.97 90.93 157.28 7,504.58 9,251.87 S 7,522.13 W 10989.59 2.36 15535.50 91.85 156.00 7,502.36 9,335.87 S 7,485.85 W 11060.05 1.72 15629.09 90.93 154.19 7,500.09 9,420.73 S 7,446.45 W 11130.46 2.17 15722.40 87.91 151.97 7,501.04 9,503.91 S 7,404.22 W 11198.46 4.02 15818.35 87.95 150.39 7,504.50 9,587.91 S 7,357.99 W 11266.15 1.65 15913.45 89.01 154.49 7,507.03 9,672.17 S 7,314.02 W 11334.70 4.45 16007.04 89.04 158.54 7,508.62 9,757.98 S 7,276.74 W 11406.62 4.33 16102.56 89.04 157.36 7,510.22 9,846.50 S 7,240.88 W 11481.53 1.24 16196.54 89.21 161.09 7,511.65 9,934.34 S 7,207.56 W 11556.51 3.97 16291.51 89.87 166.58 7,512.42 10,025.52 S 7,181.13 W 11636.63 5.82 16340.66 90.07 165.02 7,512.44 10,073.17 S 7,169.07 W 11678.98 3.20 16386.38 89.97 165.08 7,512.43 10,117.34 S 7,157.28 W 11718.08 0.26 16481.48 89.35 164.73 7,512.99 10,209.16 S 7,132.51 W 11799.27 0.75 16574.62 89.56 167.57 7,513.88 10,299.58 S 7,110.22 W 11879.81 3.06 16669.94 89.11 171.80 7,514.98 10,393.33 S 7,093.16 W 11965.02 4.46 16762.10 89.18 171.60 7,516.36 10,484.51 S 7,079.85 W 12048.82 0.23 16857.81 89.21 175.28 7,517.71 10,579.57 S 7,068.92 W 12137.00 3.84 16951.97 89.42 177.21 7,518.83 10,673.52 S 7,062.76 W 12225.46 2.06 17047.65 89.11 177.80 7,520.06 10,769.10 S 7,058.59 W 12316.04 0.70 17143.93 88.94 177.76 7,521.70 10,865.29 S 7,054.86 W 12407.33 0.18 17236.54 88.87 177.34 7,523.47 10,957.80 S 7,050.91 W 12495.02 0.46 17331.29 88.29 171.92 7,525.82 11,052.07 S 7,042.04 W 12583.02 5.75 17384.06 88.60 170.67 7,527.25 11,104.21 S 7,034.06 W 12630.84 2.44 17425.03 87.84 170.25 7,528.52 11,144.59 S 7,027.27 W 12667.70 2.12 17520.53 87.88 169.04 7,532.09 11,238.47 S 7,010.12 W 12753.00 1.27 17615.23 88.29 167.62 7,535.25 11,331.16 S 6,990.98 W 12836.61 1.56 INSITE V8.1.0 Page 5Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 17710.36 88.70 165.60 7,537.75 11,423.67 S 6,968.96 W 12919.23 2.17 17805.59 90.38 163.45 7,538.52 11,515.43 S 6,943.55 W 13000.20 2.87 17899.60 90.62 163.49 7,537.70 11,605.55 S 6,916.80 W 13079.21 0.26 17995.02 90.31 163.37 7,536.92 11,697.01 S 6,889.59 W 13159.36 0.35 18089.34 90.00 163.26 7,536.67 11,787.36 S 6,862.51 W 13238.50 0.35 18183.54 88.94 163.34 7,537.54 11,877.58 S 6,835.44 W 13317.51 1.13 18278.42 89.04 163.72 7,539.21 11,968.55 S 6,808.55 W 13397.30 0.41 18370.51 88.67 165.63 7,541.05 12,057.34 S 6,784.21 W 13475.71 2.11 18466.12 88.46 166.42 7,543.44 12,150.09 S 6,761.13 W 13558.27 0.85 18558.52 89.15 165.46 7,545.37 12,239.70 S 6,738.69 W 13638.00 1.28 18655.04 89.21 163.26 7,546.75 12,332.64 S 6,712.67 W 13719.91 2.28 18748.80 88.94 160.95 7,548.27 12,421.84 S 6,683.87 W 13797.46 2.48 18842.94 89.56 159.24 7,549.50 12,510.35 S 6,651.82 W 13873.44 1.93 18938.53 89.63 157.55 7,550.17 12,599.22 S 6,616.63 W 13948.88 1.77 19033.04 89.56 155.91 7,550.84 12,686.03 S 6,579.29 W 14021.75 1.74 19127.59 89.59 153.15 7,551.54 12,771.38 S 6,538.64 W 14092.28 2.92 19221.99 90.04 151.01 7,551.85 12,854.79 S 6,494.44 W 14159.95 2.32 19314.38 89.93 149.73 7,551.87 12,935.10 S 6,448.76 W 14224.23 1.39 19391.69 90.52 149.52 7,551.57 13,001.79 S 6,409.67 W 14277.29 0.81 19458.89 89.56 149.22 7,551.52 13,059.62 S 6,375.43 W 14323.20 1.50 19504.04 90.17 148.64 7,551.63 13,098.29 S 6,352.13 W 14353.79 1.86 19597.81 89.11 148.22 7,552.22 13,178.18 S 6,303.04 W 14416.72 1.22 19691.36 89.62 149.30 7,553.26 13,258.16 S 6,254.53 W 14479.89 1.28 19786.40 89.97 151.07 7,553.60 13,340.61 S 6,207.28 W 14545.79 1.90 19882.04 89.25 152.39 7,554.25 13,424.84 S 6,161.98 W 14613.95 1.57 19979.01 87.29 152.58 7,557.17 13,510.80 S 6,117.20 W 14683.90 2.03 SURVEY FOOTER 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 196.28 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 19,979.01 feet is 14,831.11 feet along 204.36 degrees (True) INSITE V8.1.0 Page 6Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.0 Page 7Job No:-XX-0901388219 Well Name:CD4-96A PB1 Survey Report
