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E o o 2 E 0 y E E Q a 2 i 0 a 0 0 0 e 6 0 cps Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Monday, September 02, 2013 2:59 PM To: AK, OPS GC2 OSM; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wel!pad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; AK, OPS Well Pad Z; Wallace, Chris D (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Well Integrity Coordinator; Regg, James B (DOA) Subject: OPERABLE: Producer Z-115 (PTD#2120550) DART Passed Attachments: Producer Z-115 (PTD#2120550)TIO Plot.docx All, Producer Z-115 (PTD#2120550) passed an outer annulus repressurization test on 09/01/2013. The passing test indicates the outer annulus has integrity. The well is reclassified as Operable. A copy of the TIO is included for reference. Please call with any questions. Jack Disbrow GWO Well Integrity Coordinator 907-659-5102 From: AK, D&C Well Integrity Coordinator Sent: Monday, August 19, 2013 3:53 PM To: AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; 'chris.wallace@alaska.gov'; AK, OPS Well Pad Z; 'jim.regg@alaska.gov' Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer Z-115 (PTD #2120550) OA exceeding MOASP during TAR All, Producer Z-115 (PTD#2120550) outer annulus exceeded MOASP on 08/16/2013 with TBG/IA/OA= 340/1300/1020 psi during scheduled facility maintenance. At this time the well is classified as Under Evaluation for further diagnostics, and may remain online as needed for testing. Plan Forward: 1. Ops: Bring well online 2. DHD: Perform warm OART once thermally stable A copy of the wellbore schematic and the TIO plot has been included. Please call with any questions. Thank you, Laurie Climer 1 Producer Z-115(PTD#2120550)TIO Plot Well:Z-115 4,000 3.000 +TIV —FIA 2000- —.A—OA DOA a 1 Da 060Tf13 ry6'6G'1? 0611513 062213 0611313 07A16313 0711313 0720/13 0727713 0571143 061513 051713 0&2413 0&3183 Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWeIIIntegrityCoordinator@bp.com] Sent: Monday, August 19, 2013 3:53 PM To: AK, OPS Prod Controllers; Cismoski, Doug A; Daniel, Ryan; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; Burton, Kaity; Wallace, Chris D (DOA); AK, OPS Well Pad Z; Regg, James B (DOA) Cc: AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Climer, Laurie A Subject: UNDER EVALUATION: Producer Z-115 (PTD#2120550) OA exceeding MOASP during TAR Attachments: Z-115 Wellbore Schematic.pdf; Z-115 TIO Plot 8-19-13.docx All, Producer Z-115 (PTD#2120550) outer annulus exceeded MOASP on 08/16/2013 with TBG/IA/OA=340/1300/1020 psi during scheduled facility maintenance.At this time the well is classified as Under Evaluation for further diagnostics,and may remain online as needed for testing. Plan Forward: 1. Ops: Bring well online 2. DHD: Perform warm OART once thermally stable A copy of the wellbore schematic and the TIO plot has been included. Please call with any questions. Thank you, Laurie Climer (Alternate:Jack Di,chrrnc) BP Alaska - Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIIIntegrityCoordinatorABP.com 1 TREE= 4-1/16"CNV WELLHEAD= CNV Z-115 SA.__(NOTES: CHROME TBG&LNR ACTUATOR= LEO NT1AL KB. ELEV= 89.94' 1 1 BF.BEV= 55.36' _ H 818' _ 113-3/8"TAM PORT COLLAR KOP= 481' Max Angle= ,_ 66°€'9056' / M ' 2013' Datum MD= 11056' (Vern-ND= 6600'SS L20"CONDUCTOR,94#,H-40,ID= 19.124' J— 80• 2688' l'4-13:3,128-.710:374:131=R3::p3:Tpw, FLEXLOCK LNR HGR,D=9.51" 2721' H 10-3/4'X 9-5/8"XO,D=8.78" 13-3/8"CSG,68#,L-80 BTC,D=12.145" —I 2853' _A , GAS LFT MANDRELS ST M) ND DEV TYPE VLV LATCH FORT DATE 5 3702 2792 62 KBG DOME BK 16 08/08/12 9-5/8"LNR,40#,L-80 BTC, ID=8.835' — 5244: }.--41 4 6642 4203 60 KBG DOME BK 16 08/08/12 3 8794 5187 62 KBG DOME BK 16 08/08/12 2 9990 5785 50 KBG DOME BK 16 08/08/12 Minimum ID =3.726" @ 10770' 1 10524 6196 29 KBG SO BK 24 08/08/12 4-1/2" HES XN NIPPLE ■ ' 10598' H4-1/2"HES X NP,ID=3.813" 7"LNR v ■26#,L-80 VAM TOP HC XO 13CR-80 H 10613' n X VAM TOP . 10627' !-4-1/2"NDPG SINGLE-SENSOR SUB,ID=3.958" Z 10660' —I 7"X 4-1/2"FES TNT PKR,D=3.856" 10694' --14-1/2"HES X NP,D=3.813' ' ' 10770' H4-1/2-I IM XN NIP,D=3.725" 4-1/2"TBG, 12.6#, 13CR-85 VAM TOP, J 10782' 10782' 4-112"WLEG,I)=3.958" .0152 bpf,ID=3.958" —I ELMD TT NOT LOGGED PERFORATION SUNK ARY REF LOG:SLB VSR MODE ON 06/24/12 • 10894' —{7"MARKER JOINT w/RA TAGS j ANGLE AT TOP PERF: 19°@ 10932' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10932- 10950 0 07/24/12 3-3/8" 6 10950-10970 0 07/24/12 3-3/8" 6 10970-10990 0 07/24/12 3-3/8" 6 10990-11010 O 07/24/12 v r 7'LNR,26#. 13CR-80 VAM TOP XO L-80 BTC 11244• " PBTD --i 11286' .AAAAAAAAAAAA•A•AAt•t 7"LNR,26#,L-80 BTC,.0383 bpf,ID=6.276' --{ 11369' DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 06/30/12 DOYON14 ORIGINAL COMPLETION WELL: Z-115 07/13/12 TW/J14/1) DRLG DRAFT COf2FZECTIONS PERMIT No:"2120550 07/14/12 PJC PKR,NKR JOINT,ETC API No: 50-029-23468-00 07/25/12 LE-CLI D GLV C/O(07/21/12) SEC 19,T11N,R12E,846'FNL&2222'FWL - 07/25/12 R 'JMD ADPERFS(07/24/12) 08/14/12 THH'JMD GLV C/O(08/08/12) BP Exploration(Alaska) Producer Z-115 (PTD#2120550) TIO Plot 8/19/2013 WM —TM tN 4--O 00 00 000 ViQS�t] 061''..'3 06Vk•....- GG _.....'� .�- LFRt➢ O�:K•. .. :'-'A11 0IQM] OBU013 06&1] ®/11,13 Schiumberger Drilling&Measurements MWD/LWD Log Product Delivery Customer BP Exploration(Alaska)Inc. Dispatched To: Christine Mahnken Well No Z-115 Date Dispatched: 4/29/2012 Installation/Rig Doyon 14 Dispatched By: Brian Muzny Data No Of Prints No of CDs Surveys 2 1 Received By: Please sign and return to: Drilling&Measurements LWD Division 2525 Gambell Street,Suite 400 Anchorage,Alaska 99501 pwyman@slb.com Fax.907-561-8317 LWD Log Delivery V1.0,01/22/2010 McMains, Stephen E (DOA) From: Lastufka, Joseph N (Northern Solutions) [Joseph.Lastufka@bp.com] Sent: Tuesday, August 21, 2012 8:53 AM To: McMains, Stephen E (DOA) Subject: PBU Z-115/ PTD#212-055 Hi Steve, Please reference the following well: Well Name: PBU Z-115 Permit#: 212-055 API #: 50-029-23468-00-00 Date of Test: 8/19/2012 Type of Test: IPT (Initial Production Test) Choke Size: 37 Choke Unit: 64ths Production Method: Gas Lifted Duration (Hours Tested): 6 Top Reference (Top Perf MD): 10932' Bottom Reference (Bottom Perf MD): 11010' Tubing Flowing (Pressure): 670 Casing Pressure: 1250 Total Test(Rate f/0, W, G): 537/9/599 24-Hour Rate (0, W, G): 2147/ 37/2114 Gravity (Oil, API): N/A GOR (Gas-Oil Ratio): 985 This well began Production on: 8/12/2012 Method of Operations on this date: Gas Lifted RECEIVED STATE OF ALASKA AUG 0 7 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION ,p, WELL COMPLETION OR RECOMPLETION REPORT AND LOGOGCC 1 a Well Status. ®Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended lb. Well Class' 20AAC 25105 20AAC 25110 ®Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One 0 Service 0 Stratigraphic 2. Operator Name' 5 Date Comp.,Susp,or Aband.• 12 Permit to Drill Number. BP Exploration (Alaska) Inc. 7/24/2012 212-055 3. Address. 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 6/7/2012 50-029-23468-00-00 4a Location of Well(Governmental Section) 7 Date T D Reached: 14 Well Name and Number Surface. 6/23/2012 PBU Z-115 4434' FSL,2732' FEL, Sec. 19,T11N, R12E, UM 8. KB(ft above MSL) 89 94 15. Field/Pool(s). Top of Productive Horizon: 1477' FSL, 1308' FEL, Sec. 07,T11N, R12E, UM GL(ft above MSL). 55.9' Prudhoe Bay/Borealis Total Depth. 9.Plug Back Depth(MD+TVD) 1606' FSL, 1389' FEL, Sec. 07,T11N, R12E, UM 11287' 6907' 4b. Location of Well(State Base Plane Coordinates,NAD 27) 10 Total Depth(MD+TVD): 16. Property Designation' Surface' x- 599944 y- 5959240 Zone- ASP4 11379' 6994' ADL 028262&047450 TPI: x- 601236 y- 5966860 Zone- ASP4 11 SSSV Depth(MD+TVD). 17. Land Use Permit. Total Depth.x- 601153 Y- 5966989 Zone- ASP4 None 18 Directional Surve Y Is]Yes ❑No 19 Water depth,if offshore. 20. Thickness of Permafrost(TVD):(Submit electronic and printed information per 20 AAC 25 050) N/A ft MSL 1841' 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: MWD/DIR/GR/RES, MWD/DIR/GR/RES, MWD/DIR/GR/RES/AziDEN/NEU N/A 23CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT PER FT. GRADE . TOPBOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 ,Surface` 80' Surface 80' 42" 260 sx Arctic Set(Approx.) 13-3/8" 68# L-80 _ 35' 2853' 35' 2256' 16" 2567 sx DeepCrete, 315 sx Class'G' 9-5/8" 40# L-80 2688' 5244' 2310' 3527' 12-1/4" 1095 sx Class'G' 7" 26# L-80/13CR80 34' 11369' 34' 6984' 8-3/4" 523 sx LiteCrete, 198 sx Class'G' 24. Open to production or injection? ®Yes 0 No 25 TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) of Top&Bottom,Perforation Size and Number). 3-3/8"Gun Diameter,6 spf 4-1/2", 12.6#, 13Cr85 10782' 10660'/6319' MD TVD MD TVD 10932'-10950' 6574'-6591' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 10950'-10970' 6591'-6610' c;Chu' Tf�di 10970'-10990' 6610'-6629' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10990'-11010' 6629'-6648' i ' -.1� 500' 17 Bbls of Diesel 11.. AO ii 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL-BBL GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO. Test Period Flow Tubing Casing Press: Calculated OIL-BBL' GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR). Press 24-Hour Rate 4 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 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 250.071. None RBDMS AUG 0 9 2012 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit Ori final Only 29. GEOLOGIC MARKERS(List all formations ar'4 markers encountered). 30 FORMATION TESTS NAME ID TVD Well Testes ,]Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 1947 1841' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071 Ugnu 4292' 3074' None Schrader Bluff N 7514' 4607' Schrader Bluff O 7901' 4781' Coleville Mudstone 8770' 5176' HRZ 10709' 6364' Kalubik 10897' 6541' Kuparuk C 10932' 6574' LCU/Kuparuk B 11009' 6647' Kuparuk A 11083' 6715' Miluveach 11165' 6792' Formation at Total Depth(Name): Miluveach 11165' 6792' 31.List of Attachments. Summary of Daily Drilling Reports, Summary of Post-Rig Work,Well Schematic Diagram, Surveys 32. I hereby certify that th foreg ings rue -orrect to the best of my knowledge Y Signed' Joe Lastufk I ` ) Title: Drilling Technologist Date. Sl/ /2 PBU Z-11 212-055 Prepared 8y Name/Number Joe Lastufka, 564-4091 Well Number Permit No /Approval No Drilling Engineer Frank Roach, 564-4373 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 1 a 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 elevation 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 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval) Item 27. Method of Operation. Flowing,Gas Lift, Rod Pump, Hydraulic Pump, Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain) Item 28 Provide a listing of intervals cored and the corresponding formations,and a brief description in this box Submit detailed description and analytical laboratory information required by 20 AAC 25.071 Item 30 Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071 Form 10-407 Revised 12/2009 Submit Original Only BP AMERICA LOT / FIT Summary Well Name: Z-115 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EM W Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP)' (psl) (ppg) 06/14/12 LOT 2,883.00 2,375.60 9.30 510.00 1,657.70 13.43 06/20/12 LOT 5,244.00 3,521.09 9.10 900.00 2,564.50 14.02 Page 1 of 1 North America -ALASKA- BP Page 1 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 6/6/2012 End Date. X3-011D6-C:(7,247,370.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/6/2012 00:00 - 12:00 12.00 MOB P PRE MOVE RIG AND SPOT OVER WELL Z-115 -SKID FLOOR, SPOT ROCK WASHER -NIPPLE UP DIVERTER AND DIVERTER LINE -RIG ACCEPTED ON Z-115 AT 12:00 06/06/2012 12:00 - 00:00 12.00 RIGU P PRE CONTINUE TO RIG UP DIVERTER LINE -LOAD PIPE SHED WITH DRILL PIPE AND BHA -PICK UP 78 JOINTS AND RACK BACK IN DERRICK -INSTALLED AND FUNCTION TESTED ESD ON WELL Z-113 -HELD DIVERTER,AND RIG EVAC DRILL -AFTER ACTION REVIEW- REVIEWED PROCEDURE AND DISCUSSED THIRD PARTY NOTIFICATIONS AND LEVEL"1"NOTIFICATIONS AND WHERE THEY ARE LOCATED(GO BAGS) 6/7/2012 00:00 - 05:00 5.00 RIGU , P PRE -PICK UP HWDP AND RACK BACK IN DERRICK -PICK UP AND RACK BACK COLLARS -HELD DIVERTER,AND RIG EVAC DRILL WITH NEW CREW -AFTER ACTION REVIEW- :DESIGNATED ROCK WASHER TO NOTIFY FORK LIFT OPERATOR THIS WILL BE IMPLEMENTED IN DOYON PROCEDURE 05:00 - 06:00 1.00 RIGU P PRE PJSM,RIG UP GYRO AND SLICK LINE 06:00 - 07:30 1.50 RIGU P PRE GO OVER PRE SPUD CHECKLIST,CHAIN DOWN SURFACE RISER CLEAN OUT SUCTION MANIFOLDS ON BOTH PUMPS 07:30 - 09:30 2.00 BOPSUR P PRE FUNCTION TEST DIVERTER SYSTEM AOGCC REP BOB NOBLE WITNESSED DIVERTER TEST -29 SECONDS FOR ANNULAR TO CLOSE, KNIFE VALVE OPENED INSTANTLY. -AOGCC REP BOB NOBLE REQUESTED THAT FROM THE END OF THE DIVERTER TO EDGE OF THE PAD BE BLOCKED OFF AND A LIGHT POST ON THE EDGE OF THE PAD BE DE-ENERGIZED. 09:30 - 13:00 3.50 RIGU P PRE PICK UP SURFACE BHA 1 13:00 - 14:00 1.00 RIGU P PRE HELD PRE SPUD MEETING WITH CREW 14:00 - 00:00 10.00 DRILL P SURF DRILL AHEAD IN 16"SURFACE HOLE FROM 113'TO 614' -PUW 90K,SOW 90K,RTW 90K -GPM 450,PSI ON 720, PSI OFF 540 -RPM 40,TQ ON 5K,TQ OFF 3K,WOB 20K -RUN GYRO SURVEYS AST 3.73,ART 2.27,ADT 6.00 ADT FOR LAST 24 HRS 6.00 Printed 8/6/2012 10:06:03AM 40 North America -ALASKA- BP ! Page 2 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C:(7,247,370.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) — 6/8/2012 00:00 - 01:30 1.50 DRILL P SURF DRILL AHEAD IN 16"SURFACE HOLE FROM 614'TO 705' -PUW 90K,SOW 90K,RTW 90K -GPM 450,PSI ON 720,PSI OFF 540 -RPM 40,TQ ON 5K,TQ OFF 3K,WOB 20K 01:30 - 02:00 0.50 DRILL P SURF CIRCULATE 2 BOTTOMS UP 500 GPM,630 PSI 02:00 - 02:30 0.50 DRILL P SURF MONITOR WELL BACK REAM OUT OF HOLE FROM 710'TO 115' -GPM 500, PSI 620, RPM 40 02:30 - 04:00 1.50 DRILL P .SURF STAND BACK 8"COLLARS, LAY DOWN PONY COLLAR, DRAIN MOTOR 04:00 - 06:00 2.00 DRILL P SURF MAKE UP 12-1/8"STABILIZER,ARCVISION AND TELESCOPE MWD. 06:00 - 06:30 0.50 DRILL P SURF INSPECT AND SERVICE DRAW WORKS. 06:30 - 08:00 1.50 DRILL P - SURF MAKE UP 7"DRILL COLLARS AND JARS. 08:00 - 09:00 1.00 DRILL P SURF RUN IN THE HOLE FROM THE DERRICK WITH 5"HWDP TO 705'. 09:00 - 16:00 7.00 DRILL P SURF DRILL FROM 705'TO 1,040'. -PUW=115K,SOW=102K,ROT=108K. -GPM=520, PSI ON=1000, PSI OFF=800. -RPM=40,TORQ ON=5K,TORQ.OFF=3K. WOB=25K. 16:00 - 17:00 1.00 DRILL N DFAL 1,040.00 SURF TROUBLE SHOOT MWD. 17:00 - 00:00 7.00 DRILL P SURF DRILL FROM 1,040'TO 1,325'. -PUW=120K,SOW=108K,ROT=114K. -GPM=520,PSI ON=1100, PSI OFF=920. -RPM=40,TORQ ON=7K,TORQ.OFF=3K. -WOB=25K. -FIRE DRILL CRT=105 SECONDS MOSES CREW AST=4.50 HRS,ART=6.28 HRS,ADT=10.78 HRS. 6/9/2012 00:00 - 12:00 12.00 DRILL P SURF DRILL FROM 1,325'TO 1,955'. -PUW=135K,SOW=111K,ROT=120K. -GPM=520, PSI ON=1190, PSI OFF=1020. -RPM=40,TORQ ON=8K,TORQ.OFF=4K. -WOB=25K. -AST=4.06 HRS,ART=5.10 HRS,ADT=9.16 HRS,JARS=114 HRS. 12:00 - 00:00 12.00 DRILL P SURF DRILL FROM 1,955'TO 2,747'. -PUW= 145K,SOW=110K, ROT=123K. -GPM=520, PSI ON= 1400, PSI OFF= 1280. -RPM=40,TORQ ON=8K,TORQ.OFF=4K. -WOB=30K. -AST=9.26 HRS,ART=7.05 HRS,ADT= 16.31 HRS, JARS= 122.9 HRS. -HYDRATES ENCOUNTERED AT 2360'AND 2730' 6/10/2012 00:00 - 02:30 2.50 DRILL P SURF DRILL FROM 2,747'TO 2,863'. -PUW=136K,SOW=115K, ROT= 125K. -GPM=600, PSI ON= 1440, PSI OFF= 1310. -RPM=40,TORQ ON=7K,TORQ.OFF=4K. -WOB=30K. -HYDRATES ENCOUNTERED AT 2800'. Printed 8/6/2012 10 06:03AM North America -ALASKA- BP Page 3 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 79. 02:30 - 05:00 2.50 DRILL P SURF CIRCULATE 2 BOTTOMS UP RACK BACK STANDS WHILE CIRCULATING TO 2,748'. -GPM=600, PSI= 1310. -RPM=40,TORQ=4K. 05:00 - 10:30 5.50 DRILL P SURF PUMP OUT OF THE HOLE FROM 2,683'TO 757'. -GPM=550, PSI=1250. RPM=40,TORQ=4K. ENCOUNTERED TIGHT SPOTS AT 2,425'TO 2,373',2,058'TO 1,999',1,860'TO 1,812'. WORK PIPE UNTIL TIGHT SPOTS CLEANED UP. 10:30 - 11:00 0.50 DRILL P SURF MONITOR WELL FOR 10 MINUTES,WELL STATIC.BLOW DOWN TOP DRIVE. 11:00 - 14:00 3.00 DRILL P SURF RUN IN THE HOLE FROM 757'TO 1,232'. ENCOUNTERED TIGHT SPOT AT 1,100'. ORIENTED HIGH SIDE AND POUNDED DOWN REPEATEDLY WITH NO SUCCESS. PUMP 40 SPM,POUNDED DOWN AND GOT THROUGH. BACK REAM HOLE CLEAN AND RUN BACK THROUGH WITH PUMPS OFF WITH NO ISSUES. ENCOUNTERED TIGHT SPOT AT 1,133'(TOP OF SV3),BRIDGED OFF AND TOOK WEIGHT. ORIENTED HIGH SIDE AND POUNDED DOWN REPEATEDLY WITH NO SUCCESS. ATTEMPTED SLOW ROTATION WITHOUT PUMPS NO SUCCESS.PUMP 40 SPM AND 20 RPM POUNDED DOWN WITH NO SUCCESS. PUMP 400 GPM,40 RPM AND WORK THROUGH SUCCESSFULLY. BACK REAM THROUGH AND OBSERVED WOOD ACROSS THE SHAKERS. RAN BACK THROUGH WITH PUMPS OFF WITH NO ISSUE. ENCOUNTERED TIGHT SPOT AT 1,240'. OBSERVED WEIGHT INCREASE. WASH AND REAM THROUGH WITH 40 SPM. BACK REAM THROUGH,NO ANOMALIES OBSERVED AT SHAKERS. RUN BACK THROUGH WITH PUMPS OFF,NO ISSUES. 14:00 - 15:00 1.00 DRILL P SURF RUN IN THE HOLE FROM 1 732'TO 2,748' WASH TO BOTTOM FROM 2,748'TO 2,863'NO FILL ON BOTTOM. 15:00 - 20:30 5.50 DRILL P SURF CIRCULATE AND CONDITION MUD, RACK BACK A STAND EACH BOTTOMS UP TO 2,568'. -MW CLIMBING UP TO 9.9 PPG IN AND OUT, FINAL MW BEFORE RUNNING TO BOTTOM 9.5 PPG IN,9.8 PPG OUT -GPM=530, PSI= 1150. -RPM=40,TORQ=5K. 20:30 - 21:00 0.50 DRILL P SURF MONITOR WELL FOR 10 MINUTES,WELL STATIC. RUN IN THE HOLE TO 2,863'. 21:00 - 23:00 2.00 DRILL P SURF PULL OUT OF THE HOLE ON ELEVATORS FROM 2,863'TO 757'. -PUW=149K,SOW=110K. Printed 8/6/2012 10:06:03AM North America ALASKA- BP • Page 4 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C:(7,247,370.00) Project: Prudhoe Bay Site: PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P SURF PUMP OUT OF THE HOLE FROM 757'TO 547' DUE TO SWABBING -PUMP 1 BPM,PUW=95K,SOW=95K, 10K-15K DRAG I-PULLED 35K OVER AT 715'ABLE TO WIPE THROUGH 6/11/2012 00:00 - 01:00 1.00 DRILL P SURF CONTINUE TO PULL OUT OF HOLE FROM 547' TO 363' I-PUMPING AT 1 BPM,PUW=90K,SOW=90K -PULLED 35K OVER AT 530'MADE SEVERAL ATTEMPTS TO WIPE THROUGH -INCREASED GPM TO 450,560 PSI STILL UNABLE TO WIPE THROUGH -BACKREAM THROUGH TIGHT SPOT WITH 40 RPM,5K TQ -RAN BACK IN WITHOUT PUMPS OR ROTATION -PULLED BACK OUT NO ISSUES 01:00 - 03:30 2.50 DRILL P SURF PJSM WITH ALL PERSONNEL,RACK BACK COLLARS,LAY DOWN BHA#2 03:30 - 04:00 0.50 DRILL _ P SURF CLEAN AND CLEAR FLOOR OF BHA COMPONENTS 04:00 - 10:30 6.50 CASING P SURF I RIG UP TO RUN 13-3/8"CASING. -SIMOPS: RIG UP BACK STOP ON PIPE SKATE, BREAK PUP JOINT ON LANDING HANGER, PICK UP TAM PORT COLLAR, PERFORM A DUMMY RUN WITH HANGER AND LANDING JOINT. 10:30 - 23:00 12.50 CASING P SURF RUN 13-3/8"68#L-80 BTC CASING TO 2,818'. FILL EVER?JOINT,CIRCULATE EVERY 10 JOINTS DOWN AT 5 BPM,35 BBLS. WASH DOWN LAST JOINT TO LAND CASING ON LANDING RING AT 2,853'. 23:00 - 23:30 0.50 CASING P SURF RIG DOWN FRANKS FILL UP TOOL,BLOW DOWN TOP DRIVE,INSTALL CEMENT HEAD. 23:30 - 00:00 0.50 CASING P SURF CIRCULATE AND RECIPROCATE CASING. -3 BPM,150 PSI. -PUW=230K,SOW= 155K. 6/12/2012 00:00 - 07:30 7.50 CASING P SURF CIRCULATE AND RECIPROCATE 13-3/8" CASING. CONDITION MUD. STAGE UP PUMPS INCREMENTAL: -3 BPM,195 PSI -4 BPM,208 PSI -5 BPM,242 PSI -6 BPM,250 PSI -7 BPM,279 PSI -8 BPM,310 PSI -SCHLUMBERGER ON LOCATION AT 02:30, RIG UP SLB CEMENTERS WHILE CIRCULATING. I-SPOT REQUIRED TRUCKS WHILE CIRCULATING. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 5 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370 00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task ' Code NPT NPT Depth Phase Description of Operations ' 07:30 - 14:00 6.50 CEMT P (ft) SURF PJSM SURFACE CEMENT JOB WITH ALL CY‘ PERSONNEL. -PUMP 10 BBLS WATER,TEST LINES TO 250 PSI LOW AND 4500 PSI HIGH FOR 5 MINUTES EACH. -PUMP 103.8 BBLS OF 10.2-PPG MUD PUSH AT 6 BPM. -DROP BOTTOM PLUG. A" -PUMP 832 BBLS OF 11.0-PPG DEEP CREETE LEAD SLURRY(2554SKS)YIELD=1.82 FT/SK AT 6 BPM. -PUMP 65 BBLS OF 15.8-PPG TAIL SLURRY (318SKS)1.16 FT/SK AT 6 BPM. -DROP TOP PLUG AND KICK OUT WITH 10 BBLS OF WATER. -SWAP TO RIG PUMPS AND DISPLACE WITH 401 BBLS OF 9.8-PPG DRILL PLEX. -BUMP PLUG AT 4009 STROKES(400.9-BBLS), 450 PSI, PRESSURE UP TO 950 PSI,HOLD FOR 5 MINUTES. -BLEED OFF PRESSURE AND CHECK FLOATS;FLOATS HELD. -PRESSURE TO 3000 PSI FOR 5 MINUTES TO .CHECK CASING AND HELD. FULL RETURNS THROUGOUT CEMENT JOB WITH425..8BLS TOTAL CEMENT TO l' SURFACE. -CIP AT 13:15 HRS.FINAL LIFT PRESSURE= 450 PSI.CALCULATED LIFT PRESSURE=400 PSI 14:00 - 15:00 1.00 CEMT P SURF RIG DOWN CEMENT HEAD AND LANDING JOINT AND FLUSH. 15:00 - 16:00 1.00 CEMT P SURF FLUSH DIVERTER STACK AND FLOW LINE. 16:00 - 17:00 1.00 CEMT P SURF CLEAR RIG FLOOR OF 13-3/8"CASING EQUIPMENT, REMOVE LONG ELEVATORS, CLEAN CEMENT VALVES. 17:00 - 20:00 3.00 DIVRTR P SURF NIPPLE DOWN DIVERTER STACK,RISER, FLOW LINE. REMOVE DIVERTER AND SURFACE HYDRILL FROM CELLAR. 20:00 - 00:00 4.00 WHSUR P SURF NIPPLE UP FMC SLIP ON WELL HEAD,TEST 250 PSI LOW FOR 5 MINUTES,1000 PSI HIGH FOR 15 MINUTES. INSTALL BOP STACK, CHOKE HOSE,TURNBUCKLES,RISER. 6/13/2012 00:00 - 04:30 4.50 BOPSUR P SURF CONTINUE TO NIPPLE UP BOPE -MAKE UP CHOKE LINE,FLOW LINE -PERFORM VISUAL DERRICK INSPECTION -LOAD AND STRAP DRILL PIPE IN THE PIPE SHED ,/ 04:30 - 11:00 6.50 BOPSUR P SURF PICK UP 5"TEST JOINT,MAKE UP BOPE TEST / EQUIPMENT -TEST ALL BOPE TO 250 PSI LOW/3500 PSI 64119 HIGH FOR 5 MINUTES EACH(SEE ATTACHMENTS). -BOP TEST WITNESS WAIVED BY AOGCC REPRESENTATIVE BOB NOBLE 11:00 - 12:00 1.00 BOPSUR P SURF RIG DOWN TEST EQUIPMENT. -BLOW DOWN LINES -INSTALL WEAR RING -LAY DOWN TEST JOINT 12:00 - 12:30 0.50 DRILL P SURF INSPECT AND SERVICE TOP DRIVE. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP ` Page 6 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: 1X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release: 6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:30 - 13:30 1.00 DRILL P SURF MOBILIZE BHA#3 TOOLS TO THE RIG FLOOR. 13:30 - 14:30 1.00 DRILL P SURF INSTALL BAILS AND ELEVATORS. MAKE UP 5" SAFETY JOINT WITH FOSV AND STAGE IN PIPE SHED. TRANSFER 5"HWDP TO DRILLER SIDE TO MAKE ROOM FOR RACKING BACK 5"DRILL PIPE. 14:30 - 16:30 2.00 DRILL P SURF -PICK UP 5"DRILL PIPE SINGLES FROM THE PIPE SHED AND RUN IN THE HOLE WITH MULE SHOE TO 1890'. 16:30 - 17:00 0.50 DRILL P SURF CIRCULATE DRILL PIPE VOLUME TO CLEAR DRILL PIPE. -BLOW DOWN TOP DRIVE. 17:00 - 19:30 2.50 DRILL P SURF CUT AND SLIP 59'OF DRILLING LINE. 19:30 - 21:00 1.50 DRILL P SURF PULL OUT OF THE HOLE FROM 1980'TO SURFACE AND RACK BACK STANDS OF 5" DRILL PIPE. 21:00 - 23:00 2.00 DRILL r P .- SURF RIG UP AND TEST 13-3/8"CASING. TEST 250 PSI LOW FOR 5 MINUTES,3500 PSI HIGH FOR 30 MINUTES-PASS. BLOW DOWN 0� KILL/CHOKE LINES AND MANIFOLD. RECIEVED APPROVAL FROM WTL MIKE SCHULTZ TO PROCEED. WELLBORE BARRIERS:TESTED BOPE, CEMENTED AND PRESSURE TESTED 13-3/8" CASING,9.3 PPG DRILPLEX. ANNULUS BARRIERS:CEMENTED ANNULUS, PRESSURE TESTED WELLHEAD. 23:00 - 00:00 1.00 DRILL P SURF RIG DOWN TEST EQUIPMENT,MOBILIZE TOOLS FOR BHA#3. 6/14/2012 00:00 - 03:30 3.50 DRILL P INTI MAKE UP BHA#3, 12-1/4"INTERMEDIATE DRILLING ASSEMBLY. _-- ------._. ..----- -648'OVERALL LENGTH. 03:30 - 04:00 0.50 DRILL P INTI SINGLE IN THE HOLE,PICKING 5"DRILL PIPE FROM THE PIPE SHED. -FROM 648'TO 1120'. 04:00 - 04:30 0.50 DRILL P INTI SHALLOW HOLE TEST MWD. -500 GPM AND 830 PSI. -GOOD TEST. 04:30 - 05:30 1.00 DRILL P INTI RUN IN THE HOLE ON STANDS OF 5"DRILL PIPE FROM 1120'TO 2633'. FILL PIPE EVERY 20 STANDS. -KICK WHILE DRILLING CRT=116 SECONDS. 05:30 - 06:30 1.00 DRILL P INTI RIG UP AND TEST CASING TO 1000 PSI TO ENSURE TAM PORT IS HOLDING PROPERLY, GOOD TEST.RIG DOWN TEST EQUIPMENT. 06:30 - 07:00 0.50 DRILL P INTI WASH FROM 2633'TO 2756'.TAG CEMENT AT 2756'. -PUMP 500-GPM,122-SPM,1030-PSI. -40-RPM,8K-TORQ. 07:00 - 08:00 1.00 DRILL P INTI ARILL OUT FLOAT EQUIPMENT AND SHOE FROM 2756' I 0 2843'. 08:00 - 08:30 0.50 DRILL P INTI OBSERVE THICK MUD BACK FROM CEMENT DRILL OUT. SLOW DOWN PUMPS TO 68 SPM, 162 GPM,310 PSI. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 7 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) i Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project: Prudhoe Bay Site: PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To IHrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:30 - 09:30 1.00 DRILL P INTI RACK BACK ONE STAND FROM 2843'TO 2822'. CIRCULATE AT 57 SPM,232 GPM,WITH 410 PSI. -PREPARE PITS FOR UPCOMING DISPLACEMENT FROM 9.5-PPG DRILL PLEX TO 9.0-PPG LSND MUD. 09:30 - 11:30 2.00 DRILL P INTI PJSM AND DISPLACE MUD SYSTEM FROM 9.5-PPG DRILL PLEX TO 9.0-PPG LSND MUD. -PUMP 40 BBLS HI-VIS 9.1-PPG SWEEP. -PUMP LSND MUD AT 90-SPM,371-PSI, 80-RPM,8K-TORQ. SPR 2723'-MD,2327'-TVD,MW 9.5-PPG,10:30 HRS. -#1 MP 2-BPM,280-PSI,3-BPM,390-PSI -#2 MP 2-BPM,270-PSI,3-BPM,390-PSI 11:30 - 12:00 0.50 DRILL P INTI 10 MINUTE FLOW CHECK,NO FLOW. BLOW DOWN TOP DRIVE,RACK BACK 1 STAND. -CLEAN SUCTION PITS OF DRILL PLEX MUD. 12:00 - 13:00 1.00 DRILL P INTI DRILL FROM 2863'TO 2883'. DRILL REMAINING SHOE,20'OF RATHOLE OF NEW FORMATION. 13:00 - 14:00 1.00 DRILL P - INT1 CIRCULATE BOTTOMS UP. -MW IN=9.3-PPG,MW OUT=9.3-PPG. -RACK BACK ONE STAND. 14:00 - 15:00 1.00 DRILL P INTI PERFORM LOT TO EQJJIVALENTMUD WEIGHT OF 14 41-PPG WITH 9.3-PPG LSND. TVD=2387'. APPROVED BY DRILLING ENGINEER TO PROCEED. 15:00 - 00:00 9.00 DRILL P INTI DRILL FROM 2883'TO 4054'. -PUW= 147K,SOW=108K, ROT=127K. -PUMP 750 GPM, PSI ON= 1860, PSI OFF= 1580. -RPM=80.TORQ ON=9K,TORQ OFF=7K. WOB=30K. -OBSERVED HYDRATES FROM 2883' THROUGH 4054'. -AST-0.21 HRS,ART-4.45 HRS,ADT-4.66 HRS, BIT-4.66 HRS. SPR 2820'-MD,2372'-TVD,MW 9.3-PPG,12:30 HRS. -#1 MP 2-BPM,200-PSI,3-BPM,220-PSI -#2 MP 2-BPM,190-PSI,3-BPM,210-PSI SPR 3391'-MD,2630'-TVD,MW 9.2-PPG,18:50 HRS. -#1 MP 2-BPM,120-PSI,3-BPM,150-PSI -#2 MP 2-BPM,140-PSI,3-BPM,160-PSI SPR 3865'-MD,2869'-TVD,MW 9.4-PPG,22:17 HRS. -#1 MP 2-BPM,130-PSI,3-BPM,150-PSI -#2 MP 2-BPM,130-PSI,3-BPM,150-PSI **DOWNHOLE BARRIERS:9.4-PPG LSND KWF,TESTED BOPE** **ANNULUS BARRIERS:CEMENTED ANNULUS,PRESSURE TESTED WELLHEAD** Printed 8/6/2012 10:06:03AM • North America -ALASKA- BP Page 8 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011 D6-C: (7,247,370.00) Project: Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM 1Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. 1UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/15/2012 00:00 - 08:30 8.50 DRILL P INTI DIRECTIONALLY DRILL FROM 4054'TO 5254' INTERMEDIATE SECTION TD. -PUW=205K,SOW=100K,ROT=140K. -PUMP 750 GPM, PSI ON=2040, PSI OFF= 1800. -RPM=80.TORQ ON=15K,TORQ OFF= 13K. -WOB=30K. **DOWN HOLE BARRIERS:9.6-PPG LSND KWF,TESTED BOPE** SPR 5252'-MD,3531'-TVD,MW 9.5-PPG,08:30 HRS. -#1 MP 2-BPM,140-PSI,3-BPM,210-PSI #2 MP 2-BPM,140-PSI,3-BPM,210-PSI 08:30 - 10:30 2.00 DRILL P INTI ROTATE AND RECIPROCATE WHILE CIRCULATING HOLE CLEAN. -GPM=750, PSI= 1800. -RPM=100,TORQ= 15K. -PUMP 3 BOTTOM UP TOTAL. 1-MONITOR WELL 10-MINUTES. NO FLOW. !-MW IN 9.6-PPG,MW OUT 9.6-PPG 10:30 - 14:00 3.50 DRILL P INT1 BACK REAM, PUMPING OUT OF THE HOLE FROM 5254'TO 2917' GPM=750, PSI=1770. -RPM=100,TORQ=14K. 14:00 - 15:00 1.00 DRILL P INTI MAD PASS FROM 2917'TO 2690'. -GPM=750, PSI=1530. -RPM=80,TORQ=8K. -MONITOR WELL AT 13-3/8"SHOE.NO FLOW 15:00 - 16:30 1.50 DRILL P INTI RIH WITH 1 STAND OF DRILL PIPE TO POSITION BIT AT 9-5/8"CASING SHOE AT 2822'. CIRCULATE 2 BOTTOMS UP WHILE ROTATING AND RECIPROCATING 1-GPM=744, PSI= 1540. -RPM=40,TORQ=7K. 16:30 - 18:00 1.50 DRILL P INTI 10 MINUTE FLOW CHECK,NO FLOW. -RIH ON ELEVATORS WITH 5"DRILL PIPE FROM 2822'TO 5191'. 18:00 - 20:00 2.00 DRILL P INTI WASH DOWN FROM 5191'TO 5254'. -NO FILL ENCOUNTERED ON BOTTOM. STAGE UP PUMPS,CIRCULATE BOTTOMS UP WHILE ROTATING AND RECIPROCATING. -GPM=710, PSI=1650. -RPM=90,TORQ=7K. -PUW=200K,SOW=105K, ROT=140K. 20:00 - 22:00 2.00 DRILL P INTI 1 MONITOR WELL FOR 10 MINUTES,NO FLOW. 1-POOH ON ELEVATORS FROM 5254'TO 2822'. -MU TOP DRIVE TAKE CHECK SHOT SURVEY AT 3150'-MD -HOLE LOOKS GOOD. 22:00 - 22:30 0.50 DRILL P INTI MONITOR WELL FOR 10 MINUTES,NO FLOW. MU TOP DRIVE TO CIRCULATE BOTTOMS UP t\4 AT CASING SHOE. -STAGE UP PUMP,CIRCULATE 10-MINUTES 1,^' WHEN RIG GAS ALARM BEGINS TO INDICATE H2S. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 9 of 18 Operation Summary Report Common Wet Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 DRILL N SFAL 2,822.00 INTI SHUT IN WELL WITH ANNULAR PREVENTER FAST SHUT IN PROCEDURE PER STANDING ORDERS TO DRILLER.WELL SECURE. S -EVACUATE RIG DUE TO H2S ALARM. ALL PERSONNEL ACCOUNTED FOR AT UPWIND MUSTER AREA. -LEVEL"0"NOTIFICATIONS MADE PER ADW EMERGENCY MANAGEMENT PLAN. -AUTHORIZATION RECEIVED FOR TOUR PUSHER AND DERRICKMAN TO RE-ENTER RIG AT 23:10-HRS;DON SCBA'S RE-ENTER RIG AS PER BP/DOYON PROCEDURE WITH GAS DETECTOR. NO GAS DETECTED WITHIN CONFINES OF RIG OR ON LOCATION. 6/16/2012 00:00 - 00:30 0.50 DRILL N SFAL 2,8-22.00 INTI AUTHORIZATION TO OPEN WELL FROM OPS SUPERINTENDENT AND WTL VERIFY NO FLOW THROUGH CHOKE. -OPEN ANNULAR PREVENTER -FLOW CHECK WELL FOR 10-MINUTES, NO FLOW. -DOYON ELECTRICIAN VERIFY CALIBRATION OF LEL AND H2S ALARMS AND SENSORS. ALL OPERATIONAL AND CORRECT. MW IN 9.6-PPG,MW OUT 9.6-PPG 00:30 - 01:30 1.00 DRILL P INTI CIRCULATE 2 BOTTOMS UP INSIDE 13-3/8" CASING AT 2822'-MD ROTATE AND RECIPROCATE WHILE CIRCULATING -750 GPM,1490-PSI -20-RPM,5-7K TORQUE 01:30 - 02:30 1.00 DRILL P INTI MONITOR WELL 10-MINUTES WITH NO FLOW. MINIMUM HYDRATES WERE OBSERVED WHILE MONITORING WELL. -PUMP DRY JOB, BLOW DOWN TOP DRIVE. -DROP 2.38"OD DRIFT INSIDE DRILL-PIPE FOR UPCOMING 9-5/8"LINER RUN 02:30 - 05:00 2.50 DRILL P INTI POOH ON ELEVATORS FROM 2822'TO BHA. -HEIGHTENED AWARENESS PULLING BHA THROUGH TAM PORT COLLAR AT 817' MW IN 9.6-PPG,MW OUT 9.6-PPG 05:00 - 06:30 1.50 DRILL P INTI PJSM-LAYING DOWN BHA.. -RACK IN DERRICK HWDP AND JARS. -LAY DOWN COLLARS AND BHA TO PIPE SHED **DOWN HOLE BARRIERS:9.6-PPG LSND KWF,TESTED BOPE **5"SHEAR JOINT WITH FOSV READILY AVAILABLE FOR NON-SHEARABLES ACROSS BOPE. 06:30 - 10:00 3.50 BOPSUR P INTI CLEAN AND CLEAR RIG FLOOR. PJSM, LAY DOWN TOOLS VIA BEAVER SLIDE. PJSM, CHANGE OUT 3-1/2"X 6"VARIABLE RAMS TO 9-5/8"RAMS. 10:00 11:00 1.00 BOPSUR P INTI TEST 9-5/8"RAMS TO 250 PSI LOW/3500 PSI HIGH FOR 5 MINUTES EACH. 11:00 - 12:00 1.00 BOPSUR P INTI RIG DOWN TEST EQUIPMENT AND BLOW DOWN LINES. RIG UP AND INSTALL WEAR RING. MOBILIZE TOOLS TO THE RIG FLOOR FOR UPCOMING 9-5/8"LINER RUN" 12:00 - 13:30 1.50 CASING P INTI RIG UP EQUIPMENT TO RUN 9-5/8"CASING. -SPILL DRILL CRT=95 SECONDS. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 10 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 6/6/2012 End Date: ,X3-011D6-C: (7,247,370.00) Project: Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task ; Code NPT ' NPT Depth Phase Description of Operations (hr) (ft) _ 13:30 - 18:30 5.00 CASING P INTI RUN 9-5/8"40#L-80 BTC CASING. RUN SHOE 4( TRACK AND CHECK FLOATS,GOOD. -BAKERLOK ALL CONNECTIONS BELOW LANDING COLLAR -USE BEST-O-LIFE 2000 NM THREAD DOPE t'" te ON ALL CONNECTIONS -FILL PIPE EVERY JOINT IN THE HOLE AND -TOP OFF EVERY 10 JOINTS IN THE HOLE -INSTALL CENTRALIZERS ON FIRST 25 • JOINTS 18:30 - 19:30 1.00 CASING P INTI RIG DOWN CASING EQUIPMENT. PICK UP BAKER 10-3/4"X 13-3/8"FLEX-LOCK HANGER, MIX UP PAL MIX,SECURE HANGER,PICK UP ONE JOINT OF 5"DRILL PIPE. 19:30 - 21:00 1.50 CASING P INTI CIRCULATE 200 BBLS WHILE WAITING ON PAL MIX TO SET UP. -5 BPM=100 PSI -6 BPM= 110 PSI -7 BPM= 120 PSI -8 BPM= 140 PSI -9 BPM= 150 PSI -10BPM=170 PSI 21:00 - 23:30 2.50 CASING P INTI RUN IN THE HOLE WITH 9-5/8"CASING ON 5" DRILL PIPE,FILL EVERY 5 STANDS. OBTAIN PUW/SOW EVERY 10 STANDS. PICK UP ONE STAND OF 5"DRILL PIPE AND TAG UP AT 5254',RACK STAND BACK. 23:30 - 00:00 0.50 CASING P INTI REMOVE 15'PUP AND 6'PUP ON BOTTOM OF CEMENT HEAD. MOBILIZE 1,31'JOINT OF 5" DRILL PIPE TO THE RIG FLOOR TO REPLACE PUP JOINTS. 6/17/2012 00:00 - 01:00 1.00 CASING P INTI RIG UP CEMENT HEAD WITH A SINGLE OF 5" DRILL PIPE(31')ON BOTTOM. 01:00 - 03:45 2.75 CEMT P INTI CIRCULATE AND CONDITION MUD WHILE RECIPROCATING PIPE. STAGE PUMPS UP SLOWLY TO 3 BPM AND GRADUALLY TO 5 BPM. CIRCULATE ANNULAR VOLUME AND STAGE PUMPS UP TO 11 BPM. -RECIPROCATE IN 10'-15'STROKES. Printed 8/6/2012 10:06:03AM North America-ALASKA- BP Page 11 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release: 6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 03:45 06:00 2.25 CEMT P INTI PJSM WITH SCHLUMBERGER,DOYON, CH2MHILL,AND BP ON CEMENT JOB. -PUMP 5 BBLS OF WATER TO FILL LINES. -CLOSE LOWER TIW OF TD CEMENTING HEAD. -TEST LINES TO LOW 250 PSI AND HIGH 4500 PSI. -OPEN LOWER TIW OF TD CEMENTING HEAD. PUMP 80 BBLS OF 12.5-PPG MUD PUSH. -(04:30)MIX AND PUMP 228 BBLS(1095 SACKS)OF 15.8-PPG CLASS G TAIL SLURRY. -YIELD=1.17 FT3/SK. FINAL LIFT PRESSURE AT 640 PSI. CALCULATED LIFT PRESSURE AT 650 PSI. -DROP DART AND KICK OUT WITH 10 BBLS OF WATER FROM SLB CEMENTERS. CLOSE 2"DEMCO TO ISOLATE RIG FROM CEMENTERS. -PUMP 16GBBLS 9.5-PPG LSND,70 BBS HI-VIS SWEEP. - -PLUG DID NOT BUMP,PUMP 2226 STROKES W/96%PUMP EFFICIENCY. -SLACK OFF ALL WEIGHT. PICK UP TO NEUTRAL WEIGHT OF 110K. ROTATE TO RELEASE PACKER. SET DOWN 60K WHILE ROTATING. POSITIVE VERIFICATION AT FLOOR THAT PACKER SET. PICK UP AND REPEAT SETTING DOWN WEIGHT. 06:00 - 08:00 2.00 CEMT P. INTI BLOW DOWN CEMENT LINE AND RIG DOWN; CAP CEMENT HEAD. CIRCULATE WITH RIG, PUMP 173 SPM,702 GPM,760 PSI. TOTAL STROKES=4502. 08:00 - 09:00 1.00 CEMT P INTI LAY DOWN DRILL PIPE SINGLE AND FLUSH CEMENT VALVES. 09:00 - 11:30 2.50 CEMT P INTI PRESSURE UP TO 500 PSI. PICK UP 35 FT TO CLEAR RUNNING TOOL. CIRCULATE OUT CEMENT, STAGE PUMPS UP TO 128 SPM,518 GPM,420 PSI. RECIPROCATE IN 45' STROKES. CIRCULATE 42 BBL CEMENT TO SURFACE 11:30 - 15:00 T 3.50 CEMT P INTI PULL OUT OF THE HOLE FROM 2688'TO BAKER RUNNING TOOL. -MW IN=9.5,MW OUT=9.5. 15:00 - 15:30 0.50 CEMT P INTI LAY DOWN BAKER RUNNING TOOL. 15:30 - 17:30 2.00 BOPSUR P INTI MAKE UP 1 JOINT OF 5"DRILL PIPE AND THE STACK WASHER.MIX UP BLACK WATER. FLUSH STACK AT 9 BPM,80 RPM. MOBILIZE 4"FLOOR VALVES TO THE RIG FLOOR. 17:30 - 18:00 0.50 BOPSUR P INTI PULL WEAR BUSHING AND LAY DOWN RUNNING TOOL. 18:00 - 20:30 2.50 BOPSUR P INTI CHANGE OUT UPPER RAMS FROM 9-5/8"TO 3-1/2"X R"VARIABLE RAMS.LAY DOWN AND INSTALL MOUSE HOLE. FUNCTION HCR KILL AND HCR CHOKE. 20:30 - 21:30 1.00 BOPSUR P INTI RIG UP TO WITH 4"TEST JOINT, INSTALL TEST PLUG,AND TEST EQUIPMENT. MAKE J UP(2)-4"FOSV AND(1)-4"DART VALVE. /( 21:30 - 00:00 2.50 BOPSUR P INTI TEST ANNULAR PREVENTER,3-1/2"X 6" """ ��\ RAMS,2-7/8"X 5"RAMS WITH 4"TEST JOINT i ALL TO 250 PSI LOW/3500 PSI HIGH. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 12 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: .X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/18/2012 00:00 - 02:00 2.00 BOPSUR P INTI PJSM ON TESTING RAMS. -LD 4"TEST JOINT. -PU 5"TEST JOINT. -TEST TOP VBR RAMS: 3-1/2"X 6" -250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES. -RD TEST EQUIPMENT. LD TEST JT. INSTALL WEAR BUSHING AND LOCKDOWN SAME. 02:00 - 02:30 0.50 BOPSUR P • INTI CLEAR RIG FLOOR OF TOOLS AND PREP TO SLIP DRILLING LINE. 02:30 - 04:30 2.00 BOPSUR P INTI PJSM ON CUT AND SLIP OPERATION. -SLIP AND CUT DRILLING LINE. -FIND BAD SPOT ON DRUM. MAKE SECOND SLIP AND CUT. -SIM OPS: X-OUT DIES ON IRON ROUGHNECK. 04:30 - 05:00 0.50 BOPSUR P INTI SERVICE RIG AND TOP DRIVE. 05:00 - 06:30 1.50 BOPSUR P INTI PJSM ON PICKING UP 5"DP. •-MU 5"MULESHOE TO BOTTOM OF 5"DP. -PICK UP/TIH WITH SINGLES OF 5"DP FROM "PIPE SHED. 06:30 - 07:00 0.50 BOPSUR P INTI -PULL OUT OF THE HOLE WITH 5"DRILL PIPE WAND RACK BACK IN DERRICK ON DRILLER SIDE. 07:00 - 07:30 0.50 BOPSUR P INTI MOVE 5"HWDP/JAR STAND/COLLAR STAND TO OFF DRILLER SIDE TO MAKE ROOM FOR 4"AND 5"DRILL PIPE ON DRILLER SIDE. 07:30 - 09:30 2.00 BOPSUR P INTI RUN IN THE HOLE WITH 5"DRILL PIPE,PICK UP SINGLES FROM THE PIPE SHED. 09:30 - 10:30 1.00 BOPSUR P INTI PULL OUT OF THE HOLE WITH 5"DRILL PIPE, RACK BACK IN DERRICK ON DRILLER SIDE. 10:30 - 12:00 1.50 BOPSUR P INTI MAKE UP 4.96"STACK WASHER ON 4"DRILL PIPE AND PICK UP 4"DRILL PIPE SINGLES FROM THE PIPE SHED, RUN IN HOLE. 12:00 - 12:30 0.50 BOPSUR P INTI INSPECT/SERVICE TOP DRIVE, BLOCKS, DRAWWORKS. 12:30 - 17:00 4.50 BOPSUR P INTI CONTINUE TO PICK UP 4"DRILL PIPE SINGLES FROM THE PIPE SHED AND RUN IN THE HOLE FROM 630'TO 4464'. 17:00 - 21:00 4.00 BOPSUR P INTI MONITOR WELL FOR 10 MINUTES, NO FLOW. 'PULL OUT OF THE HOLE FROM 4464'TO ,SURFACE. RACK BACK STAND IN DERRICK. -LAY DOWN STACK WASHER. 21:00 - 21:30 0.50 CASING P INTI PJSM ON CASING PRESSURE TEST. CLEAN AND CLEAR RIG FLOOR. �S 21:30 - 23:30 2.00 CASING P INTI RIG UP AND TEST 9-5/8"CASING TO 250 PSI LOW FOR 5 MINUTES;7 STROKES. 3500 PSI HIGH FOR 30 MINUTES;98 STROKES. 7.1 BBLS RETURNS FROM BLEED OFF. -FIRE DRILL CRT=97 SECONDS. -CONFIRM RESULTS OF TEST,OBTAIN WTL •AUTHORIZATION TO PROCEED 23:30 - 00:00 0.50 CASING P INTI BLOW DOWN CHOKE/KILL LINES. RIG DOWN PRESSURE TEST EQUIPMENT. 6/19/2012 00:00 - 01:00 1.00 CASING P INTI MOBILIZE RTTS PACKER AND TOOLS TO RIG FLOOR. POSITION COLLARS IN DERRICK FOR PIPE HANDLING Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 13 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date: 6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release: 6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 03:00 2.00 CASING P INTI PJSM ON MAKING UP BHA. -MAKE UP BHA#4: 13-3/8"RTTS PACKER ASSEMBLY. 03:00 - 05:30 2.50 CASING P INTI TRIP IN HOLE WITH BHA#4. TAG LINER TOP ON DEPTH AT 2691'.33-FT IN STAND 24.MW 9.6-PPG,MW OUT 9.6-PPG 05:30 - 06:30 1.00 CASING P INTI RACK BACK 1 STAND AND RIG UP FOR NEGATIVE PRESSURE TEST. -SET RTTS AT 2662'WITH CIRCULATING VALVE OPEN. 06:30 - 08:00 1.50 CASING P INTI CIRCULATE AND PUMP ANNULAR VOLUME. STAGE PUMPS TO 80 SPM,326 GPM,380 PSI. BOTTOMS UP=4000 STROKES. SPR 2662'-MD,2296-ND,MW 9.6-PPG,06:55 HRS. -#1 MP 2-BPM,120-PSI,3-BPM,140-PSI -#2 MP 2-BPM,110-PSI,3-BPM,130-PSI MW IN 9.6-PPG,MW OUT 9.6-PPG -CLOSE PIPE RAMS AND TAKE SPR's REVERSE CIRCULATION: -#1 20 SPM AT 30 PSI,30 SPM AT 40 PSI -#2 20 SPM AT 30 PSI,30 SPM AT 40 PSI -CLOSE CIRCULATING VALVE. -TEST PACKER/13-3/8"CASING TO 250 PSI LOW/1000 PSI HIGH DOWN KILL LINE FOR 5 MINUTES-OK. 08:00 - 11:00 3.00 • CASING P INTI PJSM ON NEGATIVE PRESSURE TEST. -RIG UP LITTLE RED AND PRESSURE TEST LINES TO 1500 PSI. -LITTLE RED PUMP 48 BBLS OF DIESEL DOWN THE DRILL PIPE WITH FCP AT 380 PSI, BLED BACK PRESSURE TO LITTLE RED. -PERFORM 10 MINUTE FLOW CHECK ON DRILL PIPE,NO FLOW. -RU TO CHART RECORDER AND RECORD DP PRESSURES FOR 30 MINUTES. -DP PRESSURE=0 FOR 30 MINUTES -NEGATIVE PRESSURE TEST PASSED AND APPROVED BY WTL. -CLOSE ANNULAR,OPEN PIPE RAMS AND OPEN CIRC VALVE. -REVERSE OUT DIESEL TO CUTTINGS BOX AT 3 BPM. -MONITOR WELL FOR 10 MINUTES-NO FLOW. -UNSET PACKER AND OPEN ANNULAR PREVENTER. 11:00 - 13:30 2.50 CASING P INTI RIG DOWN PRESSURE TEST EQUIPMENT. -BLOW DOWN AND RIG DOWN HOSES,T'S, AND VALVES. -BACK OUT TD FROM FOSV. BREAKDOWN FOSV AND SIDE PORT SUB. 13:30 - 14:30 1.00 CASING P INTI CIRCULATE OUT AT 10 BPM AND 340 PSI. PU=126K AND SO=95K. 14:30 - 16:00 1.50 CASING P INTI MONITOR WELL FOR 5 MINUTES-NO FLOW. -PUMP DRY JOB AND BLOW DOWN TOP DRIVE. -TOH FROM 2662 TO 491 FT. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 14 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date. 6/6/2012 End Date 1X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 CASING P INTI MONITOR WELL FOR 5 MINUTES BEFORE PULL NON-SHEARABLES THRU STACK-NO FLOW. -PULL 5"HWDP AND 1 STD DC'S. -LD MULESHOE, XO, STAB AND RTTS PACKER. 17:00 - 18:30 1.50 CASING P INTI PJSM ON CLEARING RIG FLOOR. -CLEAR RIG FLOOR OF PAKCER TOOLS. -MOB BHA#4 TOOLS TO FLOOR. 18:30 - 21:30 3.00 CASING P INTI PJSM ON PICKING UP DIRECTIONAL BHA. -PU DIRECTIONAL BHA#4 -ENSURE CONTINGENCY FOR NON-SHEARABLES ACROSS STACK. -SHALLOW TEST MWD AT 500 GPM AT 1300 PSI-OK. 21:30 - 00:00 2.50 CASING P INTI PJSM ON TRIPPING PIPE. -TIH F/680 FT T/4486 FT. -HELD KICK DRILL WHILE TRIPPING,3 MINUTES CRT -DOGHOUSE AAR. 6/20/2012 00:00 - 01:00 1.00 CASING _.P INTI TRIP IN HOLE F/4486 FT T/5133 FT. 01:00 - 03:30 2.50 CASING P INTI TAG CEMENT AT 5133 FT. --DRILL CEMENT F/5133 FT T/5158 FT. -DRILL WIPER PLUG AND FLOAT. -DRILL SHOE TRACK F/5158 FT T/5224 FT. (20 FT ABOVE SHOE). -SCREENS BLINDED ONCE CONTAMINATED CEMENT REACHED SURFACE AND SLOW PUMPS. -SPR'S AT 5119 FT 41 20 SPM AT 560 PSI AND 30 SPM AT 650 PSI. #2 20 SPM AT 550 PSI AND 30 SPM AT 660 PSI. 03:30 - 05:00 1.50 CASING P INTI CIRCULATE AND CONDITION MUD DUE TO CONTAMINATED CEMENT PRIOR TO DISPLACING TO NEW MUD. 05:00 - 07:30 2.50 CASING P INTI PJSM.EMPTY PITS FOR UPCOMING DISPLACEMENT.PUMP 40 BBL 9.0 PPG HIGH VIS SWEEP AND DISPLACE SYSTEM TO 9.0 PPG NEW LSND. 07:30 - 10:30 3.00 CASING P INTI SHUT DOWN AND CLEAN PITS AND SURFACE EQUIPMENT OF CONTAMINATED CEMENT. 10:30 - 13:30 3.00 CASING N RREP INTI WORK ON TOTCO SYSTEM. 13:30 - 14:30 1.00 DRILL P PROD1 OBTAIN SLOW PUMP RATES AND BASELINE ECD. DRILL DOWN TO 5276 FT. -PUW 145K,SOW 100K, ROT 118K -TQ 7K, RPM 100, -600 GPM,1780 PSI, ECD 9.63 PPG SPR 5234'MD,3527'TVD,9.1 PPG MP#1 20 SPM 320 PSI,30 SPM 380 PSI MP#2 20 SPM 320 PSI,30 SPM 380 PSI 14:30 - 15:30 1.00 DRILL P PROD1 CIRCULATE BOTTOMS UP AT 600 GPM,1780 PSI. Printed 8/6/2012 10:06:03AM North America-ALASKA- BP Page 15 of 18 Operation Summary Report Common Well Name Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 ! End Date X3-011D6-C:(7,247,370.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. j UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 17:30 2.00 DRILL P PROD1 PULL BACK INTO CASING SHOE.RIG UP AND PERFORM LOT AT 5244'MD AT 3527'TVD 9.1 PPG MUD WT.OBSERVED BREAKOVER AT 900 PSI,14 PPG EMW.CALLED ODE AND WTL AND RECIEVED APPROVAL TO MOVE FORWARD WITH OPERATIONS. 17:30 - 00:00 6.50 DRILL P PROD1 DRILL FROM 5276'-6196'. -PUW 170K,SOW 104K,SOW 127K -TQ ON 10K, OFF 8K, RPM 80,WOB 5-10K -GPM 600, PRESSURE ON 2320 PSI,OFF 2190 PSI. SPR 5720'MD,3751'TVD,9.1 PPG MP#1 20 SPM 300 PSI,30 SPM 370 PSI MP#2 20 SPM 310 PSI,30 SPM 380 PSI 6/21/2012 00:00 - 12:00 12.00 DRILL P PROD1 DRILL FROM 6196'TO 7520'. -PUW 185K,SOW 115K, ROT 143K -TQ ON 14K,OFF 11K, RPM 80,WOB 13K -GPM 600, PRESSURE ON 2710 PSI,OFF 2540 PSI. -SPILL DRILL RESPONSE TIME=104 SECONDS. AST= 1.28 HRS,ART=4.56 HRS,ADT=5.84 IHRS -MW IN 9.2-PPG,MW OUT 9.2-PGG SPR 6203'MD,3986'TVD,9.1 PPG MP#1 20 SPM 310 PSI,30 SPM 380 PSI MP#2 20 SPM 330 PSI,30 SPM 390 PSI SPR 6668'MD,4215'TVD,9.1 PPG MP#1 20 SPM 400 PSI,30 SPM 490 PSI MP#2 20 SPM 400 PSI,30 SPM 480 PSI SPR 7141'MD,4437'TVD,9.1 PPG MP#1 20 SPM 390 PSI,30 SPM 430 PSI MP#2 20 SPM 370 PSI,30 SPM 450 PSI SPR 7516'MD,4609'TVD,9.1 PPG 11:50 HRS. MP#1 20 SPM 350 PSI,30 SPM 430 PSI MP#2 20 SPM 350 PSI,30 SPM 430 PSI 12:00 - 00:00 12.00 DRILL P PROD1 DRILL FROM 7520'TO 8560'. -PUW 185K,SOW 126K, ROT 151K -TQ ON 13K,OFF 11K, RPM 100,WOB 10K -GPM 600, PRESSURE ON 3030 PSI, OFF 2790 PSI. AST=1.28 HRS,ART=4.56 HRS,ADT=5.84 HRS CALCULATED ECD 9.66 PPG,ACTUAL REAL-TIME 10.48 PPG MW IN 9.2-PPG,MW OUT 9.3-PGG SPR 8369'MD,4987'TVD,9.2 PPG,22:00 HRS. MP#1 20 SPM 340 PSI,30 SPM 450 PSI MP#2 20 SPM 330 PSI,30 SPM 420 PSI FAULT CROSSING AT 8260'-MD,215'THROW, NO LOSSES OBSERVED. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP • Page 16 of 18 Operation Summary Report Common Wet Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: 1X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/22/2012 00:00 - 12:00 12.00 DRILL P PROD1 DIRECTIONALLY DRILL 8-3/4"HOLE FROM 8560'TO 9696'-MD -PUW 205K,SOW 133K,ROT 163K -TQ ON 16K,OFF 11K, RPM 100,WOB 15K -GPM 600, PRESSURE ON 3400 PSI,OFF 3200 PSI. --AST=3.10 HRS,ART=2.59 HRS,ADT=5.69 HRS JAR HRS= 155.4 BEGIN INCREASING MW TO 10.2 AT 9500' MW IN 10.2-PPG,MW OUT 10.2-PPG 12:00 - 00:00 12.00 DRILL P PROD1 DIRECTIONALLY DRILL 8-3/4"HOLE FROM 9696'TO 10673'-MD -PUW 243K,SOW 145K, ROT 175K -TQ ON 14-15K,OFF 14K, RPM 100,WOB 15K -GPM 600, PRESSURE ON 3590 PSI,OFF 3410 PSI. AST=3.7 HRS,ART=3.2 HRS,ADT=6.9 HRS JAR HRS=162.8 MW IN 10.2-PPG,MW OUT 10.2-PPG 6/23/2012 00:00 - 09:30 9.50 DRILL P PROD1 DIRECTIONALLY DRILL 8-3/4"PRODUCTION HOLE F/10673'T/11379'-MD PRODUCTION SECTION TD 11379'-MD TVD 6995' -PUW 281 K,SOW 151K, ROT 190K -TQ ON 19-20K,OFF 22K, RPM 120,WOB 17K -GPM 546, PSI ON 3750, PSI OFF 3540 PSI. -CALCULATED ECD= 11.08-PPG,ACTUAL ECD=11.76-PPG -MW IN 10.2-PPG,MW OUT 10.2-PPG 09:30 - 12:00 2.50 DRILL P PROD1 ROTATE AND RECIPROCATE WHILE CIRCULATING HOLE CLEAN SCR#2 DOWN CIRCULATE AT GPM 370, PSI 1980, TRQ 22K -PUW 265K,SOW 155K, ROT 200K 12:00 - 00:00 12.00 DRILL P PROD1 MONITOR WELL 10-MINUTES,NO FLOW -BACKREAM POOH AT DRILLING RATE FROM 11379'TO 7145' -GPM 550, PSI 3400, 100 RPM,TRQ 15-20K 9100'to 8700'REAM STAND AN ADDITIONAL TIME DUE TO INCREASE IN ECD MAD PASS LOG AT 360-FT/HR BIT DEPTH INTERVALS: 11070'TO 11010', 8360'TO 7600',7500'TO 7145' 6/24/2012 00:00 - 01:00 1.00 DRILL P PROD1 MAD PASS LOG AT 360-FT/HR: 7425 TO 7145 FT GPM 550, PSI 3050, 100 RPM,TQ 15-20 K MW IN 10.2-PPG,MW OUT 10.2-PPG 01:00 - 02:30 1.50 DRILL P PROD1 PUMP HIGH-VIS SWEEP SURFACE TO SURFACE -CONTINUE TO BACK REAM F/7145'T/7047' -550 GPM,3050 PSI,100 RPM,TRQ 10-14K NO SIGNIFICANT INCREASE IN CUTTINGS WITH SWEEP AT SURFACE. MONITOR WELL,NO FLOW. Printed 8/6/2012 10:06:03AM North America -ALASKA- BP Page 17 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 04:30 2.00 DRILL P PROD1 RIH ON ELEVATORS: 7047 TO 11307 FT. STAGE UP PUMPS,WASH LAST STAND TO BOTTOM AT 11379' FILL PIPE EVERY 2000'TRIP LOOKS GOOD, NO FILL ON BOTTOM. 04:30 - 08:30 4.00 DRILL P PROD1 CIRCULATE AND CONDITION HOLE AT TD 11379' -PUMP 30 BBL HIGH VISC SWEEP DUMP 290 BBL MUD AND ADD 290 BBL NEW MUD. 550 GPM,3370 PSI PRE-SWEEP: ROTATE AND RECIPROCATE 100 RPM,TQ 23K, PU 275K MAX POST-SWEEP: ROTATE AND RECIPROCATE 100 RPM,TO 19K, PU 195K MW IN 10.2-PPG,MW OUT 10.2-PPG -PJSM ON TRIPPING PIPE. 08:30 - 14:30 6.00 DRILL P PROD1 TAKE SPR'S AND MONITOR WELL 10 MINUTES-NO FLOW. -POOH ON ELEVATORS F/11,379 FT TO 5244 FT W/5"DP -FLOW CHECK AT SHOE FOR 10 MINUTES- NO FLOW -PJSM ON CHANGING OVER TO 4"TOOLS -CHANGE OUT ELEVATORS,SLIPS AND MUD BUCKET RUBBERS -POOH TO 2908 FT W/4"DP -WELL COMMANDER AT 2688 FT AND BIT AT 2908 FT 14:30 - 17:00 2.50 DRILL P PROD1 PJSM ON OPENING WELL COMMANDER -DROP 2.125"OPENING BALL AND ROTATE 30 RPM -PRESSURE TO 1000 PSI FOR 30 SECONDS -PRESSURE TO 2380 PSI AND COMMANDER OPENED -VERIFY MWD TOOL NOT PULSING 17:00 - 18:00 1.00 DRILL P PROD1 CIRCULATE THROUGH WELL COMMANDER AT 9-5/8"LINER TOP -620 GPM AT 1130 PSI -DROP 2.125"CLOSING BALL -PRESSURE TO 1000 PSI AND HOLD FOR 30 SECONDS -PRESSURE TO 2340 PSI AND COMMANDER CLOSED -VERIFY MWD TOOL PULSING. 18:00 - 19:30 1.50 DRILL P PROD1 PJSM ON TRIPPING PIPE OPERATION -PUMP DRY JOB AND BLOW DOWN TOP DRIVE -POOH F/2908 TO 700 FT -FLOW CHECK FOR 10 MINUTES BEFORE PULLING BHA 19:30 - 23:00 3.50 DRILL P PROD1 -PJSM ON BHA OPERATION -LD 9 JTS HWDP -PJSM W/SLB ON HANDLING RA SOURCES -LD JARS,WELL COMMANDER, SAVER SUB, NON-MAG DRILL COLLARS -REMOVE RA SOURCES FROM ADN TOOL -LD ADN. MWD. PONY NON-MAG DRILL COLLAR -DRAIN MOTOR AND BREAK BIT *NO VISUAL DAMAGE TO BHA,ALL COMPONENTS IN GAUGE Printed 8/6/2012 10:06.03AM North America -ALASKA- BP Page 18 of 18 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: DRL-ONSHORE(DON) Start Date:6/6/2012 End Date: X3-011D6-C: (7,247,370.00) Project: Prudhoe Bay Site: PB Z Pad Rig Name/No.: DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 23:00 - 00:00 1.00 DRILL P PROD1 -CLEAN AND CLEAR RIG FLOOR OF DIRECTIONAL TOOLS. -=MOB 1 JT OF 5"DP AND STACK WASHER. Printed 8/6/2012 10:06:02AM North America-ALASKA- BP Page 1 of 6 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/15/2012 End Date:6/30/2012 X3-011D6-C: (4,071,578.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/25/2012 00:00 - 01:00 1.00 BOPSUR P RUNPRD PERFORM WEEKLY FUNCTION TEST ON ALL BOP'S. 01:00 - 03:30 2.50 BOPSUR P RUNPRD CHANGE TOP RAMS TO 7"PIPE RAMS. -LD SHORT BALES. -MOB CASING CENTRALIZERS AND X-OVERS TO RIG FLOOR. 03:30 - 05:00 1.50 BOPSUR P RUNPRD -PULL WEAR BUSHING. -INSTALL 7"TEST PLUG W/7"TEST JOINT. -RU TO TEST 7"RAMS. -TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES. *CHARTED AND GOOD TEST. -LD TEST JOINT. -RD TEST EQUIPMENT. 05:00 - 06:00 1.00 CASING P RUNPRD PICK UP 7"LANDING JOINT AND CASING HANGER. -VERIFY HANGER LANDED IN HEAD THRU IA VAVLE. -MARK LANDING JOINT AT ROTARY TABLE. -LD LANDING JOINT. 06:00 - 09:00 3.00 CASING -P RUNPRD RIG UP TO RUN 7"PRODUCTION CASING. . -RU FRANKS FILL-UP TOOL. .-RU LONG BALES. -RU CASING SPIDER SLIPS AND ELEVATORS. -RU CASING TONGS. -RU TORQUE TURN. 09:00 - 12:00 3.00 . CASING P RUNPRD PJSM ON CASING RUNNING OPERATION. -MAKE UP AND BAKER LOCK SHOE TRACK. -CIRCULATE THROUGH SHOE TRACK-OK. -DRAIN FLUID FROM SHOE TRACK-OK. -RUN SHOE TRACK IN HOLE AND ENSURE FLOATS HOLDING-OK. -RUN 7"26#(L80,9Cr,13Cr)(BTC,TCII,VAMT, VAMTHC)PRODUCTION CASING. -FILL CASING EVERY 10 JTS. RIH AT 3-5 FPM. MONITORED FLUID DISPLACEMENT. MAKE UP TORQUES: VT 8300 FT LB,TCII 10,100 FT LB,VTHC 11,950 FT LB. (TORQUE TURNED ALL CONNECTIONS). -THREAD COMPOUND: JET LUBE SEAL. -RA MAKER JOINT AT: 10,894 FT(50 FT ABOVE TKC TOP). -CENTRALIZATION: HYDROFORM 7-1/8"X 8-1/8". (1)SHOE JT LOCKED DOWN W/STOP RING. (2)PER JOINT WITH STOP RING MID JOINT TO 6952 FT.(TOP OF Ma). (1)PER JOINT TO 5921 FT(FLOATING). -RECORDED PU,SO AND HANGING WEIGHTS EVERY 10 JTS. *BARRIERS: TESTED BOPE W/7"RAMS, KWM. -CROSSOVER SWAGE FROM CASING TO 5" DP WITH FOSV IN OPEN POSTION ON RIG FLOOR. -CONTINGENCY FOR NON-SHEARABLES IN STACK IN PLACE. -RIH TO 877 FT. MW=10.2 IN/OUT. Printed 8/6/2012 10:06.36AM North America -ALASKA- BP • Page 2 of 6 Operation Summary Report Common Well Name.Z-115 AFE No Event Type:COM-ONSHORE(CON) Start Date:6/15/2012 I End Date:6/30/2012 IX3-011 D6-C: (4,071,578.00) Project: Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) 12:00 - 20:30 8.50 CASING PNUR PRD PJSM ON CASING RUNNING OPERATION. -RIH W/7"26#L80 VAMTHC CASING F/877 TO 5243 FT,BREAKING CIRCULATION EVERY 10 JTS. *NOTIFIED AOGCC,C.SCHEAVE AT 16:00 OF UPCOMING BOPE TEST(24 HR NOTICE). 20:30 - 22:00 1.50 CASING P RUNPRD CIRCULATE CASING(1.5X BOTTOMS UP)AT INTERMEDIATE CASING SHOE. -STAGE UP: 3 BPM AT 320 PSI,4 BPM AT 360 PSI,5 BPM AT 410 PSI,6 BPM AT 500 PSI AND 7 BPM AT 600 PSI. 22:00 - 00:00 2.00 CASING P RUNPRD RUN 7"CASING F/5243 TO 6519 FT. -BREAK CIRUCLATION EVERY 10 JTS AND RECORD PU,SO AND HANGING WEIGHTS. 6/26/2012 00:00 03:00 3.00 CASING P RUNPRD RUNNING 7"PRODUCTION CASING. -FROM 6519 FT TO 7921 FT. -BREAK CIRCULATION EVERY 10 JTS. 03:00 - 04:30 1.50 CASING ( P RUNPRD CIRCULATE CASING AT 7921 FT.(TOP SB_OA). 04:30 - 11:00 6.50 CASING P RUNPRD RUNNING 7"PRODUCTION CASING. -FROM 7921 TO 11335 FT. -BREAK CIRCULATION EVERY 10 JTS. 11:00 - 11:30 0.50 CASING P RUNPRD PICK UP LANDING JOINT AND LAND ON HANGER,LAY DOWN FRANKS TOOL,BLOW DOWN TOP DRIVE AND PICK UP CEMENT HEAD. 11:30 - 16:00 4.50 CASING P RUNPRD MAKE UP CEMENT LINE AND STAGE PUMPS UP TO 7 BPM 900 PSI. I PUW 265K,SOW 140K.CONDUCT PJSM FOR CEMENTING AND CLEAR RIG FLOOR. Printed 8/6/2012 10:06:36AM North America -ALASKA- BP • Page 3 of 6 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: COM-ONSHORE(CON) Start Date: 6/15/2012 End Date:6/30/2012 X3-011D6-C: (4,071,578.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:OOPM Rig Release: 6/30/2012 Rig Contractor:DOYON DRILLING INC. 1 UWI Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 19:00 3.00 CEMT P RUNPRD WHILE RECIPROCATING 20'STROKES PUMP 5 BBLS OF WATER AND PRESSURE TEST .� CEMENT LINES TO 250 PSI LOW 4000 PSI HIGH.PUW 265K,SOW 150K PUMP CEMENT AS FOLLOWS: -29.9 BBLS OF 11.1 PPG MUD PUSH AT 5 BPM -KICK OUT BOTTOM PLUG AND PUMP 12 PPG LEAD AT 5 BPM.SHUT DOWN WITH PUMPS WITH 12.7 BBLS AWAY DUE TO CEMENT SILO ISSUES CAUSING DENSITY TO DROP TO 10.6 PPG.BRING PUMPS BACK UP TO 5 BPM WITH 12.0 PPG LEAD.AT 35 BBLS AWAY SLOW DOWN TO 1 BPM TO KEEP DENSITY ABOVE 11.6 PPG AND ADDRESS SILO ISSUE.PUMP REMAINING CEMENT AT 6 BPM 12 PPG PUMPING A TOTAL OF 154.1 BBLS,523 SX, 1.64 FTA3/SX OF 12 PPG L -SWAP OVER TO TAIL CEMENT AND PUMP A TOTAL OF 41.1 BBLS,198 SX, 1.17 FTA3/SX OF 15.8 PPG GASBLOK CEMENT AT 5 BPM WITH NO ISSUES. SWAP OVER TO RIG PUMPS DROP THE TOP .PLUG AND DISPLACE THE CEMENT WITH 10.5 PPG NACUNABR BRINE AS FOLLOWS: -PUMP 354 BBLS AT 7 BPM 960 PSI.STOP RECIPROCATION 293 BBLS INTO DISPLACEMENT SOW WENT FROM 150K TO 125K.LAND CASING HANGER AND CONTINUE DISPLACEMENT. -SLOW DOWN TO 5 BPM 1250 PSI AND PUMP 406 BBLS AWAY. -SLOW TO 3 BPM AND PUMP 423 BBLS. -SLOW TO 2 BPM AND BUMP PLUG WITH 430.4 BBLS AT 1110 PSI CIP AT 18:20 PRESSURE UP TO 1640 PSI AND HOLD FOR 5 MIN.BLEED OFF AND CHECK FLOATS. FLOATS HELD. 19:00 - 20:30 1.50 CEMT P RUNPRD RIG UP AND PRESSURE TEST 7"26#CASING 250 PSI LOW 5 MIN 3500 PSI HIGH FOR 30 MIN. -LOST 40 PSI IN THE FIRST 15 MIN AND 10 PSI IN THE SECOND 15 MIN. BLEED PRESSURE OFF CLOSE THE ANNULAR AND INJECT 10.2 PPG LSND AT 1.5 BPM DOWN THE OA.PRESSURE BROKE OVER AT 1280 PSI AND CONTINUED TO INJECT 10 BBLS INTO THE FORMATION FINAL INJECTION PRESSURE 1020 PSI. 20:30 - 22:00 1.50 CEMT P RUNPRD RIG DOWN CEMENT LINES,BACK OUT LANDING JOINT,FLUSH STACK,AND RIG DOWN CASING EQUIPMENT. 22:00 - 00:00 2.00 CEMT P RUNPRD PICK UP A JOINT OF HWDP AND PACKOFF RUNNING TOOL.INSTALL PACKOFF 7" MANDREL HANGER,RILDS 6/27/2012 00:00 - 02:00 2.00 BOPSUR P RUNPRD TEST PACK OFF TO 250 PSI LOW 15 MIN AND 5000 PSI HIGH 30 MIN.GOOD TEST. -BARRIERS- TESTED CASING,PACK OFF,KILL WEIGHT FLUID,BOPE 02:00 - 03:30 1.50 BOPSUR P RUNPRD SLIP AND CUT DRILLING LINE Printed 8/6/2012 10:06:36AM North America-ALASKA- BP • Page 4 of 6 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/15/2012 End Date: 6/30/2012 .X3-011D6-C: (4,071,578.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release:6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 06:30 3.00 BOPSUR P RUNPRD CHANGE OUT UPPER RAMS FROM 7"TO 3.5" X 6"VBR -TEST RAMS WITH 4"TEST JOINT 250 PSI LOW 3500 PSI HIGH 5 MIN EACH 06:30 - 07:00 0.50 BOPSUR P RUNPRD RIG DOWN TEST EQUIPMENT -PULL TEST PLUG -INSTALL WEAR RING 07:00 - 08:00 1.00 BOPSUR P RUNPRD 'PULL MWD SENSORS ON MANIFOLD PJSM TO RIH WITH 4"XT-39 DP.OUT OF DERRICK 08:00 - 10:00 2.00 BOPSUR P RUNPRD RIH WITH 4"DRILL PIPE -M/U STACK WASHING TOOL -RIH TO 4464' 10:00 - 15:00 5.00 BOPSUR P RUNPRD PJSM -LAY DOWN DRILL PIPE 4464 TO SURFACE -63 BBLS TOTAL INJECTED INTO 7 X 13-3/8 ANNULUS,PSI 1020 15:00 - 15:30 0.50 BOPSUR P RUNPRD PJSM -SERVICE AND INSPECT TOP DRIVE, BLOCKS AND DRAWWORKS 15:30 - 21:30 6.00 BOPSUR - P RUNPRD PJSM -LAY DOWN 5"DRILL PIPE IN THE MOUSE -HOLE -RIG UP LITTLE RED TO INJECT 215 BBLS OF CRUDE DOWN OA -BROKE DOWN AT 1600 PSI -INITIAL PRESSURE 1100, FINAL PRESSURE 1380 21:30 - 22:00 0.50 BOPSUR P RUNPRD PJSM -DRAIN STACK AND PULL WEAR RING 22:00 - 23:30 1.50 BOPSUR P RUNPRD PJSM -RIG UP TO TEST BOPE WITH 4.5"TEST JOINT,4"FOSV,4"DART VALVE,3.5"FOSV 23:30 - 00:00 0.50 BOPSUR P RUNPRD TEST BOPE -250 PSI LOW,3500 PSI HIGH (1.4 -5 MIN EACH TEST 6/28/2012 00:00 - 04:30 4.50 BOPSUR P RUNPRD CONTINUE TO TEST BOPE -250 PSI LOW,3500 PSI HIGH -5 MIN EACH TEST -TEST WITNESSED BY TOURPUSHER GOUCHENAUER,WSL WILL TURNER AND JACOB THOMPSON -AOGCC REP LOU GRIMALDI WAIVED WITNESS OF TEST 04:30 - 05:00 0.50 BOPSUR P RUNPRD RIG DOWN TEST EQUIPMENT,BLOW DOWN LINES 05:00 - 10:00 5.00 RUNCOM P RUNCMP RIG UP TO RUN 4.5"VAM TOP COMPLETION -LAY DOWN SHORT BALES AND PICK UP LONG BALES -INSTALL COMPENSATOR SINGLE JOINT ELEVATORS -PICK UP-I-WIRE SPOOL,286 FULL CLAMPS AND 20 HALF CLAMPS 10:00 - 10:30 0.50 RUNCOM P RUNCMP PJSM WITH HALLIBURTON HAND AND I-WIRE CREW 10:30 - 00:00 13.50 RUNCOM P RUNCMP RUN 4.5"13CR-80 VAM TOP COMPLETION TO 5687' -AVERAGE MAKE UP TORQUE 4440 FT/LBS Printed 8/6/2012 10:06:36AM North America -ALASKA- BP Page 5 of 6 Operation Summary Report Common Well Name:Z-115 AFE No Event Type: COM-ONSHORE(CON) Start Date:6/15/2012 End Date: 6/30/2012 X3-011D6-C: (4,071,578.00) Project:Prudhoe Bay Site: PB Z Pad Rig Name/No.:DOYON 14 Spud Date/Time:6/7/2012 2:00:00PM Rig Release: 6/30/2012 Rig Contractor:DOYON DRILLING INC. UWI: Active Datum:Z-115 actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/29/2012 00:00 - 10:00 10.00 RUNCOM P RUNCMP CONTINUE TO RUN 4.5"13CR-85 VAM TOP COMPLETION FROM 5687'TO 10752' -AVERAGE MAKE UP TORQUE 4440 FT/LBS -FINAL PUW-155K FINAL SOW-100K -INSTALLED 259 EA 4 1/2"CROSS CUPLING"I" WIRE CLAMPS WITH 2 KEEPER PINS EACH -INSTALLED 11 EA 4 1/2"HALF CLAMPS WITH ONE KEEPER PIN EACH. 10:00 - 10:30 0.50 RUNCOM P RUNCMP FMC RUN I-WIRE THRU TUBING HANGER 10:30 - 11:00 0.50 RUNCOM P RUNCMP LAND HANGER,FMC RUN IN LOCK DOWN SCREWS 11:00 - 14:30 3.50 RUNCOM P RUNCMP PJSM -10.5 PPG'100 DEGREE BRINE CIRCULATE DOWN IA AT 4 BPM AT 680 PSI -DISPLACE WITH CORROSION INHIBITOR BETWEEN GLM#5 AT 3700'AND AROUND PRODUCTION PACKER. -CIRCULATE 5 BBL DOWN TUBING TO WASH OFF RHC SEAT. -DROP BALL AND ROD. 14:30 - 18:30 4.00 RUNCOM - P RUNCMP TEST TUBING 250 PSI FOR 5 MIN,3500 PSI FOR 30 MIN -TEST TUBING TWICE.THIRD TEST SUCCESSFUL LOSING 70 PSI IN THE FIRST 15 MIN AND 30 PSI IN THE SECOND 15 MIN. -BLEED OFF TUBING TO 1500 PSI -TEST ANNULUS TO 250 PSI 5 MIN,3500 PSI 30 MIN.LOST 90 PSI IN THE FIRST 15 MIN AND 10 PSI IN THE SECOND 15 MIN. -WTL APPROVAL OF TEST BEFORE PROCEEDING 18:30 - 19:30 1.00 RUNCOM P RUNCMP SHEAR DCK VALVE -PUMP 2 BBL EACH DIRECTION AT 2 BPM 19:30 - 21:00 1.50 RUNCOM P RUNCMP INSTALL TWC.TEST FROM ABOVE 250 PSI LOW 5 MIN AND 3500 PSI HIGH 5 MIN.TEST TWC FROM BELOW 250 PSI LOW 5 MIN AND 3500 PSI HIGH FOR 5 MIN. -LOST 50 PSI IN THE FIRST 15 MIN AND 20 PSI IN THE SECOND 15 MIN. 21:00 - 00:00 3.00 RUNCOM P RUNCMP REMOVE 4.5"RUNNING TOOLS FROM THE RIG FLOOR,REMOVE LONG BAILS AND COMPENSATOR AND LAY DOWN I-WIRE SPOOL,TOOLS AND CLAMPS -FLUSH STACK 6/30/2012 00:00 - 04:30 4.50 RUNCOM P RUNCMP NIPPLE DOWN BOP,NIPPLE UP TREE -CHANGE OUT SAVER SUB 04:30 - 06:00 1.50 RUNCOM P RUNCMP TEST TREE AND ADAPTOR -250 PSI LOW 5 MINS,AND 5000 PSI HIGH 10 MIN. 06:00 - 07:30 1.50 RUNCOM P RUNCMP RIG UP DSM LUBRICATOR AND TEST -250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -PULL TWC 07:30 - 09:30 2.00 RUNCOM P RUNCMP RIG UP LITTLE RED AND TEST LINES -250 PSI LOW,3500 PSI HIGH 5 MINUTES EACH 09:30 - 10:00 0.50 RUNCOM P RUNCMP FREEZE PROTECT WELL WITH 17 BBLS OF DIESEL -2 BPM,840 PSI Printed 8/6/2012 10:06:36AM Common Well Name:z'11n AFE No Event Type:COM-ONSHORE(CON) Start Date:6/15/2012 End Date:6/30/2012 .X3-011D0-C: (4.071.578.00) Pm��: PmuhooBay Site: Pa�Pau Rig Name/No.:DOYON 14 | Spud oate/Time:s/7/2o1u 2:00:00PM Rig Release:6/30/2012 Rigoon�ocmcDRILLING uvv|� Active Datum:Z'115actual @89.94ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 11:00 100 RUNCOM p RUNCMP R|GUPDSMLU8R|C�T0R. |m�TAL[�sV---- 'TsuT�PvTOusoPo|�ovv�onn�|wuTES -3500 PSI HIGH FOR 30 MINUTES -GOOD TEST -SECURE WELL 11:00 00:00 13.00 RIGD P RUNCMP CLEAN uPRIG,PREPARE RIG FOR MOVE -INSTALL BOOSTER WHEELS -SEND IN ALL SAA, RAA MATERIALS,AND UNNEEDED SUBS ON FLOOR -PREPARE TO SKID RIG FLOOR -RIG RELEASED FROM z'11o0guaoeow 06/30/2012 Printed 8/6/2012 10:06:30AM Z-115, Well History (Post Rig Work) Date Summary 07/21/12 T/I/0=Vac/0/0; Conduct PJSM; Barriers=SV&SSV.Verified by applying 500 psi against SV through tree cap. LTT Passed; R/U lubricator and test against SV to 300&3500 psi for 5 min. (LTT passed); Pull 4- 1/16" CIW"H" BPV#116 thru tree post Doyon 14; 1-1'ext. used, tagged @ 114"; RDMO; Install tree cap • w/new 0-ring and test to 500 psi for 5 min. (LTT passed). 07/21/12 (post-rwo/pre-frac). PULLED B&R FROM RHC IN XN NIPPLE @ 10746'SLM. PULLED BK-DCK FROM ST#5 @ 3682' SLM/3702' MD. SET BK-DGLV IN ST#5 @ 3682' SLM/3702' MD. LRS MIT-IA TO 4000 PSI, PASSED. 07/21/12 T/I/O=0/30/9 Temp=Sl Assist S-line MIT IA 4000 psi **PASS**(NEW WELL POST) Pumped 3 bbls of diesel down IA to reach test pressure of 4016 psi. 1st 15 mins Tbg gained 1 psi/IA lost 63 psi/OA lost 0 psi. 2nd 15 mins Tbg lost 0 psi/IA lost 13 psi/OA lost 0 psi.Total Test Tbg gained 1 psi/IA lost 76 psi/ OA lost 0 psi. Bled IA to 31 psi and got back 3 bbls. SLine in control of well per LRS departure. FWHP's= 0/31/9 CVs=OTG. 07/22/12 (post-rwo/pre-frac). PULLED 4-1/2" RHC FROM XN NIPPLE© 10752' SLM/10770' MD. DRIFT TUBING W/4-1/2" BRUSH &3.70"G. RING&TAG TD @ 11250' SLM. DRIFT W/20'x 2-3/8" DUMMY GUNS, TAG BTM @ 11,260' SLM. 07/23/12 (ELINE ADPERF). INTIAL T/I/O=0/0/0 PSI. RUN 1: RIH W/HEAD/ERS/PGGT/FIRING HEAD/20'3 3/8" POWER JET, 6 SPF, 60 DEG PHASING, PENETRATION =36.5" ENTRANCE HOLE=0.37" SWELL=3.66.TIED INTO SLB VISION SERVICE RECORDED MODE LOG 24-JUNE-2012. PERFORATED INTERVAL 10990-11010'. 07/24/12 T/I/O=0/0/0/Temp=Sl Assist E-line (Post RWO) Pumped a total of 14 bbls diesel & 170 bbls slick seawater to establish injectivity&then capped with 38 bbls diesel for FP. FWHP's=1750/0/2 DSO notified E-line on well &in control of all VLV's upon departure. 07/24/12 (ELINE PERFS). RUN 2: RIH W/20' GUN, CCL TO TOP SHOT=4.2', CCL STOP DEPTH = 10965.8', PERF INTERVAL 10970-10990'. RUN 3: RIH W/20'GUN, CCL TO TOP SHOT=4.2', CCL STOP i✓K" DEPTH = 10945.8', PERF INTERVAL 10950-10970'. RUN 4: RIH W/18'GUN, CCL TO TOP SHOT= 6.2', CCL STOP DEPTH = 10925.8', PERF INTERVAL 10932-10950'. 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W W W N W N O m m>OO[mi� >W J O W b0 OOgPw +W cN gg NO Z S O A m o W A P N N O� A P N N G N N N N N N C ON W N N N W 7 W umW AAA A A NE A+ W W VWV V N W J W pWp AO V OPi OI O PO V P P O m+W NV W giO ET W A O G+O IA! s GP A V g2228 *2 yy bOP O E p+O O+NWAo A W W ON1%A W.W O A N W W 17;:4 A W ,r O [IEEE Eiiii mEmAwEEE WW REM z aEONWyWWN OW !PH PA C O +NSWO +WWWV JOmNAAmNOP WWWWN G2 O 0 0 0 0 0 sagas W O O D 0 0 0 0 0 W O O D + N W +� E N N N O W W A A tr m Y W N W m J P PW A fmn E O>E N +N O N EINE m V mm w N iOm E V W A1WON OWiPON V Wggggg +Naris ws aD O 8, -66,648, 00000 86,61648 o0o64ggg8Joo NNN wO W ww wWm wmww win wwA wm w iWs A w P iVn in N w w r NNO + Vr EugWO •p (T N b bPP fOmPP W W PP 5 11111 (WP OmWo 11111 D m m O O VW VnWAN�VNA OVO VmWW VWW++�EJW mWO WWV EAN JWANp�W WOJ wW VAOA ENO EOV OPWA VNPO CW Wfn VW E+ W J N W W A W N N TREE= 4-1/16"CMV WELLHEAD- CM/ Z-115 SA f NOTES: CHROME TBG 8,LNR ACTUATOR= LEO INITIAL KB. ELEV= 89.94' 1 I BF.ELEV= 55.36' -- 818' H 13-3/8"TAM FORT COLLAR KOP= 481' Max Angle= 66°@ 9056' 1 111 2013' H4-1/2"HES X NIP,ID=3.813" Datum MD= 11056' Datum TVD= 6600'SS 2688' 113-318"X 10-3/4"BKR ZXP LTP w/ 20"CONDUCTOR,94#, H-40,ID= 19.124' 80' FLEXLOCK LNR HGR, ID=9.51" 2721' H 10-314"X 9-5/8"XO,ID=8.78" 13-3/8"CSG,68#, L-80 BTC, ID=12.145" H 2853' 1-4 II GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 3702 2792 62 KBG DM' BK 0 07/21/12 9-5/8"LNR,40#,L-80 BTC, ID=8.835" H 5244' 4 6642 4203 60 KBG DMY BK 0 06/29/12 3 8794 5187 62 KBG DIVK BK 0 06/29/12 2 9990 5785 50 KBG DMY BK 0 06/29/12 Minimum ID =3.726" ( 10770' 1 10524 6196 29 KBG OMY BK 0 106/29/12 4-1/2" HES XN NIPPLE I 1 10598' —14-1/2"HES X NIP, ID=3.813" 7"LNR,26#, L-80 VAM TOP HC XO 13CR-80 H 10613' X `'. VAM TOP 10627' —14-1/2"NDPG SINGLE-SENSOR SUB, ID=3.958" 10660' —H7'X 4-1/2"HES TNT PKR,ID=3.856" I I 10694' H4-1/2"HES X NIP, ID=3.813" i ' 10770' --14-1/2"HES XN NIP, ID=3.725" 41/2"TBG,12.6#,13CR-85 VAM TOP, H 10782' / \ 10782' H4-1/2"WLEG, ID=3.958" .0152 bpf, ID=3,958" H ELMD TT NOT LOGGED PERFORATION SUMMARY REF LOG:SLB VSR MODE ON 06/24/12 • 10894' --{7"MARKER JOINTWI RA TAGS ANGLE AT TOP PERF: 19°@ 10932' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10932- 10950 0 07/24/12 �A 3-318" 6 10950- 10970 0 07/24/12 Cr3-3/8" 6 10970-10990 0 07/24/12 3-3/8" 6 10990- 11010 0 07/24/12 7" LNR,26#, 13CR-80 VAM TOP XO L-80 BTC -{ 11244' PBTD H 11286' •.....14.0•+• 1.0.0.1.4.11....., 7"LNR,26#,L-80 BTC, .0383 bpf, ID=6.276" H 11369' DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 06/30/12 DOYON14 ORIGINAL COMPLETION WELL: Z-115 07/13/12 TW/JMD DRLG DRAFT CORRECTIONS PERMIT No:'2120550 07/14/12 PJC PKR,MKR JOINT,ETC AR No: 50-029-23468-00 07/25/12 LEGJMD GLV C/O(07/21/12) SEC 19,T11 N,R12E,846'FNL&2222 FWL 07/25/12 RM/JND ADPERFS(07/24/12) BP Exploration(Alaska) 0 by Date 9-28-2012 Transmittal Number: 93258 RECEIVE' BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. SEP $ 01 (BPXA FIELD LOG DATA) AOGCC If you have any questions, please contact Doug Dortch at the PDC at 564-4973 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 2N9lei 15-09B 2\2 024 21c1: 5C-02A 212-o\5 J-16B �Z��ct J-166P61 2-XL-0A J-27B 2.2.-0161 2\`)<Ct P2-51A 2X2-- kl P2-15AL1 '11qo Z-06A v.Z 0` S � 14(eeXer-1- &leie/ .• Please Sign and R urn one copy o this transmittal. Thank You, Doug Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Atm: Christine Shartzer 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RECEIVED ' STATE OF ALASKA A. AKA OIL AND GAS CONSERVATION COMMIaJION AUG 2 7 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1 Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Performed Alter Casing ❑ Pull Tubing❑ Stimulate-Frac s Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Wel❑ 2 Operator 4 Well Class Before Work: 5 Permit to Drill Number Name BP Exploration(Alaska),Inc Developments Exploratory ❑ - 212-055-0 3.Address P O Box 196612 Stratigraphic Service ❑ 6.API Number Anchorage,AK 99519-6612 50-029-23468-00-00 7.Property Designation(Lease Number): 8.Well Name and Number ADL0047450 a 5010, R I S Z-115 9 Logs(List logs and submit electronic and printed data per 20AAC25.071) t 10 Field/Pool(s): To Be Submitted PRUDHOE BAY,BOREALIS OIL ✓ 11.Present Well Condition Summary Total Depth measured 11379 feet Plugs measured None feet true vertical 8994 feet Junk measured None feet Effective Depth measured 11286 feet Packer measured See Attachment feet true vertical 6905 94 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2818 13-3/8"68#L-80 35-2853 35-2388 03 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 2533 9-5/8"40#L-80 2711-5244 2320 97-3527 31 5750 3090 Perforation depth Measured depth 10932-11010 feet True Vertical depth 6574.12-6647 54 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12 6#13Cr80 29-10782 29-6432 36 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary. Intervals treated(measured) 10932'-11010' Treatment descriptions including volumes used and final pressure YF130FIexD Gel System:54 Bbls 30#XL Gel,54 Bbls 30#Non-XL Gel,46 Bbls Mineral Oil,222,132 lbs 16/20 Carbolite Proppant behind pipe. 13 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation 8882 2465 820 1645 605 14 Attachments 15 Well Class after work Copies of Logs and Surveys Run Exploratory❑ Developments - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16 Well Status after work. Oil ,-111 Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUc-❑ 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 312-275 Contact Garry Catron Prepared by Garry Catron 564-4424 Printed Name Garry Catron Title PDC PE Signature ga,tAi, ci,v , Phone 564-4424 Date 8/27/2012 R6DMS AUG 3 2012 ,oitfi y ( °�Ifzl tz Form 10-404 Revised 10/2010 Submit Original Only Packers and SSV's Attachment ADL0047450 SW Name Type MD TVD Depscription Z-115 PACKER 2688 2219.67 13-3/8"x 10-3/4"ZXP Lnr Top Packer Z-115 PACKER 10660 6228.62 4-1/2" HES TNT PACKER a0000000 N0) - - '- CTI O 0 . M L() q 't V N M 7 LC) I- N N N O Nr m r LO r- r N- LC) CO a- COa- OMCO M LO M M O u CO ' CC) N N Op O co Nr MCOCO (0 (NI CO in O L N O •- tri (O In C� (y M r- CO M (N M N Co N CO CO _M ' 0) M N • (O N M I- .0 LO O �- N O a M ,. c- - ' 10 O) • 0 M N M CNIM N I—• 9 O ▪ a 0 O0 02 c0 0 N *k r *k CO CO UC C (R1 (0D (N N �) N N th Otr- M r � 4 Z O in C10 r l() C co L M N O I*- J N O CO N O o 000 �I- H i i (n DDDQC7 (° OCCOOOu_ Z O ZcerecenD 0 = aCl- av) I- Daily Report of Well Operations ADL0047450 ACTIVITYDATE I SUMMARY TWO 193/0/0 Temp= SI Perform step rate test(Pre FRAC) Load tubing with 2 bbls meth, 207 bbls 2% KCL. Perform step rate test at 1,2,3,5 bpm for 5 min each step. 1 bpm at 1176 psi, 2 bpm at 1398 psi, 3 bpm at 1444 psi, 5 bpm at 1637 psi. See log for details. Freeze protect tubing with 35 bbls diesel FWHP 1120/790/556 7/25/2012 SV,WV,SSV=closed, MV=open, IA and OA=OTG SLB Frac: Job Scope: Fracture I reatment- Kuparuk Sands: MIRU Frac equipment. 7/29/2012 PT frac iron to 8500 psi. ***Job Continued on 30 July 12*** SLB Frac: Job Scope: Fracture Treatment- Kuparuk Sands: Job Continued from 29 July 12. Pump breakdown, data frac, and fracture treatment. Datafrac analysis showed frac gradient= 0.61 psi/ft, ISIP = 1568 psi, Pc= 1195 psi, Tc = 13.2 min, eff = 0.63. Pump frac at 25 bpm using YF130FIexD gel system: Pad stage of 125 Bbls, 1 PPA Flat stage, ramp 1 PPA-6 PPA in 150 bbls, pump 6, 7, 8, and 9 ppa flat stages in 150 Bbls each. Pump 10 ppa flat stage in 204 Bbls. Flush volumes of 54 r Bbls 30#XL gel, 54 Bbls 30# non-XL gel, and 46 Bbls mineral oil. Seven Bbls of mineral oil in surface lines, and 39 Bbls in the well, placing freeze protect at 2566'. Pnet for frac= 910 psi. Pumped a total of 227,110 lbs of 16/20 Carbolite propant, of which 222,132 lbs were placed behind pipe with 4,978 lbs left in liner. Propant top at 7/30/2012 —11,075'. ***Job Complete*** 8/1/2012 ASRC Test Unit#2. Move to Z-115 for post frac flowback- Rig up ***Stand by*** ASRC Test Unit#2. Continue from WSR 08/1/12 S/B For Well Service Profile 8/2/2012 Clarification before any Work is done Per P.E ( Cody ) , Begin R/U 8/3/2012 ASRC Test Unit#2. Continue from WSR 08/2/12 8/4/2012 ASRC Test Unit#2. S/B for CTU ,Continue from WSR 08/3/12 8/5/2012 tTU #3 w 1.75" ct: Job objective: Post frac clean out CTU #3 w 1.75"ct: Job objective: Post frac clean out. MU FCO BHA w/2.63" JSN. RIH and tag at 10860' cmtd (72' of fill covering perfs). Bring pumps online to establish rate for 1:1 returns. 8/5/2012 <<<Job in progress. Continued on 8/5/12 WSR>>> ASRC Test Unit#2. S/B for C I U ,Continue from WSR 08/4/12 ***Continue standby 8/5/2012 for CTU ASRC Test Unit#2. S/B for CTU ,***Continue from WSR 08/5/12 *** Continue standby for CTU, Standby for slick line, 8/6/2012 ***Continue to WSR 8/7/12*** CTU #3 w/ 1.75" ct. Job Objective: Post frac clean out. <<<Continued from 8/5/12 WSR>>> Confirmed returns at 1:1 at 1.8 bpm. Begin POOH at 80%. Wash GLM's up/dn/up while pumping Powervis pills across them. Freeze protect from 2500' while POOH. 8/6/2012 «<Job complete>>> ***WELL SHUT IN ON ARRIVAL*** (new well post) DRIFT TBG W/3.625" CENT., TEL, 2.50" SAMPLE BAILER LOC TBG TAIL AT 10755' SLM, +27' CORR TO 10782' MD TAG TD AT 10840' SLM +27' CORR.= 10867' MD (rec. frac sand) CURRENTLY RIH W/4-1/2" CAT VALVE 8/6/2012 ***CONT WSR ON 8/7/12 *** ASRC Test Unit#2 ***Continue from WSR 8/6/12*** Inlet Well Z-115, Outlet Kill Flange Standby for Slick Line 8/7/2012 ***Continue to WSR 8/8/12 Daily Report of Well Operations ADL0047450 T/I/0=370/0/0 Temp=SI Assist S-line Pumped 5.5 bbls of 50*diesel down TBG TBG locked up 2837 psi monitor psi lost 14 psi in 10 min Bleed TBG psi downBleed back aprox. 3 bbls S-line on well on dep. Wing shut swab open ssv open master open 8/7/2012 casing valves open to gauges Final Whp's=420/0/0 ***CONT WSR FROM 8/6/12 ***(postrig/post frac) SET 4-1/2" CAT STANDING VALVE IN XN-NIP AT 10746' SLM(10770' MD) PULLED STA#4 BK-DGLV FROM 6624' SLM (6642' MD) PULLED STA#3 BK-DGLV FROM 8773' SLM (8794' MD) PULLED STA#1 BK-DGLV FROM 10507' SLM (10524' MD) PULLED CAT VALVE FROM 10746' SLM (10770' MD) LRS ATTEMPT TO DISPLACE TBG W/160 BBLS DIESEL (unable to pump down tbg) SET C-SUB @ 10741' SLM PULLED STA#2 BK-DGLV FROM 9974' SLM(9990' MD) PULLED STA#5 BK-DGLV FROM 3682' SLM(3702' MD) 8/7/2012 *** CONT WSR ON 8/8/12 *** *** CONT. WSR FROM 8/7/12 ***(postng/post-frac) SET BK-LGLV(16/64" ports,1672#tro) IN STA#5 AT3682' SLM(3702' MD) SET BK-LGLV(16/64" ports,1670#tro) IN STA#4 AT 6624' SLM(6642' MD) SET BK-LGLV(16/64" ports,1670#tro) IN STA#3 AT 8779' SLM(8794' MD) SET BK-LGLV(16/64" ports,1670#tro) IN STA#2 AT 9974' SLM(9990' MD) SET BK-LGLV(16/64" ports,1670#tro) IN STA#1 AT 10507' SLM(10524' MD) PULL EMPTY WHIDDON C-SUB FROM 10741' SLM 8/8/2012 ***WELL LEFT SHUT IN DEPARTURE, PAD OP NOTIFIED *** ASRC Test Unit#2 ***Continue from WSR 8/7/12*** Inlet Well Z-115, Outlet Kill Flange Standby for Slick Line 8/8/2012 ASRC Test Unit#2 ***Continue from WSR 8/9/12*** Inlet Well Z-115, Outlet Kill Flang Flow Well 8/10/2012 ASRC Test Unit#2 ***Continue from WSR 8/10/12*** Inlet Well Z-115, Outlet Kill Flange Flow Well ***8Hr Test Results*** 8/11/2012 ASRC Test Unit#2 ***Continue from WSR 8/11/12*** Inlet Well Z-115, Outlet Kill Flange Flow Well ***8hr Test*** ***Job Complete*** 8/12/2012 ASRC Test Unit#2 Inlet Well Z-115, Outlet Kill Flange Flow Well Stabilize well,*** Conduct 4hr Test*** Results of 1700-2100 Test 8/12/2012 ASRC Test Unit#2 Inlet Well Z-115, Outlet Kill Flange Flow Well Stabilize well, 8/12/2012 Continued WSR 8/11/12 Flow Well ASRC Test Unit#2 Inlet well Z-115 outlet Kill flange ***Stabilize well At 3000 bbls/d 8/13/2012 and conduct 6 Hr Test*** ASRC Test Unit#2 Inlet Well Z-115, Outlet Kill Flange Flow Well Stabilize well, Continued From WSR 8/12/12 Flow Well, ***6 Hr Test @ 4000 bbls/d**2nd test*** 8/13/2012 Job Complete*** Daily Report of Well Operations ADL0047450 -ASRC Test Unit#2 Inlet well Z-115 outlet Kill flange ***Stabilize well At 4000 bbls/d 8/14/2012 and conduct 6 Hr Test*** ASRC Test Unit#2 ***cont. from WSR 8/13/12*** Inlet well Z-115 outlet Kill flange 8/14/2012 ***Stabilize well and conduct 4 Hr Test*** ASRC Test Unit#2 ***Continue from WSR 8/14/12 *** Inlet well Z-115 outlet Kill flange ***Stabilize well At 4000 bbls/d and conduct 6 Hr Test*** 8/15/2012 *** Continue on WSR 8/16/12 *** ASRC Test Unit#2 ***Continue from WSR 8/14/12 *** Inlet well Z-115 outlet Kill flange ***Stabilize well At 4000 bbls/d and conduct 6 Hr Test. Test Completed*** Begin to step inlet choke back to achieve 2000 psi BHP per APE 8/15/2012 ***Continue on WSR 8/16/12 *** ASRC Test Unit#2 ***Continue from WSR 8/14/12 *** Inlet well Z-115 outlet Kill flange 8/15/2012 ***Stabilize well At 4000 bbls/d and conduct 6 Hr Test Test Completed*** ASRC test unit#2 ***Cont. WSR 8/15/12*** Inlet well Z-115 outlet well kill flange Z115 Flow Well Perform 6 hr Test ***Continue on WSR 8/16/12***6 Hr test data 8/16/2012 ASRC Test Unit#2 ***Continue from WSR 8/17/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115.Adjust CK Stabilize Well, Perform 6 hr test 8/17/2012 Continue FLowing ***Continue on WSR*** ASRC Test Unit#2 ***Continue from WSR 8/17/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115.Adjust CK Stabilize Well, Perform 6 hr test 8/17/2012 Continue FLowing ***Continue on WSR 8/18/12*** ASRC Test Unit#2 ***Continue from WSR 8/17/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115. Adjust CK Stabilize Well, Perform 6 Hr Test. Ended 6 Hr Test after 3 Hrs, Adjust CK to 36 beans, Start 6 Hr Test. Continue Flowing ***Continue on WSR 8/18/2012 8/18/18 ASRC Test Unit#2 ***Continue from WSR 8/18/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115. Adjust CK Stabilize Well, Perform 6 Hr Test. . Continue Flowing *** 8/18/2012 Continue on WSR 8/19/12 *** ASRC Test Unit#2 ***Continue from WSR 8/19/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115. Continue Flowing, Perform 2nd 6 Hr Test of Back to Back Tests. *** 8/19/2012 Continue on WSR 8/20/12*** ASRC Test Unit#2 ***Continue from WSR 8/19/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115. Continue Flowing, Perform 1st 6 Hr Test of back to back 6 Hr Tests. 8/19/2012 ***Continue on WSR 8/19/12*** ASRC Test Unit#2 ***Continue from WSR 8/18/12*** Inlet Well Z-115, Outlet Well Kill Flange Z-115. , Perform 6 Hr Test. . Continue Flowing ***Continue on WSR 8/19/12 8/19/2012 *** ASRC Well Test Unit#2. Inlet Z-115, Outlet Z-Kill Flange, R/D complete***Job Complete*** Carbolite total recovered = 8.9 bbls, Solids total recovered 46.8 bbls, 8/20/2012 Cumulative Solids total = 55.7 bbls TREE= 4-1/16"CM _WELLHEAD= OW Z-115 SAFETY NOTES: CHROME TBG&LNR ACTUATOR= LEO MWL KB.BEV= 89.94' 1 1 BF.ELEV= 55.36' -../ — , ' H 818' —113-3/8"TAM FORT COLLAR KOP= 481 Max Angie= 66"@ 9056' 2013' 4 1/2"HES X NP,ID=3.813' Datum MD= 11056' Datum ND= 6600'SS 2688' — 13-3/8"X 10-3/4"BKR ZXP LTP w/ 20"CONDUCTOR,94#,H-40,D= 19.124' — 80• FLIXLOCK LNR FOR,D=9.51" 2721' H 10-3/4"X 9-5/8"XO,D=8.78" 13-3/8"CSG,68#,L-80 BTC,D=12.145" H 2853' _A , GAS LFT M4NDRELS ST MT) ND DEV TYPE VLV LATCH PORT DATE 5 3702 2792 62 KBG DONE BK 16 08/08/12 9518"LNR,40#,L-80 BTC, ID=6.835' -j 5244' LI 4 6642 4203 60 KBG DONE BK 16 08/08/12 3 8794 5187 62 KBG DONE BK 16 08/08/12 2 9990 5785 50 KBG DOME BK 16 08/08/12 Minimum ID =3.725" @ 10770' 1 10524 6196 29 KBG SO BK 24 08/08/12 4-1/2" HES XN NIPPLE I I 10598' --I4-1/2"HES X NP,D=3.813" 7"LNR,26#,L-80 VAM TOP HC XO 13CR-80 H 10613' `. V VAM TOP ■ 10627' I-14-112'NDPG SINGLE-SENSOR SUB,ID=3.958" 5Z X 10660' —{7"X 4-1/2"FES TNT PKR D=3.856" ' ' 10694' -14-1/2"HES X NP,D=3.813" ' 1 10770' H4-1/2"HES XN NP,D=3125" 4-1/2'TBG, 12.64, 13CR-85 VAM TOP, H 10782' I-----/ 10782' —14-1/2"WLEG,D=3.958" .0152 bpf, ID=3.958" H ELM)TT NOT LOGGED PERFORATION SUMMARY REF LOG SLB V SR MODE ON 06/24/12 10894' —7'MARKER JOINT w/RA TAGS ANGLE AT TOP PERF:19`@ 10932' Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10932-10950 0 07/24/12 3-3/8" 6 10950-10970 O 07/24/12 3-3/8" 6 10970-10990 O 07/24/12 3-3/8" 6 10990-11010 O 07/24/12 7"LNR,26#,13CR-80 VAM TOP)Q)L-80 BTC H 11244' R3TD H 11286' •♦�♦�♦�'�'�'�'•••••• 7'LNR 26#,L-80 BTC,.0383 bpf,D=6.276" H 11369' DATE REV BY COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 06/30/12 DOYONI4 ORIGINAL COMPLETION WELL: Z-115 07/13/12 TW/JND DRLG DRAFT CORRECTIONS PERMT No: 120550 07/14/12 PJC PKR,MKRJONT,ETC AR No: 50-029-23468-00 07/25/12 LEG/JUT) GLV C/O(07/21/12) SEC 19,T11N,R12E,846'FM.&2222'FWL 07/25/12 RMJMD ADPERFS(07/24/12) 08/14/12 Tl-WJND GLV GO(08/08/12) BP Exploration(Alaska) I -, , H , ,,,:\ ,_, ,:, [---,, , (Th i-r-., T ,, .i,,i ,, , 1 N, , , i,„ , , ,,,, 111, p"u N 1 61 SEAN PARNELL, GOVERNOR ,: LI iti,,t,\ ALASKA OIL AND GAS / 333 W 7th AVENUE,SUITE 100 CONSERVATION COMMISSION / ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Joshua R. Allely Well Intervention Engineer BP Exploration (Alaska), Inc. _ Q 5.---S' P.O. Box 196612 I�c`' Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, Z-115 Sundry Number: 312-275 Dear Mr. Allely: 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, aff Cath P. Foerster Chair DATED this pi day of July, 2012. Encl. /A/1)1/4— ,1 ,,-✓ c STATE OF ALASKA .I RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS JUL 2 0 2012 20 AAC 25.280 1.Type of Request. Abandon❑ Plug for Redrill ❑ Perforate New Pool E Repair Well E Ao . •. o 0-rogram E Suspend❑ Plug Perforations❑ a Perforate ❑ Pull Tubing E Time Extension ❑ Operations Shutdown❑ Re-enter Susp.Well ❑ yStimulate E• Alter Casing❑ Other. ❑ 2 Operator Name: 4.Current Well Class 5 Permit to Drill Number BP Exploration(Alaska), Inc. Development 0 . Exploratory ❑ 212-055-0• 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-23468-00-00 • 7 If perforating,closest approach in pool(s)opened by this operation to nearest 8.Well Name and Number: property line where ownership or landownership changes' Spacing Exception Required'? Yes ❑ No ❑✓ Z-115. 9.Property Designation(Lease Number) ' 10.Field/Pool(s). ADL0047450 PRUDHOE BAY, BOREALIS OIL ' 11 PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft). Effective Depth MD(ft). Effective Depth ND(ft)• Plugs(measured): Junk(measured). 11379 6994 11286 6906 None None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"94#H-40 34-114 34-114 1530 520 Surface 2818 13-3/8"68#L-80 35-2853 35-2388 03 5020 2260 Intermediate None None None None None None Production See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Liner 2533 9-5/8"40#L-80 2711 -5244 2320.97-3527 31 3437 2321 Perforation Depth MD(ft). Perforation Depth ND(ft)• Tubing Size. Tubing Grade: Tubing MD(ft): None None 4-1/2"12.6#13Cr80 6432 29-10782 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft). See Attachment for Packer Depths No SSV Installed No SSV Installed 12.Attachments. Description Summary of Proposal Q 13.Well Class after proposed work. Detailed Operations Program ❑ BOP Sketch ❑ Exploratory [1 Development n Service ❑ 14.Estimated Date for �1 15.Well Status after proposed work Commencing Operations //30/ 20 t Z Oil Q • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval. Date: 7_ 2.1_i z_ WINJ ❑ GINJ ❑ WAG ❑ Abandoned ElCommission Representative. 67- C c Li)....---/11tL GSTOR ❑ SPLUG ❑ 17 I hereby certify that the foregoing is true land correct to the best of my knowledge. Contact Prepared by Garry Catron 564-4424 Printed Name 4.......---7e. -----.- Title 1/20/ed i Z Signature Phone Date JOSKUA 2 i}(la1 911-360-1362 II COMMISSION USE ONLY 312-2-7n Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /D _tJ Q y � J APPROVED BY Approved by' `�/ 4COMMISSIONER THE COMMISSION Date. 7- 3/- V^/ tos40a vi€eQ11 J 7-24i./Z, 0RIGINAL ,AerT4$, _Submit in Duplicate %,Li`l Casing Summary ADL0047450 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse CONDUCTOR 80 20" 94# H-40 34 114 34 114 1530 520 LINER 2533 9-5/8" 40# L-80 2711 5244 2321 3527 5750 3090 PRODUCTION 10582 7" 26# L-80 31 10613 31 6276 7240 5410 PRODUCTION 631 7" 26# 13Cr80 10613 11244 6276 6866 7240 5410 PRODUCTION 125 7" 26# L-80 11244 11369 6866 6984 7240 5410 SURFACE 2818 13-3/8"68# L-80 35 2853 35 2388 5020 2260 TUBING 10753 4-1/2" 12.6# 13Cr80 29 10782 29 6432 8430 7500 Packers and SSV's Attachment ADL0047450 Well Facility Type MD Top Description TVD Top Z-115 PACKER 2688 13-3/8" x 10-3/4" ZXP Lnr Top Packer 2310 Z-115 PACKER 10660 4-1/2" HES TNT PACKER 6319 To: Guy Schwartz rot, Senior Petroleum Engineerbp Alaska Oil& Gas Conservation Commission From: Josh Allely Wells Intervention Engineer BP Alaska Date: July 20,2012 Re: Z-115 Sundry Approval Sundry approval to perform a hydraulic fracture stimulation treatment on well Z-115 is requested. Planned Work: 1. SL Perform post rig work: Pull ball and rod and RHC. Drift for E-Line perf guns. 2. EL Perforate 10932-11010 (78')of Kup-C formation with 3-3/8"SLB perf guns. 3. FB Injectivity test with 1%KCl for basline injection parameters. 4. FB Fracture Stimulation [see detailed fracture treatment procedure] 5. CT Coiled Tubing FCO. Assessment of Cement Bonding of the Production Casing: The cement job was performed as designed and the casing was successfully pressure tested to 3500 psi. The cement job satisfied both state and BP requirements for zonal isolation and did not require running a cement bond log. BP's characterization of the cement bonding of the production casing is that it is competent for a keeping the fracture treatment in the target zone. Appendix A contains the cement job summary from Open Wells and the casing pressure test chart. MIT-IA and MIT-T Records The production packer was set as designed and the tubing was successfully tested to 3500 psi. The annulus(MIT-IA)was successfully tested to 3500 psi. Appendix B contains the pressure test summaries from Open Wells and the pressure test charts. Detailed Fracture Stimulation Procedure The detailed fracture stimulation procedure is attached in Appendix C. Please note that this is the planned designed with our current understanding the formation properties. It is common to modify the fracture stimulation procedure if data analysis suggests predicted rock properties are different to that observed on the data frac. The stimulation will be pumped by Schlumberger. Tubing Movement Calculations The production packer was supplied by Halliburton(7"x 4-1/2"TNT Packer)and the tubing movement calculations were also supplied by Halliburton using parameters supplied by BP. See Appendix D for the detailed report. Josh Allely Wells Intervention Engineer 564-5732 (w) 350-7362 (c) Clint Spence Wells Intervention Engineering Team Lead 564-5667 (w) 240-8047 (c) APPENDIX A: Cement Job Summary and Casing Test Chart Summary taken from Open Wells report Z-115 06-26-12 WHILE RECIPROCATING 20' STROKES PUMP 5 BBLS OF WATER AND PRESSURE TEST CEMENT LINES TO 250 PSI LOW 4000 PSI HIGH. PUW 265K, SOW 150K PUMP CEMENT AS FOLLOWS. -29.9 BBLS OF 11.1 PPG MUD PUSH AT 5 BPM -KICK OUT BOTTOM PLUG AND PUMP 12 PPG LEAD AT 5 BPM. (P- SHUT DOWN WITH PUMPS WITH 12.7 BBLS AWAY DUE TO - A'�' CEMENT SILO ISSUES CAUSING DENSITY TO DROP TO 10.6 5 �,< PPG. BRING PUMPS BACK UP TO 5 BPM WITH 12.0 PPG LEAD. AT 35 BBLS AWAY SLOW DOWN TO 1 BPM TO KEEP DENSITY !_G V - 6a ABOVE 11.6 PPG AND ADDRESS SILO ISSUE. PUMPei REMAINING CEMENT AT 6 BPM 12 PPG PUMPING A TOTAL OF -Cr 154.1 BBLS, 523 SX, 1.64 FTA3/SX OF 12 PPG LITECRETE. -SWAP OVER TO TAIL CEMENT AND PUMP ATOTAl. OF 41 1 ... BBLS, 198 SX, 1.17 FT^3/SX OF 15.8 PPG GASBLOK CEMENT AT 5 BPM WITH NO ISSUES. SWAP OVER TO RIG PUMPS DROP THE TOP PLUG AND DISPLACE THE CEMENT WITH 10.5 PPG NACL/NABR BRINE AS FOLLOWS: -PUMP 354 BBLS AT 7 BPM 960 PSI. STOP RECIPROCATION 293 BBLS INTO DISPLACEMENT SOW WENT FROM 150K TO 125K, LAND CASING HANGER AND CONTINUE DISPLACEMENT. -SLOW DOWN TO 5 BPM 1250 PSI AND PUMP 406 BBLS AWAY. -SLOW TO 3 BPM AND PUMP 423 BBLS. -SLOW TO 2 BPM AND BUMP PLUG WITH 430.4 BBLS AT 1110 ✓ PSI GIP AT 18:20 PRESSURE UP TO 1640 PSI AND HOLD FOR 5 MIN. BLEED OFF AND CHECK FLOATS. FLOATS HELD. RIG UP AND PRESSURE TEST 7"26#CASING 250 PSI LOW 5 MIN 3500 PSI HIGH FOR 30 MIN. -LOST 40 PSI IN THE FIRST 15 MIN AND 10 PSI IN THE SECOND 15 MIN. ,. -= 1` 7OL �, y y\� i a \ fi �� ` �� t`+ .�. N'` - \a • _ - ! / t. ,. alCOQ. Yt 9 _ , 94' i 1 lit In O i {y Z, r + f 1, - '0- • • \- 0 V am t` "' d 11 ‘...t,/,,I` / t,' ' \ , \ \ . . ,, _,., 50_07 '. ..,\:1,,...„:4:' /7/ ' / . f . 4000 l .y l \. -.,,...• / if - v • J / '. �� t ,.. , .. - . y^ _ j� ).. ., 1--- \ , / , ,... ___ 1 . 'I ..."-- ,•,,, / ` / _ , -1 . „... ,...„„ , • ,...... , ......._ . _20 0..___________ / . ...._ / .. ,.... ..... . ...„, ,,,., ....„ 1 , , .,,, ..„. • . _t____ t , , .,..., . ,. ___ _______ _ ____ - ., ... .....„1 ......, ...„ . -..„. .. . . .... . , -..,..... •--- 1 .....„-, . ,,, . ........_ .„. _ 10 0 . ,. .., .... , . ..,. ........ . , . ...„ ....._ „. : ..,.. •1- lo �� - __ ._ ___--..---- — - * �� ----- -w GI APPENDIX B: MIT-IA and MIT-T Test Summary and Pressure Test Charts Summary taken from Open Wells report Z-115 06-29-12 TEST TUBING 250 PSI FOR 5 MIN, 3500 PSI FOR 30 MIN -TEST TUBING TWICE. THIRD TEST SUCCESSFUL LOSING 70 PSI IN THE FIRST 15 MIN AND 30 PSI IN THE SECOND 15 MIN. -BLEED OFF TUBING TO 1500 PSI -TEST ANNULUS TO 250 PSI 5 MIN, 3500 PSI 30 MIN. LOST 90 PSI IN THE FIRST 15 MIN AND 10 PSI IN THE SECOND 15 MIN. -WTL APPROVAL OF TEST BEFORE PROCEEDING - . ""? . • , ' . N ...---i- 00 Z—'--- _-__-x.-_ - -.., :r >,..„>, Y . ,- _____ ___./.... —L , .41,..,. __ -\.\\ cam. t-_._.. i \ vr, / .\ . . \ \ . 00 ,r_L . r—`\ \\ \ !' ` \ y r-00 �r f 1 1 1 , 1 , ,v 0 �� \ i , ,,,,„ . . . " .4.,P — /At \2.,_._.g....._...4___.,(sic_.....1„0 1 ,, t � - .-_ K g _ - —Cr—. 7..) -.. _-1 w-...- °, WO \' �� I�,� 1,1"1- �` � I I ` I 1 .° .,y6%trp *i - / , ? , .. . i / i ,, .i i . . \ '\ \ ,,- . I \ , i U X' ..........._ .1.....60 , . / . / i \ N ; . - /. \ / •. / / ......' \' • --' -'- ' / L.-I'.''''' • \ ''/ , . ' / „ A .7 '../ .i, / • / '‘.' 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O Y 0 o f ❑ ❑ v a n a a a a CC z a b aaaa a 0 0 0) x 0 m U v w 0 O 4 a O O N tao IID `' 0 E F- CO U. o u. 0- w COpr ' r° N O E E o '� EW o Oa I 0000 > = m CO LU c m � > Utam Cl) 0 N7 I- H ° Cr as a s J ' Z a g o 0 m w IO L H Q Z F U N t•) a li) 0 = ' N iY .- N h Y h t0 1` a0 W m W J 1, W Cu 7 J J Q O O IO to r„,. N a) L 7 Z H co co) Q f Is Q d CO Q ~ a N ' H F H H y, 1L H m HO 0 3 0 Z _ ry « a3 APPENDIX D: Tubing Movement Calculations with Packer Performance Envelope HALLIBURTON Company: BPXA Well No.: Z-115 CY ��- Phone No: 907 854-2321 Contact: Frank Roach Well API No.: Lease Name: Z Pad OVERVIEW PURPOSE: This Tubing Movements report analyzes the effects of movements,forces,temperatures,and stresses occurring in the tubing string and down-hole tools during the specified operating scenarios.CyberString utilizes EnerTech engineering technology. PROJECT: Name: Z-1 15 Tubing Move Field location: Date: July 20,2012 Greater Prudhoe Bay Alaska,USA Comments: 60dcg completion fluid. FRAC Screen Out No problems are predicted1111 • Ji!L t I MU R MD Parameter Unit Injection Maximum Stress psi 39428.29 Max.Stress Location ft 10765.90 Buckling Length ft 0.00 Sign Conventions: Movement: +Elongation, -Contraction Force: +Tension(Upward),-Compression(Downward) THIS REPORT IS BASED ON SOUND ENGINEERING PRACTICES,BUT BECAUSE OF VARIABLE WELL CONDITIONS AND OTHER INFORMATION WHICH MUST BE RELIED UPON,HALLIBURTON MAKES NO WARRANTY,EXPRESSED OR IMPLIED,AS TO THE ACCURACY OF THE DATA OR OF ANY CALCULATIONS OR OPINIONS EXPRESSED HEREIN.YOU AGREE THAT HALLIBURTON SHALL NOT BE LIABLE FOR ANY LOSS OR DAMAGE,WHETHER DUE TO NEGLIGENCE OR OTHERWISE ARISING OUT OF OR IN CONNECTION WITH SUCH DATA,CALCULATIONS OR OPINIONS. HALLIBURTON Company: BPXA Well No.: Z-115 CY �1Phone No: 907 854-2321 Contact: Frank Roach {L4)��JR�"fi Well API No.: Lease Name: Z Pad INITIAL CONDITION Packer(TNT) : Well Deviation: Ilydraulic/Permanent/no mandrel movement. M.D. T.V.D. Start to set pressure: 1930.00 psi (ft) (ft) Plug depth: 10766.00 ft 0 0 Slackoff Force: 0.00 lb 1000 995 Packer Depth: 10766.00 ft 2500 2186 4365 3095 6427 4095 7300 4518 8600 5094 9600 5562 10766 6379 Measured Depth Tubing From To OD ID WT Min.Yield quid Frictior ft ft in in Ib/ft psi psi/100ft 0 10766 4.500 3.958' 12.600; 80000 0.00 Measured Depth Casing From To OD ID WT Min.Yield ft ft in in lb/ft psi 0 11311 7.000 6.276 26.000 80000 Measured Depth Tubing Annulus Fluid (M.D.) Pressure Temp. Density Axial Force Stress Dogleg Pressure Density ft psi °F Ib/gal lb psi deg/100ft psi Ib/gal 0 1 60.00 10.50 73039 20287 0 00 1' 10.50 1000 544 68.36 10.50 60556 17363 0.00 544 10.50 i 2500 1193 80.90 10.50 46035' 13979 0.00, 1193; 10.50 4365 1689 96.49 10.50 35447 11534 0.00 1689 10.50 6427 2235 113.73 10.50 23806 8847 0.00 2235 10.50 7300 2465 121.031 10.50 18882 7710 0.00 2465 10.50 9600 3035 140.25i 10.50 6818 4928 0.00 3035 10.50 10766 3480 150.001 10.50 -3034 2638 0.00 3480 10.50 Sign Conventions: Force: +Tension(Upward),-Compression(Downward) Z-115_Tubing Move_Screen Out Scenario.doc Page 2 07/20/12 HALLIBURTON Company: BPXA Well No.: Z-115 TRl� I B��SI Ill�� Phone No: 907 854-2321 Contact: Frank Roach U\ i Well API No.: Lease Name: Z Pad RESULTS FOR INJECTION SCENARIO Tubing fluid: Brine Tubing fluid density: 12.7 lb/gal Annulus fluid:Brine No pro• ems`are pre: c _.,,.•. Annulus fluid density:9.8 lb/gal Injection rate: 1260.0 gaUmin ,.- ' Injection duration:6.0 hour Injection pressure: 7650.0 psi we Injection temperature: 100.00°F - Annulus surface pressure:3500.0 psi _ Category j Parameter Unit Value Residual Tension lb 5667.294 Force lb 5667.294 Total Tension Length+Stretch ft 0.000 Ida x_ Stress Tool Passage Check:NOT ENABLED 39428 psi IDiff. Pressure across Pkr from psi below 5115 10706 ft MD I 1 1 Measured Depth Tubing Annulus Fluid (M.D.) Pressure Temp. Density Axial Force Stress Dogleg Pressure Density ft psi °F Ib/gal lb psi deg/100ft psi lb/gal 0 7650 100.24 12.71 96483 35608 0 00 3500' 9.80 1000 8307 102.20 12.71 84009 35243 0.001 4007 9.80 2500 9093 104.9212.71 69578 35348 O 00 4613 9.80 4365 9694 107.91 12.71 591531 35791 0 00 5076 9.80 6427 10354 111.22 12.71 476911 36576 0.00 5585 9.80- 7300 10633__- 112.67 12.71 42843 36996 0.00 5800 9.80 9600 11322 116.58 12.71 30983 38243 0.00 6332 9.80 10766 11862 118.96 12.71 211961 39428 0.00 6748 9.80 Sign Conventions: Force: + Tension(Upward),-Compression(Downward) Z-1 15_Tubing Move_Screen Out Scenario.doc Page 3 07/20/12 HALLIBURTON Company: BPXA Well No.: Z-115 �(r Phone No: 907 854-2321 Contact: Frank Roach CYBEf S tjIt it ti Well API No.: Lease Name: Z Pad GRAPHS Stress Profile Tubing Stress(psi) 35000 36000 37000 38000 39000 40000 1000- ( 2000- 3000- L• 4000 0 5000- v 6000- m 7000 8000 9000 10000 11000 - Injection' Z-115_Tubing Move_Screen Out Scenario.doc Page 4 07/20/12 HALLIBURTON Company: BPXA Well No.: Z-115 CYBERSTO• Phone No: 907 854-2321 Contact: Frank Roach Well API No.: Lease Name: Z Pad Temperature Profile Tubing Temperature('F) 100 102 104 106 108 110 112 114 116 118 120 0 1 1 , 1 1 $ $ 4 I I I I 1 F I * 1 1000 2000- 3000 = 4000- T 5000-- a - 6000- rn v 7000- 8000- 9000- _ 10000 000- 10000- 11000- niection Z-115 Tubing Move Screen Out Scenario.doc Page 5 07/20/12 HALLIBURTON Company: BPXA Well No.: Z-115 Phone No: 907 854-2321 Contact: Frank Roach CYBERSIIIK Well API No.: Lease Name: Z Pad Pressure Profile Tubing Pressure(psi) 7000 8000 9000 10000 11000 12000 0 1 1 i 4 1 / f 1 1000 2000- • 3000- a 4000 p 5000 6000 aai 7000 8000 9000- 10000- 11000- Injection) Z-115_Tubing Move_Screen Out Scenario.doc Page 6 07/20/12 • HALLIBURTON Company: BPXA Well No.: Z-115 Phone No: 907 854-2321 Contact: Frank Roach CyBERS R I Well AP/No.: Lease Name: Z Pad DogLeg Profile Tubing DogLeg(degll 00ft) 0 1 0' I 1000 • 2000 • 3000 • L 4000 - 5000 - T, - L 6000 • 2 7000 8000 - 9000 10000 r 11000- Injection Z-I 15_Tubing Move Screen Out Scenario.doc Page 7 07/20/12 HALLIBURTOI Company: BPXA Well No.: Z-115 R �(±• Phone No: 907854-2321 Contact: Frank Roach CyBERSTIIiIG Well API No.: Lease Name: Z Pad Force Profile Tubing Axial Force(Ib) 20000 40000 60000 80000 100000 0 $ 4 ---4 1000 2000 • 3000 4000 p 5000 6000 f: N N 7000 8000 9000 10000 11000 Injectio Z-I 15_Tubing Move_Screen Out Scenario.doc Page 8 07/20/12 HALLIBURTON Company: BPXA Well No.: Z-115 CY {l�J(w'�J/1��- Phone No: 907 854-2321 Contact: Frank Roach EL Well API No.: Lease Name: Z Pad Packer Operating Envelope 200000 n 100000- J a . d a) 0 ! a) } o w -100000 U O W -200000 -300000 -10000 -5000 0 5000 10000 Differential Pressure(psi) Injection! Z-115 Tubing Move_Screen Out Scenario.doc Page 9 07/20/12 TREE= 4-1/16"CIW — ' WELLFEAD= CNV Z–1 1 5 SA,,fY NOTES: CHROME TBG&LNR ACTUATOR= LEO NTIAL KB.H-EV= , 89.94' 1 1 BF.l3EV= 55.36' / — -H 818' -j13-3/8"TAM PORT COLLAR _KOP= 481' Max Angle= 66° 9056' ' I 2013' –14-1/2"HES X NP,ID=3.813" Datum MD= 11056' Datum TVD= 6600'SS 2688' 113-3/8"X 10-3/4"BKR ZXP LTP w/ 120"CONDUCTOR,94#,H-40,D= 19.124' -H go• FLEXLOCK LNR HGR,D=9.51" 2721' –110-3/4"X 9-5/8"XO,D=8.78" 133/8"CSG,68#,L-80 BTC,D=12.145' H 2853' GAS LIFT MANDRELS ST MD 'VD DEV TYPE VLV LATCH PORT DATE 5 3702 2792 62 KBG DCK BK 0 06/29/12 19-5/8"LNR,40#,L-80 BTC, ID=8.835" {—H 5244' I 4 6642 4203 60 KBG DMY BK 0 06/29/12 3 8794 5187 , 62 KBG DMY BK 0 06/29/12 2 9990 5785 50 KBG DMY BK 0 06/29/12 Minimum ID =3.725" @ 10770' 1 10524 6196 29 KBG DMY BK 0 06/29/12 4-1/2" HES XN NIPPLE I I 10598' --I4-1/2"I-ES X NP,D=3.813" 7"LNR 26#,L-80 VAM TOP HC XO 13CR-80 H 10613' �n VAM TOP ■ 10627' H4-1/2'NDPG SINGLE-SENSOR SUB,ID=3.958" Z . - 10660'J–{7"X 4-1/2"HES TNT PKR,D=3.856" ' r 10694' –14-1/2"I-16 X NP,D=3.813" I I 10770' —14-1/2"HES XN NP,D=3.725" 4-1/2"TBG, 12.6#,13CR-85 VAM TOP, — 10782' 1 / \--1 10782' –I4-1/2"MEG,D=3.958" i 0152 bpf, ID=3.958" —1 ELMD TT NOT LOGGED PERFORATION SL1 IAARY REF LOG: ANGLE AT TOP PERF: Note:Refer to Production DB for historical perf data 0 10894' –17'MARKER JOINT w/RA TAGS SIZE SPF MER'/AL Opn/Sqz DATE ve 7"LNR,26#, 13CR-80 VAM TOP XO L-80 BTC -r 11244' A A PBTD H 11286' ••••••M..•.•.•P P. 7"UNE,26#,L-80 BTC,.0383 bpf,D=6.276" J 11369' ........../.........., DATE REV BY i COMMENTS DATE REV BY COMMENTS BOREALIS UNIT 06/30/12 DOYON14 ORIGINAL COMPLETION 1 WELL: Z-115 07/13/12 TW/.LID DRLG DRAFT CORRECTIONS 1 PERMIT No:"2120550 07/14/12 PJC .PKR,MKR JOINT, ETC I API No: 50-029-23468-00 SEC 19,T11N,R12E,846'FNL&2972'FWL BP Exploration(Alaska) f'W: Z-115 Fracture Stimulation Sundry Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Sunday, July 29, 2012 8:29 AM To: 'Allely, Josh (BPXA)' Subject: RE: Z-115 Fracture Stimulation Sundry (PTD 212-055) Josh, I have reviewed the sundry application. Good job on completeness... You have verbal approval to proceed wit the Hydraulic fracture of Z-115 as proposed. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Allely, Josh (BPXA) [mailto:Josh.Allely@bp.com] Sent: Friday, July 27, 2012 4:59 PM To: Schwartz, Guy L (DOA) Subject: FW: Z-115 Fracture Stimulation Sundry Guy Apologies for all the e-mails concerning this topic, normally I have this all taken care of prior to scheduling the job. Unfortunately, we did not receive the Sundry for the Z-115 frac as of late afternoon Friday. You had indicated on Wednesday that was in the process of being signed. Assuming that happened, and all we are waiting for is the delivery, is there another mechanism by which I can get a copy of the Sundry or approval to proceed so that we can pump the job on Monday? Thanks Josh Josh Allely Well Intervention Engineer BP Alaska 907-564-5732 (office) 907-350-7362 (mobile) From: Catron,Garry R(Wipro) Sent: Friday,July 27,2012 10:32 AM To: Allely,Josh(BPXA) Cc: Lastufka,Joseph N(Northern Solutions) Subject: RE:Z-115 Fracture Stimulation Sundry Josh, Joe is off today for Flex-Friday. As of late yesterday, He had not received the 10-403 for Z-115. If it arrives via courier today, I'll let you know. 7/29/2012 'FW: Z-115 Fracture Stimulat;— Sundry Page 2 of 2 Regards, Garry Catron (Wipro) PDC Principal Engineer BP Headquarters Bldg L270D office: +1 907 564-4424 email: Garry.Catron@bp.com From: Allely, Josh (BPXA) Sent: Friday, July 27, 2012 10:25 AM To: Lastufka, Joseph N (Northern Solutions); Catron, Garry R(Wipro) Subject: Z-115 Fracture Stimulation Sundry Gary, Joe I'm trying to track down a Sundry for Z-115. I spoke with Guy Schwartz on Wednesday and he indicated that it was with the commissioners and should have been signed on Wednesday. Any chance it has made it to BP today? Thanks Josh Josh Allely Well Intervention Engineer BP Alaska 907-564-5732 (office) 907-350-7362 (mobile) 7/29/2012 [F Y 1 SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Pool, Z-115 BP Exploration (Alaska), Inc. Permit No: 212-055 Surface Location: 4434' FSL, 2732' FEL, SEC. 19, T11N, R12E, UM Bottomhole Location: 1597' FSL, 1354' FEL, SEC. 07, T11N, R12E, UM Dear Mr. Allen: Enclosed is the approved application for permit to 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 Commission 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 Commission 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 Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, • Daniel T. Seamount, Jr. Commissioner nI DATED this 2 day of May, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASK SIL AND GAS CONSERVATION COMMIL. JN PERMIT TO DRILL 20 AAC 25.005 1 a.Type of work: 1 b.Proposed Well Class: ®Development Oil 0 Service-Winj ®Single Zone 1 c. Specify if well is proposed for: ® Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Re-Entry ❑ Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 15.Bond: ® Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 . Z-115 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11311' TI/D 6890' ' Prudhoe Bay/Borealis ` 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Surface: ADL 028262&047450 4434'FSL,2732'FEL, Sec. 19,T11N, R12E, UM • Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 1496'FSL, 1294'FEL, Sec.07,T11 N, R12E, UM June 3,2012 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 1597'FSL, 1354'FEL,Sec.07,T11 N, R12E, UM 2560 11200' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 90.2' feet 15.Distance to Nearest Well Open Surface: x- 599944 - y-5959240 ' Zone- ASP4 GL Elevation above MSL: 55.9' ' feet to Same Pool: 3160' ' 16.Deviated Wells: Kickoff Depth: 300' feet 17.Maximum Anticipate Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 65 degrees Downhole: 0 358 t L4' Surface: .2844- .3,/38 p.s.. �� 18. Casing Program: Specifications Top-Setting Depth-Bottom fl Quantity of Cement,c.f.or sarcks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" 91.5# _ H-40 _ PE 80' Surface Surface 80' 80' 260 sx Arctic Set(Aoorox.) 16" 13-3/8" 68# _ L-80 BTC 2933' Surface Surface, 2933' 2400' 2091 sx DeeoCrete.315 sx Class'G' 12-1/4" _ 9-5/8" 40# L-80 _ BTC 2521' 2783' 2327' _ 5304' 3550' 1094 sx Class'G' 8-3/4" _ 7" 26# 13CR85 VamTop Surface Surface_Surface 11311' 6890' 377 sx LiteCrete. 195 sx Class'G' 19. PRESENT WELL.CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 20.Attachments: ❑ Property Plat ®BOP Sketch IN Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis ®Diverter Sketch 0 Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Frank Roach,564-4373 Printed Name Ken Allen Title Engineering Team Leader , Prepared By Name/Number Signature _.,..1.:____:1—d-7. ,�--_�. _ Phone 564-4366 Date 6/2- Joe Lastufka,564-4091 Commission Use Only Permit To Drill . /.2_6(.74--)c--,-- API Number: 7 Permit pr vol te: I See cover letter for Number: �l - 50-62cr'GS7e.E -etroc 2 %r/.— other 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 shales:[� Other: •K 35&0 Ste- g ! /ey. , Samples Req'd: 0 yes I No Mud Log Req'd: 0 yes I 'No j4 I ' HZS Measures: 0/Yes ❑No Directional Survey Req'd: B-Yes 0 No � o,, ((�� art;aOL6vt-' Z S:033�' � k.�a el")..... r e ...... tel/ 14 eir • cc S id-.rn . �'` -Ae- Sk.C.J7 Alf APPROVED BY THE COMMISSION L Date lill'4L111111111.81.l."P' ,COMMISSIONER Form 10-401 Revised 0 /2009 Th' ij iss ay fob 2 " nths from th ate of approval(20 AAC 25.005(8)) Submit In Duplicate j ,i,1 t7 f 1 V t.. y-36-/z, .. f��;� .,,ri,- Well Name: Z-115 Drill and Complete Plan Summary Name Position Office Home Cell Frank Roach Drilling Engineer 4373 854-2321 306-9023 Roger Sels New Well Delivery Geologist 5215 240-8096 , Bob Dawson Ops Geologist 5264 345-3359 242-2391 Mike Francis New Well Delivery PE 4240 644-0534 529-8678 Type of Well (service / producer/ injector): Producer Surface Northing Easting Offsets TRS • Location 5,959,240.03 599,943.56 4433.39 FSL / 2731.42 FEL 11N, 12E, 19 Target Northing Easting TVDss Offsets TRS Locations 5,966,880 601,250 -6475 1496' FSL / 1294' FEL 11N, 12E, 7 Bottom Northing Easting TVDss Offsets TRS Location 5,966,980 601,188 -6800 1597' FSL / 1354' FEL 11N, 12E, 7 API NUMBER: NA Rig: Doyon 14 Estimated Start Date: 06/03/12 Operating Days to complete: 32.3 MD: 11311' TVD: 6890' RT/GL: 34.3/55.9' RTE: 90.2 Well Design: Grassroots Kuparuk Producer 4-W tbg, 12..6#.43 /am Top, 7" 26# L-80 Vam Top HC solid casi erforated pos Objective: Kuparuk C-Sand A-Sand Directional Plan: Version: SLB P18b KOP: 300' MD, build 1.0/100 Maximum Hole Angle: 64.5° Close Approach Wells: All wells pass major risk criteria. Reference anti-collision report Nearest well within Pool TD 3160' from Z-113 Distance to Nearest Property PBU boundary 11,200' west of T.D. Line: Z-115 Permit Application Page 1 Logging Program: Surface Interval Drilling, MWD: Dir/GR/Res Open Hole: None _ Cased Hole: None Intermediate Interval Drilling, MWD: Dir/GR/RES Open Hole: None _ Cased Hole: None Production Interval Drilling, MWD: Dir/Real time GR/RES/AziDEN/NEU Open Hole: None Cased Hole: None Mud Program: 16" Surface Hole: Fresh Water Drilplex Mud Density Funnel Viscosity LSYP Yield Point API FL pH (ppg) (seconds) (2x3-6 rpm) (Ib/100ft2) (mis/30min) Spud to TD 8.8—9.5 . 60-120 (for reference 30—50 40— 100 Less than or 10.8 only. Fluid should be equal to 8 run off LSYP) 12-1/4" Intermediate Hole: LSND MW PV YP API FL Interval pH (ppg) (cp) (Ib/1000ft2) (ml/30min) Casing Shoe to TD 9.0 -9.5 12 - 18 20-28 < 8 9 - 10 8-3/4" Production Hole: LSND Depth Interval Density (ppg) PV YP API Fl pH Csg Shoe to TCM1 9.0 - 9.5 12 - 18 20 -28 < 6.0 9 - 10 TCM1 to TD ----10.2 - 10.4 12 -22 20 -28 < 4.0 9 - 10 Casing/Tubing Program: Hole Size Csg/ Wt/Ft Grade Connection Length Top Btm Tbg O.D. MD/TVD MD/TVD 42" 20" 91.5 H-40 PE 80' GL 80'/80' 16" 13-%" _ 68 L-80 BTC 2933' GL 2933' /2400' 12-W 9-%" 40 L-80 BTC 2521' 2783' /2327' 5304' / 3550' 8-3/ 7 26 13Cr-85 VAM TOP HC 11311' GL 11311' /6890' Tubing 4 1/2" 12.6 13Cr-85 VAM TOP 10892 GL 10892' /6504' Z-115 Permit Application Page 2 Formation Integrity Testing: Test Point Depth Test Type 13-%" Surface Casing 20' —50' from surface shoe LOT Test Point Depth Test Type 9-%" Intermediate Casing 20' —50' from intermediate shoe LOT Cement Calculations: Surface Casing: Casing Size 13-3/8" Basis: Lead: Open hole volume +350% excess in permafrost, 40% excess below permafrost Port collar used if necessary. Lead TOC: Surface Tail: Open hole volume +40% excess below permafrost+ 80' shoe track. Tail TOC: 1000' MD above the casing shoe Total Cement Volume: Lead 700 bbl/3930 ft'/2091 sks of DeepCRETE at 11.0 ppg and 1.88 'Tcfrst Tail x`65 bbl /365 ft'/315 sks of Class 'G' at 15.8 ppg and 1.16 cf/sk Intermediate Liner: Casing Size 9-%" Basis: Lead: NA Lead TOC: NA Tail: Open hole volume 40% excess + 80' shoe track + 200' 13-%" 68#CSG x 5" DP annulus Tail TOC: 200' MD above liner top Total Cement Volume: Lead None Planned Tailbbl/1269 ft'/ 1094 sks of Class 'G' at 15.8 ppg and 1.16 cf/sk Production Casing: Casing Size 7" Basis: Lead: Open hole volume 30% excess Lead TOC: 1000' MD above top Ma sand Tail: Open hole volume 40% excess + 80' shoe track v/Tail TOC: 1000' MD above the casing shoe Total Cement Volume: Lead53 bbl-/859 ft3/377 sks of LiteCRETE at 12.5 ppg and 2.28 cf/sk Tail O. bbl /228 ft'/ 195 sks of Class `G' at 15.8 ppg and 1.17 c51/sk Z-115 Permit Application Page 3 Formation Markers: Estimated Depth Fluid Most LikeII Minimum Maximum Formation Formation Top Uncertaintg Tgpe Pore Pressure Pore Pressure Pore Pressure (TYOss) (•t-TVD ft) (for sands) (EMV ppg) (EMV ppg) (EMV ppg) G1 270 .1-20' Permafrost 8.4 8.35 8.45 SV6 1,030 .l-20' Permafrost 8.4 8.35 8.45 EOCU 1,620 .l-20' Permafrost 8.4 8.35 8.45 SY5 1,685 4-20' Permafrost 8.4 8.35 8.45 BPRF 1,750 •l-'20' Permafrost 8.7 8.35 8.9 raumc I ' (Highland State 1,800 4-200'MO 8.7 8.35 8.9 Nk Fautrl SV4 1,815 •1-20' 8.7 8.35 8.9 SV3 2,150 .1-20' Hydrates 8.7 8.35 9.3 SV2 2,350 •l-20' Hydrates 8.7 8.35 9.3 SY1 2,685 4-20' Hydrates 8.7 8.35 9.3 UG4 :3,005 .1.20' Coal 8.7 8.35 9.3 UG4A 3,050 •l-20' Heavy oillgas? 9.3 8.35 9.3 UG3 3,420 .l-20' Wet 8.7 8.35 8.8 UG1 4,005 •l-20' Wet 8.7 8.35 8.8 UG Ma 4,250 •l-20' Wet 8.7 8.35 8.8 UG_Mb1 4,335 •l-20' Wet 8.7 8.35 8.8 8.7 8.35 8.8 UG_Mb2 4,390 •l-20' Wet 8.7 8.35 8.8 UG_Mc 4,465 •l-20' Wet 8.7 8.35 8.8 SB_Na 4,530 4-20' Wet 8.7 8.4 8.7 SB_Nb 4,560 .l-20' Oil 8.7 8.4 8.7 SB_Nc _ 4,595 .l-20' Wet 8.7 8.4 8.7 SB_OA 4,690 .1.20' Wet 8.45 8.4 8.7 SB_OBa _ 4,760 4-20' Wet 8.45 8.4 8.7 SB_OBb 4,795 .l-20' Wet 8.45 8.4 8.7 SB_OBc 4,850 •l-20' Wet 8.45 8.4 8.7 SB OBd 4,910 .l-20' Vet 8.45 8.4 8.7 Fault 2(Z Pad 4,920 •1-150'MD 8.7 8.4 8.7 Fault SB_OBe absent-faulted .l-20' Possible oil 8.7 84 8.7 SB_OBf absent-faulted •l-20' Possible oil 8.7 84 8.7 ; SB_OBI_Base absent-faulted •l-20' Possible oil 8.7 8.4 8.7 LI. CM2 5,390 •l-30' No 8.7 8.45 8.7 ei 1)* CM1 5,820 .1-30' No 9.5 9.4 10.2 --'�-TLBK 6,160 .1-30' No 10 94 10.7 ,(L THRZ 6,290 •l-30' No 10 9.4 10.3 1- ' 4 TKLB 6,455 •l-30' No 10 9.4 10.3 TKC4 6,475 .l-30' Oil/Gas? 8.2 64 10.4 TKC3E 6,485 .l-30' Oil/Gas? 8.2 6.4 10.4 TKC2A 6,505 .1-30' Oil/Gas? 8.2 6.4 10.4 TKC1C 6,535 .l-30' Oil/Gas? 8.2 6.4 10.4 TKBILCU 6,550 4-30' Oil/Gas? 9.95 8.45 10.4 3588 p TKA6 6,625 .l-30' Oil 9.95 8.45 10& , ---u,. TKA5 6,635 .1-30' Oil 9.95 8.45 10.4 ).b-AO TMLV 6,700 •l-30' Water 10 9.6 10.3 TO 6,800 .1-30' 10 9.6 10.3 Z-115 Permit Application Page 4 Well Control: 16" hole will be drilled with diverter. The 12 '/4" intermediate hole and the 8 %" production hole will use well control equipment consisting of 5000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Annular preventer and the rams will be tested to 3500 psi. The BOP test frequency will be conducted on a 14 day frequency, with a function test every 7 days. Except for significant operational issues that may effect well integrity or pose safety concerns, an extension to the 14 day BOP test period should not be requested. Diverter routing, BOPE and choke manifold schematics of Doyon 14 are attached to this permit to drill. •355' �,�� J bt r t'�� (v.&( /,):;1- Production Production Interval- _ • Maximum anticipated BHP: 3,480 psi @ 6,635' TVDss, 9.95 ppg EMW • Maximum surface pressure: 2,817 psi @ surface << , (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: • Annular Preventer 250 / 3,500 psi • Rams 250 / 3,500 psi • Planned completion fluid: 10.5 ppg brine from 10,766'MD (TD) to 500'MD / 6.8 ppg diesel from 500'MD to surface (Freeze Protect) = 3,570 psi. Expected BHP seen at TD is 3,480 psi Kick Tolerance/ Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure 13-%" Surface 3500 psi 25 BBLS (assuming 9.5 9.3 LOT Casing _ 11.2 LOT) 9-%" Intermediate 3500 psi 25 BBLS (assuming 10.2 10 LOT Liner 12.1 LOT) 7" Production 3500 psi NA NA NA NA Casing Disposal: • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. Variance Request: To avoid the risk of plugging the flow line with large rocks and wood encountered while drilling surface hole, it is requested to drill without a flow paddle for the first portion of the surface hole. After drilling past the larger rocks and wood sections, the flow paddle will be put back in the flow line (<1000'). Z-115 Permit Application Page 5 Z-115- Drill and Complete Procedure Summary Pre-Rig Work: 1. Inspect Cellar Box and 20" conductor 2. Weld an FMC landing ring for the FMC Gen 5 wellhead on the conductor. 3. If necessary, level the pad and prepare location for rig move. Shut in nearby wells, bleed off process lines, and remove well houses as necessary. Rig Operations: r t ovv4L-t 1. MIRU. Nipple up diverter spool and function test diverter. Give the AOGCC 24 hrs notice prior to function testing. 2. Prepare pits with Drillplex Mud and PU DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/GR/Res and directionally drill surface hole to TD in the SV3. If needed, perform wiper trip at the base of permafrost. CBU and condition hole as necessary, then POOH for casing. 4. Run and cement 13-%" surface casing. A TAM port collar may be run at 500' as a contingency. 5. ND diverter and NU casing / tubing head. NU BOPE (Configured from top to bottom: annular ✓ preventor, 3-%"x 6"VBR, blind/shear, mud cross, 2-%"x 5"VBR). Test BOPE to 250 psi low, 3500psi high. Give the AOGCC 24 hrs notice prior to testing. 6. Make up 12-W drilling BHA with MWD/GR/RES and RIH to float collar. Pressure test 13-%" casing to Ll 3500 psi for 30 minutes. Drill out shoe track and displace well to LSND drilling fluid. Drill 20' of new formation and perform LOT. Minimum requirement for leakoff is 11.20 ppa EMW 7. Directionally drill remainder of surface hole to TD in the UG3. If needed, perform wiper trip to previous casing shoe. CBU and condition hole as necessary, then POOH for liner. 8. Change out 3-%" x 6" VBRs for 9-%" casing rams and test with 9-%" test joint to 250 psi low, 3500 psi high. 9. Run and cement the 9-%", 40.0 lb/ft L-80 drilling liner with 150' overlap into the 13-%". Displace cement with mud and set hanger/liner top packer. POOH 10. Change out 9-%" casing rams for 3-W x 6" VBRs and test with 5" test joint to 250 psi low, 3500 psi high. 11. Pressure test 9-%" liner x 13-3/" casing to 3500 psi for 30 minutes. Perform negative pressure test on 9-%" liner top packer. 12. Make up 8-3/4" drilling BHA with MWD/GR/RES/AZI-DEN/NEU/PWD and RIH to float collar. Drill out shoe track and condition LSND drilling fluid. Drill 20' of new formation and perform LOT. Minimum requirement for leakoff is 12.10 o.pa EMW. - 13. Drill to ± 200' above the HRZ, ensure mud is conditioned and properly weighted (10.2 ppg) for shale stability, and perform short trip as needed. Ensure pre-reservoir meeting is held highlighting kick tolerance and detection prior to entering the HRZ. 14. Drill ahead to target TD, (below top TMLV). Ensure LWD/MWD has logged entire Kuparuk formation before calling TD. Circulate and condition fluid. Back-ream/MAD Pass as required, then trip back to TD. CBU and POOH to run casing. 15. Change 3-'/2" x 6" VBRs to 7" rams and test with 7" test joint to 250 psi low, 3500 psi high prior to running casing. Z-115 Permit Application Page 6 16. Run 7" production casing and cement in 1 stage. Displace with brine. Bring TOC to —500' above the Schrader. Bump plug and ensure that float holds. Pressure test casing to 3500 psi for 30 minutes. 17. Change 7"casing rams to 3-'/z"x 6"VBRs and test with 4-%"test joint to 250 psi low, 3500 psi high. 18. Freeze protect 7"x 13-%/9-%"annulus. 19. Run 4-%" 13Cr-85 completion w/6 GLM and land tubing hanger. RILDS. 20. Reverse circulate clean brine followed by corrosion inhibited brine for IA. Drop RHC ball and rod on rollers and set packer as per Halliburton recommendation and test tubing to 3500 psi and annulus to 3500 psi. Shear the DCK valve and pump both ways to confirm circulation ability. 21. Install and test TWC. Nipple down the BOPE. Nipple up and test double master valves to 5000 psi. RU DSM and pull TWC. 22. Freeze protect the well to 500' TVD by pumping diesel down IA w/ Hot Oil truck, taking clean brine returns to surface Allow diesel to u-tube into tubing. 23. Install BPV in tubing hanger. Install all annulus valves and secure the well. Ensure that T/IA/OA are protected with two barriers. RDMO. Post-Rig Work: 1. Install tree with electric valve. Pull BPV. 2. R/U Slickline and pull ball and rod / RHC. 3. Replace the DCK shear valve with a dummy GLV. 4. Perforate post-rig with e-line 5. Perform frac job on KuDaruk C-Sands. 6. Pull dummy valves and replace with gas lift valves. Pull VR Plugs. 7. Flowback well through test separator until production stream acceptable for GC processing. 8. Install wellhouse(s)and flowline(s). 9. Pump RG2401 (Blue-Goo) on top of surface casing cement. Z-115 Permit Application Page 7 POST THIS NOTICE IN THE DOGHOUSE Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control: A. The Schrader Bluff reservoir could be pressured as high as 8.7 ppg EMW. B. The Lower Brookian (TLBK) had to be drilled with a 10.7 ppg due to over pressure on Z-08. Most likely pressure is 10.0 ppg. C. The Kuparuk sands may be pressured as high as 10.4 ppg EMW due to pressure uncertainty in this fault block. Most likely pressure is 10.0 ppg II. Hydrates and Shallow gas: A. Free gas and/or gas hydrates may be present in the SV and Ugnu intervals while drilling the 121/4" hole below the Permafrost base. Use standard operating procedures for hydrates, if encountered. III. Running Gravels: A. Unconsolidated sand, gravel, & cobbles and thawing permafrost could impede well angle build and casing running through permafrost. Keep moderate to low build angles until out of permafrost section. Keep flow rates low. Hazards include wood and cobbles, running gravels, lost circulation, and tight hole problems while drilling and running casing. IV. Faults Lost circulation at fault crossing possible in the Surface section and Production section. Follow normal monitor and mitigation procedures for losses while drilling. Forma:ion V'Iiere Encoun:er Faul: MD Intersect TVCss Imersec: Es:.Thro.:: Thro'.:Cirec:ion Uncerainr Fa,tt:1 -Highiano State Fautt S..- 2,C2E.0 1.- 1== ,e_. 1E0 ' Fault#2-Z Pad Faut1Or6f Base E.=C`.0 - ..e_. 1: ''G V. Kick Tolerance/ Integrity Testing: A. The 13%" casing will be cemented to surface using a port collar at 500' if necessary. The 9 5/e" intermediate liner will be fully cemented. The 7" production casing will be cemented to 1000' above the Ma but will keep sufficient standoff from below the 9 %" liner shoe. I Kick Tolerance/ Integrity Testing Summary Table Casing and Casing Maximum Influx Mud Exp Pore LOT/ Interval Test Volume Weight Press FIT Pressure • 13'/a" Surface 3500 psi 25 BBLS (assuming 9.5 9.3 LOT Casing 11.2 LOT) 9%" Intermediate 3500 psi 25 BBLS (assuming 10.2 10.0 LOT Liner _ 12.1 LOT) 7" Production 3500 psi NA NA NA NA Casing VI. Lost Circulation / Breathing: A. Lost circulation potential when crossing the Highland Fault and Z-Pad Fault. There are three fault crossings planned throughout the entire well. No faults are expected in the reservoir interval. Follow LCM decision tree; reduce mud weight slightly. B. Coleville breathing is possible. Follow"Wellbore Breathing" mitigation plan. Z-115 Permit Application Page 8 VII. Broaching A. Monitor adjacent wells for broaching while drilling surface hole. IX. Hydrogen Sulfide A. This site should be treated as an H2S site with all the required precautions. (6) H2S Data Well flame 112S Level Reaclinci Cate Comments Parent Well(if sidetrack) =1 Closest SHL Well H2S Level Z-11° e v Well.tic data :et T2 Closest SHL S-+yell H2S Level Z-`F 1C 23;2C12 :1 Closest BHL Well H2S Level Z-1CC 1120,2C12 =2 Closest BHL Well H2S Level -122 30 1.22i2C12 t3 Closest BHL Well H2S Level Z-11'_ ew Well,No data yet ed Closest BHL Well H2S Level v-11` 20 212.43;2012 Max.Recorded H2S on Pad•Facility Z-1CC 12C 27'2010 Other Relevant H2S Data (H2S alarms'rom rigs,etc.) CONSULT THE Z PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Z-115 Permit Application Page 9 SDS �r ti�: (j r,'‘ :1,...` 1 ` v-PAD` %ti. "-) ". : \ j IV- 50 \I., f,N cRlo is. ��) t .- ` o -'SPINE RD 0\..! 9 ■ ■ 33P/77.•. r t 2 8 ■ ■ 32 ti J 7 ■ ■ 31 1 1 0. W AD-- 6 D"6 ■ ! 30 A\\ 11, , A I 115 : ■ 29 • Z-PAO ` 4AM \ 108 : ■• 2210u �� t ■ 102iJ j� " L 3 ■ ■ 27 THIS PROJECT tt)) 77 ■ 1161 2 ■ ■ 1041 \" I.. l.,J h 111114i cri II 1031 f 5 1 ■ ■ SPARE-A ■ P-504A r, ) ® E ■ P-5046 r tt .,s1 ®® C 1l - VICINITY MAP p NTS ! 21 • 22 39 ■ 11 IN ■ 23 111 ■ 24 12 13 111 ■ 25 14 ■ ■ 26 ■ SLOT t ��q{i{1A1j{1' 15 ■ ■ SLOT 2 � ` OF . ■ z-100 „` �'`G,.......44 A 17 ■ i 1007 4 _ ,`P.••' `'•.'r'f,�91/ C7 ■ _. ' SURVEYOR'S CERTIFICATZ n. 18 • 3111 ' ,* S I HEREBY CERTIFY THAT I AM 46 ■ S PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN w 19 ! Z-PAD i► THE STATE OF ALASKA AND THAT 20 IS , ,,,,,,,,,,,,, THIS AS-BUILT REPRESENTS A SURVEY ,,,,,,°„°°„ • MADE BY ME OR UNDER MY DIRECT I 50 = 811 P °ichard F. Allison THAT ALL •".. DIMENSIONS SUPERVISIONANDDOTHER DETAILS ARE 8 �2 r6�8 ,.,yam'= CORRECT AS OF JULY 02, 2011. il SD 65 70 281 ,,It `ES$i CNA•-* ` 215i 113_ 113 ',',IW{WV4%%`` I40 6961 El SL 2131 II I n _ LEGEND 283 - 2aNI • AS-BUILT CONDUCTOR B8 42 111 EXISTING WELL CONDUCTOR NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, HAD 27. `� i 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAO MONUMENTATION. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L) DATUM. 5. GEODETIC DATUM IS NAD27. 6. PAD AVERAGE SCALE FACTOR IS 0.999911213. 7. DATES OF SURVEY: JUNE 28-30, JULY 1-2, 2011. 8. REFERENCE FIELD BOOKS: NS11-44 PGS. 1-75; NS11-46 PGS. 1-9. AS-BUILT WELL CONDUCTORS• 1 ..T 34i, 40. 42, 50, 511, 55. 57, 61, 62. 65, 66, 68, 69, 70, 105, 113, 115, 201, 202, 203. 2111, 2121, 2131, 2141, 215i, 2161, 2171, 218i, S0, SG, SL, NK Robert DRA'-"E BARNHART Awn bp hn W1E 7/1/11 pRAWilf4 3 �p FR811 woe 21 WOA Z-PAD SHEET 171SSICi - WRD PAD EXPANSION MI 7/1/1103940 FOR DA0UA11o11 TMD JJ '•WNW L�° 1 AS-BUILT WELL CONDUCTORS 1 OF 3 .VIIIIWMW. DATE PE-JIS!)vc Br Cloc Norma NINr. mo LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) BOX ELEV. OFFSETS Y= 5,959,100.13 N= 1,179.09 70'17'51.597" 70.2976658' 4,292' FSL 341 X= 600,125.84 E= 1,870.12 149'11'20.998" 149.1891661' 56.1' 2,552' FEL Y= 5,959,100.17 N= 1324.00 70'17'51.616" 70.2976711' 4,294' FSL 40 X= 599,980.94 E= 1870.16 149'11'25.221" 149.1903392' 56.0' 2,697' FEL Y=5,959,239.95 N= 1,126.45 70'17'52.965" 70.2980458' 4,431' FSL 42 X= 600,178.47 E= 2,009.96 149'11'19.409" 149.1887247' 56'0' 2,497' FEL Y= 5,959,100.19 N= 1,473.93 70'17'51.636" 70.2976767' 4,296' FSL 50 X= 599,831.02 E= 1,870.18 149'11'29.591" 149.1915531' 56.2' 2,847' FEL Y=5,959,240.04 N= 1,466.46 70'17'53.011" 70.2980586' 4,435' FSL 51i X= 599,838.49 E= 2,010.05 149'11'29.319" 149.1914775' 55'9 2,837' FEL Y= 5,959,100.12 N= 1,458.95 70'17'51.634" 70.2976761' 4,295' FSL 55 X= 599,846.00 E= 1,870.11 149'11'29.155" 149.1914319' 56.1' 2,832' FEL Y=5,959,240.04 N= 1,421.49 70'17'53.005" 70.2980569' 4,435' FSL 57 X= 599,883.46 E= 2,010.05 149'11'28.009" 149.1911136' 55.9' 2,792' FEL Y=5,959,239.97 N= 1,376.44 70'17'52.998" 70.2980550' 4,434' FSL 61 X= 599,928.50 E= 2,009.98 I 149'11'26.695" 149.1907486' 55.9' 12,747' FEL Y=5,959,239.94 N= 1,436.45 70'17'53.006" 70.2980572' 4,435' FSL 62 X= 599,868.50 E= 2,009.95 149'11'28.445" 149.1912347' 56.0' 2,807' FEL Y= 5,959,100.15 (N= 1,398.94 70'17'51.626" 70.2976739' 4,295' FSL 65 X= 599,906.01 j E= 1,870.14 149'11'27.405" 149.1909458' 56.1' 2,772' FEL Y= 5,959,100.11 N= 1,443.99 70'17'51.632" 70.2976756° 4,295' FSL 66 X= 599,860.96 E= 1,870.11 149'11'28.719"� 149.1913108' 56.2' 2.817' FEL Y=5,959,100.23 N= 1,134.00 1 70'17'51.592"I 70.2976644' 4,291' FSL 68 X= 600,170.92 E= 1,870.22 149'11'19.683"t 149.1888008' 55.9' 2.507' FEL Y=5,959,239.94 N= 1,301.49 M 70'17'52.988" 70.2980522' 4,433' FSL 69 X= 600,003.45 E= 2,009.95 149'11'24.511" 149.1901419' 56.1' 2,672' FEL Y= 5,959,100.10 N= 1,384.02 70'17'51.624" 70.2976733' 4,294' FSL 70 X= 599,920.93 E= 1,870.09 149'11'26.971" 149.1908253' 56.2' 2,757' FEL Y=5,959,100.05 N= 1,163.88 70'17'51.594" 70.2976650' 4,291' FSL 105 X= 600,141.04 E= 1,870.04 149'11'20.554" 149.1890428' 55'9 2,537' FEL Y=5,959,239.90 N= 1,346.45 70'17'52.994" 70.2980539' 4,434' FSL 113 X= 599,958.49 , E= 2,009.91 149'11'25.821" 149.1905058' 56.0' 2,717' FEL Y=5,959,240.03 , N= 1,361.38 70'17'52.997" 70.2980547' 4,434' FSL / 115 X= 599.943.56 E= 2,010.04 149'11'26.256" 149.1906267' I 55'9 2,732' FEL NOTES: 1. ALASKA STATE PLANE COORDINATES ARE NAD27, ZONE 4. 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAD MONUMENTATION. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 5. PAD AVERAGE SCALE FACTOR IS 0.999911213. AS—BUILT WEI L CONDUCTORS. 34i, 40. 42, 50. 51i, 55. 57. 61. 62, 65, 66, 68. 69, 70, 105, 113, 115, 201. 202, 203, 2111, 212i, 213i, 214i, 215i, 216i, 217i, 218i, SD, SG, SL, NK UPAvn+ F. Robert BARNHART hn j, JACOBS OA tC t 7f1/11 F� OP.AWING: +�assoc. FR811 WOZ 21 WOA Z PAD rF �3 assoc. �. r WRD PAD EXPANSION Re 7/1/11 ISSUED IR INFORMATION 1F9 J E I ev+S+nN ..3,ran=we r 200 AS—BUILT WELL CONDUCTORS2 3 R 1 H 6Mn LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 12 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC GRAVEL SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) PAD ELEV. OFFSETS Y=5,959,240.18 N= 1,171.46 70'17'52.973" 70.2980481' 4,432' FSL 201 X= 600,133.47 E= 2,010.19 14911'20.721" 149.1890892' 56.6' 2,542' FEL Y=5,959,239.94 N= 1,451.46 70'17'53.008" 70.2980578' 4,435' FSL 202 X= 599,853.49 E= 2,009.95 149'11'28.882" 149.1913561' 55'9 _2,822' FEL Y=5,959,100.03 N= 1,148.96 1 70'17'51.592" 70.2976644' 4,291' FSL 203 X= 600,155.96 E= 1,870.02 149'11'20.119" 149.1889219' 56.0' 2,522' FEL Y=5,959,100.23 N= 1,308.95 70'17'51.615" 70.2976708' 4,293' FSL 211 X= 599,995.99 E= 1,870.22 149'11'24.783" 149.1902175' 55'9 2,682' FEL Y= 5,959,240.11 N= 1,141.47 70'17'52.969" 70.2980469' 4,431' FSL 212i X= 600,163.45 E= 2,010.12 149'11'19.847" 149.1888464' 56.4' 2,512' FEL Y=5,959,240.04 N= 1,271.44 70'17'52.985" 70.2980514' ` 4,433' FSL 213i X= 600,033.50 E= 2,010.05 14911'23.635" 149.1898986' 56.1' 2,642' FEL Y=5,959,100.25 N= 1,293.88 70'17'51.613" 70.2976703' 4,293' FSL 214i X= 600,011,06 E= 1,870.24 149'11'24.343" 149.1900953' ; 56.2' 2,667' FEL Y=5,959,100.14 N= 1,354.05 70'17'51.620" 70.2976722' 4,294' FSL 2151 X= 599,950.89 E= 1,870.13 149'11'26.097" 149.1905825° 56.2' 2,727' FEL Y=5,959,240.09 N= 1,316.42 7017'52.992" 70.2980533' 1 4,433' FSL 216i X= 599,988.52 E= 2,010.10 149'11'24.946" 149.1902628' 56'0' 2,687' FEL Y=5,959,239.98 N= 1,156.36 70'17'52.970" 70.2980472' 4,431' FSL 217i X= 600,148.56 E= 2,009.99 1 149'11'20.281" 149.1889669' I 56.2' 2,527' FEL Y=5,959,239.98 N= 1,391.46 70'17'53.000" 70.2980556' 4,434' FSL 2181 X= 599,913.48 E= 2,009.99 149'11'27.133" 149.1908703' 55.9' 2,762' FEL Y= 5,959,100.11 N= 1,429.03 7017'51.630" 70.2976750' 4,295' FSL SD X= 599,875.92 E= 1,870.10 149'11'28.283" 149.1911897' 56.4' 2,802' FEL Y=5,959,100.09 N= 1,369.02 70'17'51.621" 70.2976725' 34,294' FSL SG X= 599,935.92 E= 1,870.08 149'11'26.533" 149.1907036' 562'' 2,742' FEL Y= 5,959,100.01 N= 1,279.00 . 70'17'51.609" 70.2976692' 4,293' FSL SL X= 600,025.94 E= 1,870.00 ; 149'11'23.910" 149.1899750' ' 56.3' 2,652' FEL Y=5,959,239.85 N= 1,286.54 70'17'52.985" 70.2980514' 4,433' FSL NK X= 600,018.40 E= 2,009.86 I 149'11'24.075" 149.1900208' 1 56'0' 2,657' FEL NOTES: 1. ALASKA STATE PLANE COORDINATES ARE NAD27, ZONE 4. 2. HORIZONTAL CONTROL IS BASED ON Z PAD CONTROL MONUMENTS MON 2 AND MON 3. 3. VERTICAL CONTROL IS BASED ON Z PAO MONUMENTATION. 4. ELEVATIONS ARE BPX MEAN SEA LEVEL (M.S.L.) DATUM. 5. PAD AVERAGE SCALE FACTOR IS 0.999911213. 6. ALPHA NAME DESIGNATIONS REFER TO BPX DRILLING SURFACE SLOT NAME AS—BUILT WELL CONDUCTORS. 34i, 40, 42. 50, 51i, 55, 57, 61, 62, 65. 66, 68, 69, 70, 105, 113. 115, 201, 202, 203, 2111. 212i, 213i, 214i, 215i, 216i, 217i, 218i, SD, SG, SL, NK F Robert °RA`"' --- BARNHART 1 Q� o bp JACOBS I 1 I OA rt 7/1/11 assoc. DRAWING MUT �4�{ FRB" WOZ 21_-- woa Z-PAD ,Od NO C. .._-- WRD PAD EXPANSION ad 7i,/1 i issued FoR Ir CRU 1F8 Al ocs;' 1 Z00. AS—BUILT WELL CONDUCTORS 3 OF 3 No! DA Tr r=FVISion a- CH. .,ne,.L 4aA ,,,.i TREE 4-1116' 131.t WEAD= FMC �Z 1 1 5 SAFETY NOTES: CHROMETBG' ACTUATOR= Electric KB.aEV= i c.pos BF.R.EV= - i71 KOP= 300 Max Angle= 94 @ 9635' 20'CONDUCTOR 80' • TBD 13-3/8'TAM PORT COLLAR Datum MD= Datum TVD= 2000' H4-112'HES X NP,ID=3.813" • M • 2783' —13-3/B'X 9-518"BKR ZXPN 1.1 V/hKiR 13-3/8"CSG,68# � ,L-80 BTC,ID=12.415' H 2933' ills- r ! • • ' • 9-5/8'LNR,40#,L-80 BTC,ID=8.835' H 6303' GAS LFT MANDR .S • ST MD 7VD Del/ TYPE VLV LATCH FORT [ATE 6 3787 2800 61 KBG IJMY RK 1' 5 6643 4200 61 KBG OCX RK 1" Minimum ID =3.725"@ 10,879' i l 4 8836 5200 62 KBG (*Rt' R( 1" 41/2"XN Nipple 1 ! 3 10042 5800 49 KBG OMI' RK 1" 14 2 10568 6200 28 KBG INV RK 1' M a 1 10621 6150 27 KBG IAAY RK 1' I I * I 10698' —4-1/2'NES X NP,D=3.813- 14-1/2'NDPG SINGLE-SENSOR SUB,ID _ H 10736' I,. S Z.--I 10766' 1--7"X 4-1 f2'HES TNT PKR D=3.870' /. ; I • 10803' —4-1/2'HES X NP,13=3-813'` 10879' H4-112'HESXNNP,13=3.725" 14-1/2"TBG,12.6#,13-Cr,VT,.0152 bpf,D=3.958' 19f390' I — - H 10892' MEG PERFORATION S&AMN1RY • REF LOG: MOON 1+ ANGLE AT TOP PERF: Nob:Refer to Production 06 for hisbrical perf data SIZE SPF INTERVAL Opn/Sqz LATE S M' • S 7"PBTD ani r 11231' 4/%0;4/�V�4►;41;4);41 7'CSG,26#,L-80,VT HC,.0383 bpf,ID=6.278' 11311' 40 stet �11 *�.�.t4/�.�� [ATE REV BY COWIENTS [ATE REV BY OOMVB{TS AURORA UNIT 03115/12 FVR OIIGUNAL DRAW(dr P18) WE-L:Z-115 PE IAT Ib: API Nu: 50-029-)000CX-00-00 SECJOGINPXXN RGDOCE FSL X))0('FEL XX)OC BP Exploration(Alaska) '''' :,---' '''''' ) • \17\ml ' 2g4I 10 Ul 1 N.N i F .- 1 •: 1 1,4S ik < ,..).. t -. E CL -- ....... _...., l 7-- — x00, -'...l.t. ..... N ,11 1 ' ...... 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AO O O O O ;21 2 ^ 01 el 00.a 0] U O Y (8)002l:I. =aieoS CIA . by 0 Schlumberger NELL Z-115 (P18b) FIELD STRUCTURE Prudhoe Bay Unit-WOA Z-PAD Magnetic Parameters Surface Location NAD27 Alaska State Plane,Zone 04.US Feet M'ocelMseous Model BGGM2011 Dip: 80.980' Date: July 15.2012 Lab N 70 17 52.997 NoMn, 5959240.035US Grid Con,.0.76199752' Slot: 2.115 MGI TVD Ref' Rotary TeNe(90.2ft above MSL) Mag Doc. 20.884° FS'. 57042.0n1 Lan: W149 11 26.257 Easting'. 599943.568115 Scale Fact:0.99991135 Plan 2.115 Blab) 5,Date:March 29,2012 -2000 -1000 0 1000 2000 3000 4000 8000 8000 Z-110(P18b) iik\> Z-115 Seo polygon 7"Csg Tr . Z-115 B5%drl poly Cry 4.25/100 End Cry End Cry 7000 z-+15Tgt 9. 7000 6000 4 4 Fsun.:.... .. ,~ 6000 Cry 4.25/100 End 8ry Z-115 Tgtj Z-115 Fault#2 5000 Cot MOOr 5000 A A A Z 0 0 0 4000 4000 i d To cr) \/ 9-5/6-C • iV V V 3000 3000 2000 4 4 + a 2000 13-318"Cs ' P 1000 1000 End Cry Fault 1 • Z-115 Fault#1 Cry 2.9/100 RTE Bld 2/100 0 0 KOP Bld 1/100 -2000 -1000 0 1000 2000 3000 4000 «< W Scale=1:1000(ft) E >>> co _ zr - u>a(.0 cocom Ju)N CO-OD aYNk N c c c _o IF-CO C"" - d 0.0-0-0_ 0 -- o _o _ r N M - O _ N M 0 O N o _o M tV C -O C1 CO 0 O —O CO 0 fn f6 N 1) O H 0 h M ` —O 7 - r - - O — _- g _ N - 0 —o M _- g —0 C r � � � � � � � � � ITl � � � � � � � H , � � � � � � � � � � � � � ll II � - 0 0 Un 0 U) 0 Un 0 (un p1.) uogeiedes awwue°of aijuao Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Kup Z-115(NG)v6 Project: Prudhoe Bay ND Reference: Z-115 plan new @ 90.20ft(Doyon 14) Reference Site: PB Z Pad MD Reference: Z-115 plan new @ 90.20ft(Doyon 14) Site Error: 0.00ft North Reference: True Reference Well: Plan Kup Z-115(NG)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-115 wo/PH Database: EDM .16-ANC Prod-WH24P Reference Design: Plan#18 Z-115 Offset ND Reference: Offset Datum Reference Plan#18 Z-115 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of relen Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,327.69ft Error Surface: Elliptical Conic Survey Tool Program Date 3/12/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 34.30 1,300.00 Plan#18 Z-115(Plan Z-115 wo/PH) GYD-GC-SS Gyrodata gyro single shots 1,300.00 2,933.00 Plan#18 Z-115(Plan Z-115 wo/PH) MWD MWD-Standard 1,300.00 2,933.00 Plan#18 Z-115(Plan Z-115 wo/PH) MWD+IFR+MS MWD+IFR+Multi Station 2,933.00 5,303.00 Plan#18 Z-115(Plan Z-115 wo/PH) MWD MWD-Standard 2,933.00 5,030.00 Plan#18 Z-115(Plan Z-115 wo/PH) MWD+IFR+MS MWD+IFR+Multi Station 5,030.00 6,800.00 Plan#18 Z-115(Plan Z-115 wo/PH) MWD MWD-Standard 5,303.00 11,311.25 Plan#18 Z-115(Plan Z-115 wo/PH) MWD+IFR+MS MWD+IFR+Multi Station 3/12/2012 3:34:06PM Page 2 of 4 COMPASS 2003.16 Build 73 Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Kup Z-115(NG)v6 Project: Prudhoe Bay ND Reference: Z-115 plan new @ 90.20ft(Doyon 14) Reference Site: PB Z Pad MD Reference: Z-115 plan new @ 90.20ft(Doyon 14) Site Error: 0.00ft North Reference: True Reference Well: Plan Kup Z-115(NG)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-115 wo/PH Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#18 Z-115 Offset ND Reference: Offset Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB Z Pad Plan Ivi Z-34(SM)v6-Plan Z-34-Plan#10b Z-3z 447.22 450.00 230.74 8.41 222.33 Pass-Major Risk Plan Ivi Z-42(NP)v6-Plan Z-42-Plan#5 Z-42 vE 408.62 400.00 235.75 7.75 228.00 Pass-Major Risk Plan Ivi Z-51 (NA)v6-Plan Ivi Z-Z51-Plan#2 Z-t 506.66 500.00 111.59 8.56 103.09 Pass-Major Risk Plan lvi Z-55(SB)v6-Plan Z-55-Plan#4 Z-55 vE 423.49 425.00 171.94 8.06 163.88 Pass-Major Risk Plan lvi Z-57(ND)v6-Plan Z-57-Plan#4 Z-57 vt 556.80 550.00 61.62 10.43 51.19 Pass-Major Risk Plan lvi Z-61 (NF)v6-Plan Z-61-Plan#4 Z-61 vE 507.49 500.00 16.28 9.61 6.67 Pass-Major Risk Plan lvi Z-62(NC)v6-Plan Z-62-Plan#2 Z-6214 506.29 500.00 77.25 8.60 68.65 Pass-Major Risk Plan Ivi Z-66(SC)v6-Plan Z-66-Plan#14 Z-661 348.40 350.00 162.40 6.66 155.74 Pass-Major Risk Plan lvi Z-69(NJ)v6-Plan Z-69-Plan#3 Z-69 v6 732.69 725.00 59.20 13.17 46.03 Pass-Major Risk Plan lvi Z-70(SF)v6-Plan Z-70-Plan#17 Z-70 348.50 350.00 142.27 6.66 135.61 Pass-Major Risk Plan Kup Z-105(SN)v6-Plan Z-105-Plan#4 Z-' 504.13 500.00 243.57 9.35 234.22 Pass-Major Risk Plan Kup Z-105(SN)v6-Plan Z-105PB1 -Plan# 504.13 500.00 243.57 9.56 234.01 Pass-Major Risk Plan Kup Z-114(27+45)v6-Plan Z-114-Plan#1 11,045.59 12,500.00 750.36 253.34 499.48 Pass-Major Risk Plan Kup Z-118(30.5)v5-Plan Z-118 v5-Plan#: 3,053.80 3,525.00 448.10 78.25 396.52 Pass-Major Risk Plan Sch Z-201 (NM)v6-Plan Z-201 -Plan#6 Z-: 884.56 875.00 186.24 15.42 170.82 Pass-Major Risk Plan Sch Z-202(NB)v6-Plan Z-202-Plan#2 Z 307.66 300.00 90.78 5.92 84.87 Pass-Major Risk Plan Sch Z-211 (SJ)v6-Plan Z-211-Plan#5 Z-2 429.82 425.00 150.81 8.17 142.64 Pass-Major Risk Plan Sch Z-212(NO)v6-Plan Z-212-Plan#3 Z-2 433.77 425.00 220.68 8.16 212.51 Pass-Major Risk Plan Sch Z-213(NL)v6-Plan Z-213-Plan#3 Z 433.13 425.00 90.83 8.22 82.61 Pass-Major Risk Plan Sch Z-214(SK)v6-Plan Z-214-Plan#2 Z-2 527.18 525.00 157.14 9.71 147.44 Pass-Major Risk Plan Sch Z-215(SH)v6-Plan Z-215-Plan#2 Z-2 812.74 825.00 136.28 14.36 121.99 Pass-Major Risk Plan Sch Z-216(NI)v6-Plan Z-216-Plan#2 Z-2 457.95 450.00 46.12 8.68 37.44 Pass-Major Risk Plan Sch Z-217(NN)v6-Plan Z-217-Plan#3 Z 1,048.59 1,025.00 211.94 18.79 193.23 Pass-Major Risk Plan Sch Z-218(NE)v6-Plan Z-218-Plan#2 Z-2 507.40 500.00 31.33 9.40 21.93 Pass-Major Risk Z-113-Z-113Z-113-Z-113-Z-113 574.83 575.00 13.12 9.52 3.61 Pass-Major Risk Z-113-Z-113PB1 -Z-113PB1 574.83 575.00 13.12 9.52 3.61 Pass-Major Risk Z-116-delete me Plan Z-116PB2 do not use-del 2,934.77 3,025.00 115.23 91.95 45.14 Pass-Major Risk Z-116-Z-116-Plan#24 Z-116 2,935.13 3,025.00 115.09 91.85 45.16 Pass-Major Risk Z-116-Z-116-Z-116 2,935.13 3,025.00 115.09 91.85 45.16 Pass-Major Risk Z-116-Z-116PB1 -Z-116PB1 2,935.13 3,025.00 115.09 91.86 45.15 Pass-Major Risk Z-116-Z-116PB2-Z-116PB2 2,935.13 3,025.00 115.09 91.86 45.15 Pass-Major Risk Z-19-Z-19-Z-19 1,104.20 1,150.00 223.02 29.26 194.06 Pass-Major Risk Z-19-Z-19A-Z-19A 1,108.21 1,150.00 223.13 29.37 194.07 Pass-Major Risk Z-20-Z-20-Z-20 395.95 400.00 209.26 7.23 202.04 Pass-Major Risk Z-210-Z-210-Z-210 2,221.80 2,525.00 97.20 59.66 55.59 Pass-Major Risk Z-210-Z-210PB1-Z-210PB1 2,221.80 2,525.00 97.20 59.66 55.59 Pass-Major Risk Z-40-Z-40-Plan#16 Z-40 299.89 300.00 146.26 5.53 140.73 Pass-Major Risk Z-40-Z-40-Z-40 299.89 300.00 146.26 5.69 140.57 Pass-Major Risk Z-50-Z-50-Plan#8 Z-50 v6 396.98 400.00 180.27 7.57 172.70 Pass-Major Risk Z-65-Z-65-Z-65 349.61 350.00 144.60 6.00 138.60 Pass-Major Risk Z-65-Z-65PB1-Plan#13 Z-65 approved 397.33 400.00 145.68 7.58 138.10 Pass-Major Risk Z-65-Z-65PB1-Z-65PB1 349.61 350.00 144.60 6.00 138.60 Pass-Major Risk 3/12/2012 3:34:06PM Page 3 of 4 COMPASS 2003.16 Build 73 Project: Prudhoe Bay Site: PB Z Pad Well: Plan Kup Z-115 (NG)v6 Wellbore: Plan Z-115 wo/PH Design: Plan #18 Z-115 From Colour To MD 34 500 500 — 1000 From surface to TD 1000 1500 Scan interval 25 ft Scale 1 : 50 1500 2000 All wells pass major risk 2000 3000 0 3000 5000 77 5000 8000 ir�_ 8000 11312 330 �� 30 ' Allilh fr,*AI 0 IPA i I'4.1 iv. 1p ivikir.4,-.1.-,..,..--.--4,,,„.1,---...41,„.,7441,4,4,..,-;_willt4, A AO afATA,AvAy4e.v4#11111 ��,oprit 1�1 � 11 ‘toplliiii 4 Illisitillivglv4 ,� )1w -116/Z-116PB2!-1162-1 300 vv I *40 II' Plan Sch Z-216(NI)v .41,044..1%.41111111 411111 14 e".41kb \ \ ‘40to A ,4„,i4 „..,,,,,,, Pia',SCh[.-202(tv......,..-.. '�•N � ' `'�`.�.`�_�` +!♦�'''_:��r4�� ,\:p. �'._7.....--:IL,.. T13 77.5„.„....\,...,........... 1y i Plan Sch 7-2 9 t .,R ri. ,. tkr ' 4 I ;. l — ` ;: 90 _y i ) , e ,11,1f,;:.„ ) : *,. ; i L gym,•_ jt \\ ti' 2�' i' / �� ' 19`49 ! . .< 1P4an#4 Z.5t r \ t}, Y°i / 1873 r 1 )v6IP+�ir a2 7 v,'� • t t �+WrI " r y ,t tt, / 194' / VOir i' (11 y y'I ly / 1 18 1 pl ... „,, S• f. �.r�� `I 4, 4 .. ,t,„„,,...,.,,,,,.. ,.'� _ 112F, 204' f , \ --/ 'i opp 1 140 20.6 ` s µ ri 220, .� I �` 97 % 1t�„am00a4��-' 20 111 IOW % 1221 �� 240 /ig \iw'- ,,, �` .1,41.1 12RS Z-113/2-113PB1 ' gp 103' .� ,tj { /v.e =d ;.*Plan Sch Z-214(SK)v6/Plan#2 Z-214 v6 • ..ham �.. '.'Ian Sch Z-215(SH)v6/Plan#2 Z-215 v6 g�/.,� .:4",,,,-„,,f, 210 Ivi ,.- .4 :-s @v,� ,toi , 14 r - 10/Z-210P81 ts;,..;'q'': '1�— : Plan SM 7-211 SJ)v6/Plan#5 2-211 v65 -rt w,#1o $Z,-i65 aper. .:' -40/2-40#16 Z-40 row,rvi�-,vtoi )vt'.. 180 Travelling Cylinder Azimuth (TFO+AZI)[°]vs Centre to Centre Separation[50 ft/in] OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME 9Za //c l PTD# ` Z -� Development Service Exploratory Stratigraphic Test Non- nventional Well / /--e_ AS FIELD: YC 2L�-� i' POOL: ` ' L/I ( Check Box for Appropriate Let er/Paragraphs to be Included in Transmit/ l Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE 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 ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 F I CO co 0) O a) O- N co N 0 0) Oco c @ co 0 c. 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