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Post Office Box 244027 Anchorage, AK 99524-4027 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Phone: (907) 564-4891 06/01/2023 Mr. Mel Rixse Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Prudhoe Bay Surface Casing by Conductor Annulus Top-offs of Cement, Corrosion Inhibitor through 6/1/2023. Dear Mr. Rixse, Enclosed please find a copy of a spreadsheet with a list of Prudhoe Bay wells that were topped-off with cement, corrosion inhibitor in the surface casing by conductor annulus through 6/1/2023. Cement top-offs are executed as needed to mitigate the void space left at surface by minor cement fallback during the primary surface casing by conductor cement job. The remaining void space between the top of the cement and the top of the conductor is filled with a heavier than water corrosion inhibitor to reduce the risk of external surface casing corrosion. The attached spreadsheets include the well names, API and PTD numbers, treatment dates and volumes. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404 Report of Sundry Operations. If you have any additional questions, please contact me at 564-4891 or oliver.sternicki@hilcorp.com. Sincerely, Oliver Sternicki Well Integrity Supervisor Hilcorp North Slope, LLC Hilcorp North Slope LLC.Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor Top-offReport of Sundry Operations (10-404)06/01/2023Well NamePTD #API #Initial top of cement (ft)Vol. of cement pumped (gal)Final top of cement (ft)Cement top off date Corrosion inhibitor (gal)Corrosion inhibitor/ sealant dateL-2072210815002923702003.371.31/23/2023123/1/2023L-2312230105002923746003.003.0-393/27/2023M-111810575002920589002.602.6-105/29/2023M-311920325002922256001.501.5-165/29/2023M-331941165002922504001.301.3-145/29/2023N-171830095002920898001.201.2-115/30/2023N-18A2081755002920906010.500.5-65/30/2023N-21A1961965002921342011.001.0-85/30/2023N-272071045002923365000.500.5-45/30/2023N-292141105002923521002.302.3-245/30/2023N-31215175500292356000-0--205/30/2023V-2342220045002923707006.3210.91/23/2023243/1/2023W-2412221545002923741002.502.5-263/1/2023Z-121891025002921977000.700.7-45/23/2023Z-34212061500292346900-0--155/27/2023Z-402111735002923462000.700.7-65/27/2023Z-46A2052035002923280010.500.5-35/23/2023Z-502120015002923463000.500.5-35/27/2023Z-662121955002923482000.700.7-85/27/2023Z-116211124500292345500-0--175/27/2023Z-210204181500292322600-0--125/27/2023Z-2292221045002923726003.8361.23/5/2023363/27/20230.700.7-5/27/2023Z-662121955002923482008 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by directinspection of the file. al a - I Well History File Identifier Organizing (done) Two-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: Color Items: ❑ Maps: Grayscale Items: gs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 1415". /s/ 6/1 e Project Proofing BY: Ai= Date: 1 /3)15' isl Scanning Preparation x 30 = q 0 + a3 = TOTAL PAGES IP (Count does not include cover sheet) BY: at Date: ` 13 f /s/ Production Scanning Stage 1 Page Count from Scanned File: ) I I+ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Date: 1// 3) i 5- /s/ r14 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 10 NO TOTAL PAGES: 2� Digital version appended by: Meredith Michal ME Date: 0) t /!s— isi Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: 13 7 Scanning is complete at this point unless rescanning is required. 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V+ I Q 0 Q ccO I— a) • a) Q o a Z E ►- Q d 0 1_ E fa z m ao 3 c �1 w 11 0 0 c N 3 N I d j a) coco • cn I•l V ✓ r Cto U d I E E a E E 0 o i o 2.St 3Q, WELL LOG TRANSMITTAL DATA LOGGED VZiq/2o1y K BENDER To: Alaska Oil and Gas Conservation Comm. November 26, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 r RE: Production Profile: Z-66 Run Date: 1/30/2014 A 014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 Z-66 Digital Log file, Interpretation Report 1 CD Rom 50-029-23482-00 Production Profile (Field Print) 1 Color Log 50-029-23482-00 Production Profile Report (Interpretation Report) 1 Report 50-029-23482-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: • Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS ANC@halliburton.corn Date: Signed: (4tiza-ftek-il) 6-41446t 2_.V2-4) WELL LOG 114STRANSMITTAL PROACTIVE DINSERVICES, INC. DATA LOGGED Aq� 3iy /2014 M K BENDER To: AOGCC Makana Bender RECEIVED 333 W. 7th Ave Suite 100 Anchorage,Alaska 99501 MAR 0 4 2014 [907) 793-1225 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Sarah Gunkel LR2 - 1 900 Benson Blvd. Anchorage,AK 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage,AK 99518 Fax: (907) 245-8952 1) Production Profile-MAPS 31-Jan-14 Z-66 BL/ CO 50-029-23482-00 2) Signed : Date : -S/44/,4‘ Print Name: -Z31 'b . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEOMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Archives\MasterTemplateFtles\Templates\Distnbunon\Transm ttalSheets\BP_Transmit docx 2\2-- kc) 5 DATAOGGED 2:6°1.•�ViM2013 .M K BENDER Schiumberger RECEIVED Drilling & Measurements AUG 1 5 2013 MWD/LWD Log Product Delivery AOGCC Customer BP Exploration Alaska Inc Dispatched To: Makana Bender Well No Z-66 Date Dispatched: 14-Aug-13 Installation/Rig DOYON 25 Dispatched By: STEPHANIE PACILLO Data Survey No Of Prints No of CDs Z-66 Log 1 1 2 in MD 1 2 in TVD 1 5 in MD 1 5inTVD 1 Received By: Please sign and return one copyto: Drilling&Measurements 2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax 907-561-8317 TRANSMITTAL#:6401 DA `A LOGGED - ! /1,0/2013 M K BENDER 2?620 Schiumberger RECEIVED AUG 15 Drilling & Measurements MWD/LWD Log Product Delivery AA OGCC Customer BP Exploration Alaska Inc Dispatched To: Makana Bender Well No Z-66 PB1 Date Dispatched: 14-Aug-13 Installation/Rig DOYON 25 Dispatched By: STEPHANIE PACILLO Data Survey No Of Prints No of CDs Z-66 PB1 Log 1 1 2 in MD 1 2 In TVD 1 5inMD 1 5 In TVD 1 Received By: rn Please sign and return one copyto: Drilling&Measurements 2525 Gambell Street,Suite 400 Anchorage,Alaska 99503 hecheto@slb.com Hector Echeto Fax 907-561-8317 TRANSMITTAL#:6401 U_n, a- N OGrnrnrn O i U4 4OO4W iNpd OrNa d0MNEr7 NW2 NmpWh OWWr 7W22 0 en 0 MhM NNNN0)On Eigp VNQ.O ENN NOn NNNM OWNN Nt. 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(0 g4" u W g m Y C o (O 323-2 ; f 8 0 E 29.1_- O(� o `.t a 41:0 .38° . n o 0 g ; i ItEE3,1 5 y 5 • i f� 12 6y > >0 0 0 0 5 L O H r C U IL N i m`N N f U J J U U' I U O: 2 0 N. \ 0 2 |` § ra tR 2f !!! ! 2§2 2 JNN £ f �\\ Co §\2 Ael s � t6 § k® �E000 . t§\ A { E ;asks r �® /// )E U` ! q @2 2 . „ dm Ec 2- oor \\ m () . |£ i; a') ) { \ | ! I • Q0) / 1 . �,.. . Drilling&Measurements ',i 2525 Gambell Street.Suite 400 0 212 Anchorage AK 99503 Schlumberger Tel(907)273-1700 Fax(907)561-8317 Date: May 23,2013 Well Name: Z-66 Company: BP Exploration(Alaska),Inc. API Number: 50-029-23482-00-00 AFE Number: X3-011MR-C:DRILL Location: X=599,860.96US Feet;Y=5,959,100.11US Feet Field: Prudhoe Bay Rig: Doyon 25 Drilling and Measurements Field Support: Operations Manager, Ankur Prakash Field Service Manager, Hector Echeto Drilling and Measurements Field Crew: Cell Managers, Carlos Ilizaliturri Elena Greblova Cell Engineer, Mahmoud Farrag Eric Pennington SERVICES PROVIDED Z-66 Services Services Dates Depth Intervals Directional Survey Service 26-Feb-13 to 15-Mar-13 313 feet to 13386 feet TeleScope*Direction&Inclination 26-Feb-13 to 09-Mar-13 313 feet to 9863 feet VISION*(Resistivity,Gamma Ray) 26-Feb-13 to 09-Mar-13 313 feet to 9863 feet IMPulse*Direction&Inclination 11-Mar-13 to 20-Mar-13 9863 feet to 13386 feet VISION*(Neutron,Density Azimuthal) 05-Mar-13 to 20-Mar-13 3611 feet to 13386 feet OPERATING STATISTICS Total MWD Pumping Time: 271.4 hours Total LWD Pumping Time: 271.4 hours Total MWD Time Below Rotary: 402 hours Total LWD Time Below Rotary: 402 hours Total MWD Depth Interval: 13073 feet Total LWD Depth Interval: 13073feet Total MWD Runs: 5 Total LWD Runs: STotal JOB PERFORMANCE Directional Z-66 The final MWD survey point was located at 13332.03 feet with an inclination of 82.85 degrees and an azimuth of 126.68 degrees. This direction and inclination was projected from the final survey point to TD, which resulted in the following bottom-hole location. Measured Depth: 13386 feet True Vertical Depth: 8988.13 feet 1 I A. Formation Evaluation Schlumberger 12-1/4 inch Surface Section: The 12.25"surface hole section of the well was drilled from 313 feet to 3611 feet MD in two runs.On the first run the well was drilled from 313 feet to 2076 feet MD.The BHA was pulled out to change the motor bend.On second run a side track was drilled from 1260 feet after hole was lost. A motor was used for directional control during the runs.Resistivity and Gamma Ray data were supplied in real-time and from memory once the tools were retrieved. The final measured bottom-hole temperature was 71.6 degrees Fahrenheit. 8-3/4 inch Intermediate Section: The intermediate hole section of the well was drilled from 3611 feet to 9863 feet MD in one run. A motor was used for directional control during the run. Resistivity, Gamma Ray, Azimuthal Density,Neutron and APWD data were supplied in real-time and from memory once the tools were retrieved. The final measured bottom-hole temperature was 98.6 degrees Fahrenheit. 6-1/8 inch Production Section The production lateral section of the well was drilled from 9863 feet to 13386 feet MD in two runs. A motor was used for directional control during the runs.. Directional Resistivity, Gamma Ray, Azimuthal Density, and Neutron data were supplied in real-time and from memory once the tools were retrieved. The final measured bottom-hole temperature was 193.6 degrees Fahrenheit. Innovation Implementing compressed ORION data points in our Real-Time frames when high tier formation evaluation services are requested or high ROPs are anticipated is recommended. ORION data compression techniques will provide excellent data density for all evaluation needs allowing more data channels to be sent uphole and greater log detail to catch fine geological features. Schlumberger Oilfield Services — Drilling & Measurements appreciates the opportunity to provide BP Exploration(Alaska)with MWD and LWD services. Sincerely, Elena Greblova MWD/LWD Engineer Schlumberger Drilling&Measurements 2 In 8 Q o e0ppmWM� 0ypOm' pOOWp^0ee22.: WnnNWQ86g m2-"N G . ONsO M;g7ppOpO22. e.. Omm 1940 ppothOo . 0g,0 WWW 00W0W WWWWW WW00W smm 0tho OOgm O!Oj0Ol W OlNA W W ttttt W tt010 tt010)Ol T4AAA ttttt W tt0) QVeee QQ4a4 444aa aaaaa 4444a 44444 eaeoe 4444 0. a aR WOR N Q p mn n W0 N n N O Ny O mmmm Ni 3 WanrWtt-U3ErMF,..MFEMMg, wmO OOOO ( P NNNNN 84888 NNNNN 88888 NNNNN 88888 NNNNN 8888 O O G O O C O G C G G CCC O O O G C G 0 0 0 0 0 C C C O O O OCG C C G C G N u5 •`,/J\ LC mOp V 2 m 8°26;82 8°26;82 p,2 8 21 8 g 4.1.-38V2 W 8 V 2 8m88R2,7. 8V8;37; 12'42178 N 0 12'42178 p 0 0::n Olp W0WWiA,OOO 0:4MgiLA,FH 1 NN rWO w mmmm ..Wmmmmmomm ..mmmm ...ammo ..mmmm pmmmm mmmm 1 NNNNN ,7NMM MNMM NNNNNN NNNNN 22888oo08 NNNN (1. 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O D O +8'78 O m > 0 3 i Z i Z U 0 0 Q 2= 0 0= Np8p888 0E oim'ainrenev dN C$N r A� U1 m W L N_N 2 00 �!1 O N N d N N 0 N'N to y�csiNNrr r L ] y ^"aC aC tG eC d tG O 7 S d L 222222222 000000000 C O E IL X 3 N C O X p 69w h fX 0C ',Erg � r J ! f giUN(O(ppm O(O§ Et O O`-'ON W 0)�DON OO Opo > LL OI�N NOGG. O N' 0 O N N N r O N O D M.-0)0)00 0 0 0) 0— .-000000 j 0 2 O)NA AO LL J 0 •r.,(2 U N0( C d r ^yo2 • z m g � a 1 C o ; N o E w V Ern 0 o O Ettc 0 00 RECEIVED A STATE OF ALASKA APR 2 2 2013 , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO6°GCC la. Well Status: . ®Oil 0 Gas 0 SPLUG 0 Other ❑Abandoned 0 Suspended 1 b. Well Class 20AAC 25 105 2OAAC 25 110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions One• .®Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. - 3/25/2013 • 212-195 • 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 2/26/2013 • 50-029-23482-00-00 • 4a. Location of Well(Governmental Section): 7.Date T.D. Reached: 14. Well Name and Number: Surface: 3/18/2013 •qig i Ai>(f'Z•f (4 PBU Z-66 ' 4295'FSL,2817' FEL, Sec. 19,T11 N, R12E, UM• 8. KB(ft above MSL): ,..pertri, 15.Field/Pool(s) Top of Productive Horizon: 3222' FSL,2190' FEL, Sec.24,T11 N, R11 E, UM GL(ft above MSL). 56.2' . Prudhoe Bay/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) 764' FSL, 1143' FEL, Sec. 24,T11 N, R11 E, UM 13260' • 8973' • 4b Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16 Property Designation: r Surface: x- 599861 • y- 5959100 - Zone- ASP4 13386' • 8988' • ADL 028262&028245 TPI: x- 595548 y- 5957971 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 596627 y- 5955527 Zone- ASP4 None 18. Directional Surve : 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): Y ®Yes 0 No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1806' 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/GR/RES, MWD/GR/RES/NEU/DEN, MWD/GR/RES/NEU/DEN N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 40' 108' 40' 108' , 42" 260 sx Arctic Set(Approx.) 9-5/8" 40# L-80 40' 3601' 40' 3127' _ 12-1/4" 2189 sx LiteCrete,422 sx Class'G' 7" 26# L-80 38' 9859' 38' 8595' _ 8-3/4" 528 sx Lite Crete,202 sx Class'G' 4-1/2" 12.6# 13Cr80 9682' 13384' 8433' 8988' 6-1/8" Uncemented Slotted Liner,Swell Packers 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/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2"Sliding Sleeves w/Swell Packers 4-1/2", 12.6#, 13Cr85 9688' 9565'/8326' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. • 10126' 8809' 13100' 8954' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No • 10326' 8904' 10646' 8943' COMPLETION i DEPTH INTERVAL(MD AMOUNT AND KIND OF MATERIAL USED 11112' 8936' 11295' 8933' i BlafQ 2375' Freeze Protect w/74 Bbls Diesel 11607' 8942' VW) I 11832' 8942' 12394' 8936' 12697' 8930' 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 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No• Sidewall Core(s)Acquired? 0 Yes IS 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 APR 2 5 2013) IT Form 10-407 Revised 10/2012 CONTINUED ON REVERSE Submit Original Only i(Ir i)�/ , 4( qt7(/, c z ,/ 6 29. GEOLOGIC MARKERS(List all formations and m- ' -.rs encounter 30. FORMATION TESTS NAMETVDTVD Well Tested? L s ®No _ Permafrost Top 40' 40' If yes,list intervals and formations tested,briefly summarizing test Permafrost Base 1922' 1846' results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ungu 3649' 3163' None Schrader Bluff N 5405' 4553' Schrader Bluff 0 5603' 4732' Base of Schrader Bluff 5994' 5085' HRZ 7530' 6489' Kalubik 7576' 6531' Kuparuk C 7640' 6590' LCU/Kuparuk B 7690' 6635' Kuparuk A 7717' 6659' Miluveach 7771' 6708' Kingak 8497' 7355' Sag River 9861' 8597' Shublik 9891' 8625' Eileen 10021' 8735' Ivishak/Zone 4 10071' 8772' Ivishak/Zone 3 13300' 8977' Formation at Total Depth: Ivishak/Zone 3 • 13300' 8977' 31.List of Attachment: Summary of Daily Drilling Reports,Well Schematic Diagram,Surveys 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Zach Browning;564-4664 Email: Zachary.Browning@bp.com Title: Drilling Technologist Printed Name: •- .-stufk Signature: j - Phone 564-4091 Date: At'/I Gfi5 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 ND 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 10/2012 Submit Original Only -7F11 E ` 4-1116' CNV WELLFEAD= FMD ACTUATOR= 6 6 SAFE /TES_ WELL ANGLE>70°@ 10313 *** ELECTRIC CHROME TBG&LNR*** NTFAL KB.ELEV= 96.01' / NT1 ' AL.BF.ELEV= 56.2 KOP= 300' Max Angle= 96°@ 10660' , 1995' 14-1/2'HES X NP,ID=3.813" Datum M:),= 10301 20"CONDUCTOR,94#,H-40,D=19.124" H '-108GAS LIFT MANDRELS 9-5/8'CSG,40#,L-80 BTC,D=8.835" 3601' ST MD TVD DEV TYPE VLV LATCH PORT DATE 7 3839 3308 38 KBG DCK BEK - 03/22/13 6 5442 4587 26 KBG DMY BK 0 03/22/13 5 6388 5445 24 KBG DMY BK 0 03/22/13 4 7085 6082 24 KBG DMY BK 0 03/22/13 Minimum ID = 3.813" @ 1995' 3 7782 6718 26 KBG DMY BK 0 03/22/13 4-1/2" HES X NIPPLE 2 8810 7633 26 KBG DMY BK 0 03/22/13 1 9466 8234 23 KBG DMY BK 0 03/22/13 I 9602' H4-1/2'HES X NP,13=3.813' 9531' -14-1/2"SGM NDPG SINGLE DROP SAPPHIRE GAUGE,D=3.864" 11 9565' _17"X 4-1/2"HES TNT PKR 13=3.856" 9600' H 4-1Q"HES X NP,ID=3.813" 111 • 9676' -4-1/2"HES X NP,D=3.813' 9682' -17'X 5"BKR HRD-E ZX PN LIP,D=4.32' 4-1/2'TBG, 12.6#,13CR-85 VAM TOP, -{ 9687' CI 9688' -14-1/2"WLEG,D=4.00 .0152 bpf,ID-3.958" --I\ ELM)TT NOT LOGGED \ 9703' -17'X 5'BKR FLEX-LOCK HGR D=4.36" 7"CSG,26#,L-80 VAM TOP HC, .0383 bpf, -H 9859' • 9712' H5'X 4-1/2'XO BUSHING,D=3.870' ID=6.276(BTM 2 JOINTS=L-80 BTC) •• HES OBM SWELL PACKBtS in No I HES XXD SLD SLV,ID=3.813" ' NO SIZE TOP DE'TH MND .7.1 .7. NO DEPTH OIC DATE 7 4-1/2" 10038 3958" _ 10 10126 C 03/21/13 6 4-1/2" 10261 3.958" �-� 9 10326 C 03/21/13 5 4-1/2' 10420 3.958" .-.1111..:. 8 10646 C 03/21/13 4 4-1/2" 10861 3.958" AMA 7 11112 C 03/21/13 3 4-1/2" 11467 3.958" 6 11295 C 03/21/13 2 4-1/2' 12124 3.958' IIIII 5 11607 C 03/21/13 1 4-1/2' 12910 3.958" mumau 4 11832 C 03/21/13 MIMI 3 12394 C 03121/13 _, 2 12697 C 03/21/13 II 1 13100 C 03/21/13 PBTD:4-1/2"BKR ISOLATION VALVE,D=1.250' 13260' m No• O=OPEN C=CLOSED .-- 13238' H4-1/2"BKR SHFT TOOL V ERFICATION SUB,D=3.920' 4-1/2"LNR, 12.6#.13CR-80 HYD 521. H 13263' amm• .0152 bpf,ID=3.958' 13260' H4-1/2"BKR ISOLATION VALVE,D=1.250' 3-1/2"LNR 9.2#,13CR-85 VAM TOP, ---I 13362' 13263'1H4-1/2"X 3-1/2"XO,ID=2.960" .0087 bpf,D=2992' 13274' -3-1/2'HES OBM SWELL PKR,D=2.992' 4-112'LNR, 12.6#,L-80 BT,.0152 bpf,ID=3.958" - 13384' 13362' H3-1/2'X 4-1/2'XO,D=2.992" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/25/13 D-14 INT1AL COMPLETION WELL: Z-66 03/28/13 PJC DRLG HO CORRECTONS PERMIT No:'2121950 03/31/13 RP/PJC ADD ACTUATOR API No: 50-029-23482-00 04/08/13 ZI-B/PJC FINAL APROVAL ODE SEC. 19,T11N,R12E,985'FN.&2137'FWL 04/15/13 JNUJMD PBTD CORRECTION BP Exploration(Alaska) BP AMERICA LOT / FIT Summary Well Name: Z-66 Surface Leak Off Test Test Test Depth Test Depth AMW Pressure Pressure EMW Date Type (TMD-Ft) (TVD-Ft) (ppg) (psi) (BHP) (psi) (ppg) 03/05/13 FIT 3,601.00 3,126.00 9.00 860.00 2,321.51 14.30 03/12/13 FIT 8,883.00 7,699.49 8.80 1,650.00 5,169.77 12.93 Page 1 of 1 North America-ALASKA-BP Page 1 of 22 Operation Summary Report Common Well Name Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code , NPT NPT Depth Phase Description of Operations (hr) (usft) 2/20/2013 18:00 - 00:00 6.00 MOB P PRE PREPARE TO ROMO Z-61 TO WELL Z-68, 2/21/2013 19:30 - 00:00 4.50 MOB P PRE POSITION SUB ON MATS -UNHOOK SOW AND CATS -REMOVE JEEP FROM SUB CRAB SUB OVER WELL AND SPOT -POSITION MATS FOR PIPE SHED -MOVE PIPE SHED F/Z-61 TO Z-66 AND SET. 00:00 - 06:00 6.00 MOB P RUNCMP WALK POWER,PUMP,AND PUMP COMPLEXES OUT -LOWER CATTLE SHUTE AND HATCH INTO PIPE SHED -PREP AND SKID FLOOR 06:00 - 08:00 2.00 MOB P RUNCMP LOWER DERRICK 08:00 - 12:00 4.00 MOB P RUNCMP UNPIN PIPESHED AND WALK 20',LATCH TO TRUCK AND REPOSITION W/SAME 12:00 - 16:30 4.50 MOB P RUNCMP INSTALL JEEP ON SUB AND MOVE SUB F/Z-61 TO Z-66.UNABLE TO PULL SUB ONTO MATS. 16:30 - 19:30 3.00 MOB N WAIT -0.90 PRE WAIT ON PEAK CAT.R/U TWO CATS TO PULL SUB ONTO MATS. 2/22/2013 00:00 - 07:30 7.50 MOB P PRE CONTINUE TO MOVE IN AND SPOT REMANING MODULES ON Z-66 07:30 - 10:00 2.50 MOB. P PRE RAISE DERRICK AND SKID FLOOR 10:00 - 12:00 2.00 MOB P PRE WALK PITS,PUMP,AND PIPE SHED MODULES INTO PLACE 12:00 - 18:00 6.00 MOB P PRE MOVE MOTOR MODULE INTO PLACE-RAISE CATTLE SHUTE-TEST ESD ON GENERATORS 18:00 - 21:00 3.00 MOB P PRE MAKE UP INTERCONNECTS -RU ALL STAIRWAYS,LANDINGS,POWER CABLES,STEAM ETC 21:00 - 00:00 ' 3.00 MOB N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAWWORKS CONTROLS 2/23/2013 00:00 - 02:00 I 2.00 MOB N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAVWVORKS CONTROLS. 102:00 - 15:00 13.00 RIGU P PRE NU RISER AND BOPE. 15:00 - 00:00 9.00 RIGU N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAWWWORKS CONTROLS. -HELD Z-66 PRE-SPUD MTG WITH CREW 2/24/2013 00:00 - 01:00 1.00 RIGU P PRE HELD Z-66 PRE-SPUD MTG WITH CREW 01:00 - 02:30 1.50 RIGU N RREP -0.90 PRE GENERAL HOUSEKEEPING. 02:30 - 03:00 0.50 RIGU P PRE HOLD RIG EVACUATION DRILL -CONDUCT AAR W/CREW 03:00 - 00:00 21.00 RIGU N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAWINORKS CONTROLS. -SIMOPS: -CLEAN TANK ROOM -REPLUMB JET LINES -COMPLETE PM'S -INSPECT MUD PUMPS -REPLACE HYDRAULIC GEAR BOX ON JIB CRANE Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 2 of 22 Operation Summary Report `' `n ' Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 1 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PBZ Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To 1 Hrs 1 Task Code 1 NPT NPT Depth I Phase 1 Description of Operations (hr) I (usft) - 2/25/2013 00:00 - 10:00 10.00 1 RIGU N RREP -0.90 PRE I UNABLE TO SCOPE UP DERRICK.CONTINUE TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAWWORKS CONTROLS '-ENERGIZE KOOMEY UNIT -CHECK FOR LEAKS,VERIFY KNIFE VALVE OPERATION -TEST GAS ALARMS GENERAL HOUSEKEEPING AND MAINTENANCE 10:00 - 12:00 2.00 RIGU N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK.CONTINUE TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAWWORKS CONTROLS -PERFORM ACCUMULATOR DRAWDOWN TEST,BEFORE 3,050'PSI/AFTER 2,150 PSI 10 SEC FOR 200 PSI BUILD W/2 ELEC PUMP, 46 SEC FOR FULL PRESSURE BUILD WITH 2 ELEC AND 2 AIR PUMPS. FUNCTION TESTANNULAR(ANN CLOSE=35 'SEC,KNIFE VALVE OPEN=13 SEC) -WITNESS WAIVED BYAOGCC REP JEFF JONES. 12:00 - 17:00 5.00 RIGU N RREP -0.90 PRE UNABLE TO SCOPE UP DERRICK.CONTINUE TROUBLESHOOT ELECTRICAL PROBLEM ON AMPHION DRAVWVORKS CONTROLS 1-CONT GENERAL HOUSEKEEPING AND RIG MANITENANCE 17:00 - 00:00 7.00 RIGU P PRE ;RIG ACCEPTED @ 20:30 HR$ -DRAWWORKS OPERATIONAL,BRIDAL UP AND SCOPE UP DERRICK RU KELLY HOSE AND PLUG IN DERRICK LIGHTS CUT/SLIP 105'DRLG LINE,RECALIBRATE BLOCK HEIGHT 2/26/2013 00:00 - 01:00 1.00 RIGU P PRE PJSM,C/O PS-21 SLIP INSERTS 01:00 - 04:30 3.50 RIGU P PRE I PU/MU AND STAND BACK 5 STDS 4"HWDP,5" i JAR STD IN DERRICK 04:30 - 06:30 2.00 RIGU P PRE PU/MU MUD MOTOR,12 1/4' BIT AND ORIENT UBHO W/MOTOR -FILL STACK VERIFY "NO LEAKS". 08:30 - 07:30 1.00 RIGU P PRE RIG UP GYRO DATA 07:30 - 08:00 0.50 RIGU P PRE TEST MUD LINES 3,500 PSI,OK -VERIFY OPERATION OF CUTTINGS TANK DRAIN LINE AND JETS. 08:00 - 09:00 1.00 DRILL P SURF I RIH W/BIT TAG @ 110'MD, DRILL 12 1/4"SURFACE HOLE F/110'TO 127' SMD 1-8.6 PPG DRIL-PLEX MUD -450 GPM,300 PSI, -40 RPM,1-5 KTQ 09:00 - 11:00 2.00 DRILL N DPRB 127.00 SURF -RUN GYRO,TOOL STUCK IN UBHO,DISCUSS OPTIONS,PULL TOOL FREE -POOH W/GYRO TOOL,C/O STINGER AND CENTRALIZER RIH W/GYRO,NEW STINGER,NEW CENTRALIZER.NO PROBLEM Printed 4/8/2013 11:07:06AM Pa a 30 22 . o Fh tnenca ati<A-BP Page Operation Summary Report Common Wet Name.2-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code . NPT j NPT Depth Phase Description of Operations (hr) i I (usft) 11:00 - 12:00 1.00 DRILL P SURF DRILL 12 1/4"SURFACE HOLE F 127'TO 200' MD -450 GPM,400 PSI,ON/350 PSI OFF -8.6 PPG MUD WT -40 RPM,1-2 K TQ -5K WOB -P/U 44K,S/0 53K,ROT 45K -ART=1.52,ADT=1.52,TOT BIT HRS=1.52 12:00 - 18:00 6.00 DRILL P SURF DRILL 12 1/4"SURFACE HOLE F/200'TO 313' MD(312'TVD) 450 GPM,450 PSI ON/375 PSI OFF -8.6 PPG MUD WT I-40 RPM,1-2 KTQ -5/8KWOB -P/U 45K,S/0 45K,ROT 45K -AST=2.12,TOT BIT HRS=3.64 DRILLING WITH DOUBLES FROM PIPE SHED. 18:00 - 19:00 1.00 DRILL P SURF POOH WITH BHA#1.STD BACK 4"HWDP,LD XO AND UBHO -MONITOR DISP VIA TT 19:00 - 22:00 3.00 DRILL P SURF MU BHA#2 AS PER SLB DD,ORIENT UBHO, — — RIH W/BHA#2 22:00 - 00:00 2.00 DRILL SURF DRILL 12 1/4"SURFACE HOLE F/ 313'MD TO 376'MD(375'TVD) -500 GPM,840 PSI ON/770 PSI OFF 8.6 PPG MUD WT -40 RPM,2-3 KTQ ON BTM, 1K TQ OFF BTM -10K WOB -P/U 56K,S/O 77K,ROT 60K -AS=.32,ART=.55 ,ADT=.87,TOT BIT HRS =4.51 -TOT JAR HRS=.87 MWD INDICATING CLEAN SURVEYS FROM 307'MD. PLAN IS TO KEEP GYRODATA RIGGED UP UNTIL PAST POSSIBLE AREA OF MAGNETIC INTERFERENCE FROM 900'MD TO +1400'MD. 2/27/2013 00:00 - 13:00 13.00 DRILL P SURF DRILL 12 1/4"SURFACE HOLE F/376'MD TO 1260'MD(1244'TVD) -550 GPM, 1390 PSI ON/1240 PSI OFF -8.9PPG MUD WT -40 RPM,7 KTQ ON/2K TQ OFF -32K WOB -P/U 45K,S/O 45K,ROT 45K -AST=3.8,ART=2.41,ADT=6.21,TOT BIT FIRS=10.72 JAR HRS=6.9 GYRO SURVEYS EVERY 63'. DRILLING WITH DOUBLES FROM PIPE SHED CURRENTLY OBTAINING CLEAN MWD 1 'SURVEYS. GYRODATA REMAINS RIGGED UP AND READY TO RUN IN ANTICIPATION OF POSSIBLE AREA OF INCREASED MAGNETIC INTERFERENCE FROM-900'MD.TO+1400' II MD. WHEN PAST+1400'MD.,PLAN IS TO OBTAIN AS YET UNDETERMINED NUMBER OF CLEAN MWD SURVEYS AND THEN RELEASE 1 GYRODATA SERVICES. Printed 4/8/2013 11:07:06AM • North America-ALASKA-BP Page 4 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Tme:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UVN: Active datum:Z-66 actual©96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:00 - 00:00 11.00 DRILL P SURF DRILL 12 1/4"SURFACE HOLE F/1127'MD TO 1,260'MD(1244'TVD) -550 GPM, 1640 PSI ON/1440 PSI OFF -8.9PPG MUD WT -40 RPM,6 K TQ ON/2K TQ OFF -32K WOB l i -P/U 92K,S/0 92K,ROT 90K -AST=2.93,ART=2.69,ADT=5.62,TOT BIT HRS=16.32 -JAR HRS=13.1 GYRO SURVEYS EVERY 63'. DRILLING WITH DOUBLES FROM PIPE SHED CURRENTLY OBTAINING CLEAN MWD SURVEYS. GYRODATA REMAINS RIGGED UP AND READY TO RUN IN ANTICIPATION OF POSSIBLE AREA OF INCREASED MAGNETIC INTERFERENCE FROM-900'MD.TO+1400' MD. WHEN PAST+1400'MD.PLAN IS TO OBTAIN AS YET UNDETERMINED NUMBER OF CLEAN MWD SURVEYS, -RIG DOWN AND RELEASE GYRODATA • SERVICES la 16:30 HRS,1380'MD AFTER OBTAINING VERIFIABLE CLEAN SURVEY 2/28/2013 00:00 - 03:00 3.00 DRILL P SURF "DRILL 121/4"SURFACE HOLE F/ 1840'MD TO 2076 MD(1977'TVD) -550 GPM, 1640 PSI ON /1440 PSI OFF -8.9PPG MUD WT -40 RPM,6 KTQON/2KTQOFF -32KWOB-P/U92K, S/0 92K,ROT 90K -AST=0.57 ,ART=0.69, ADT=1.26 ,TOT BIT HRS=17.58-JAR HRS= 14.36 03:00 - 04:00 1.00 DRILL P SURF CIRCULATE BOTTOMS UP -ROTATE AND RECIPROCATE PIPE DURING 1ST BTMS UP - HOLD MOTOR TO HIGH SIDE -RECIPROCATE PIPE FOR REMANING 2X BTMS UP. 04:00 - 06:00 2.00 DRILL P ; SURF POOH ON ELEVATORS F/2076'MD TO 900'MD -FLOW CHECK WELL 06:00 - 11:30 5.50 DRILL P SURF RACK BACK BHA#2-RACK BACK 4"HWDP AND 5"HWDP JARS AND COLLARS -LD UBHO -PU NEW VM-3 HUGHES INSERT BIT- ADJUST MOTOR BEND TO 1.5' BIT GRADE:02-04-WT-A-E-3/8-SS-BHA 11:30 - 12:30 1.00 DRILL P SURF SERVICE AND INSPECT TOP DRIVE 12:30 - 13:30 1.00 DRILL P SURF RIH W/BHA#3 TO 840'ON ELEVATORS 13:30 - 14:00 0.50 DRILL P SURF PERFORM MWD SHALLOW HOLE TEST-500 GPM,990 PSI(GOOD DETECTION) 14:00 - 17:00 3.00 DRILL P SURF RIH TO TIGHT SPOT AT 1,260'MD -UNABLE TO MOVE DOWN WITHOUT PUMPS AND ROTATION -NOTIFY 04040DE,WTL, SUPERINTEDENT AND DISCUSS PLAN FORWARD 17:00 - 19:00 2.00 DRILL N DPRB 1,408.00 SURF ORIENT TOOL FACE PER TOWN DISCUSSION AND BEGIN SIDE TRACK NEW 12-1/4"HOLE FROM 1,260'MD TO 1,408'MD,1,385'TVD - 550 GPM,1,475 PSI ON/1,310 PSI OFF- 10-30K WOB-P/U 82K,S/0 82K ROT 90K-AST =0.57 ,ART=0.69,ADT=1.26 ,TOT BIT HRS =17.58 Printed 4/8/2013 11:07:06AM • • North America-ALASKA-BP Page 5 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 20:30 1.50 DRILL N DPRB 1,126.00 SURF POOH ON ELEVATORS FROM 1,408'MD TO 1,126'MD-WIPED THROUGH AREA AT 2160' 2X,NO OVER PULL OR SLACK OFF SEEN -TIGHT SPOT AT 1,160'MD(15K OVERPULL)- WORKED THROUGH TIGHT SPOT,WIPED 1X- RIH TO BOTTOM AT 1,408' MD,NO PROBLEMS SEEN AT 2160'MD ON RIH- OBTAIN SURVEY AT 1408' 20:30 - 00:00 3.50 DRILL N DPRB 1,696.00 SURF OBTAIN SURVEY AT 1408-CONT DRILL SIDE TRACK 12 1/4"HOLE F/ 1,408'MD TO 1,696' MD(1,651'TVD)-550 GPM,1530 PSI ON/1400 PSI OFF-9.2 PPG MUD WT-40 RPM,4K-5K TO ON/2.5K TQ OFF-23K WOB-P/U 90K, S/O 89K,ROT 89K-AST=2.75 ,ART=0.54, 1 ADT=3.29 ,TOT BIT HRS=3.29-JAR HRS= 18.0 3/1/2013 00:00 - 05:00 5.00 DRILL N DPRB 2,076.00 SURF DRILL 12-1/4"SURFACE HOLE F/ 1696'MD TO f 2,076'MD(1,968'ND) -550 GPM, 2740 PSI ON/2540 PSI OFF -9.2 PPG MUD WT -40 RPM,5K TO ON/3K TQ OFF - 20/30K WOB -P/U 88K,S/O 90K,ROT 89K AST=2.33 ,ART= 2.50,ADT=4.83,TOT BIT HRS=8.12 -JAR HRS=23.2 _ ✓ 05:00 - 12:00 7.00 DRILL P SURF DRILL 12-1/4"SURFACE HOLE F/2,076'MD TO 2,713 MD (2,457 TVD) -700 GPM, 2740 PSI ON/2540 PSI OFF -9.2PPG MUD WT -40 RPM,6K TQ ON/2K TQ OFF - 32K WOB -P/U 92K,S/O 92K,ROT 90K -AST=0.57 ,ART=0.69,ADT=1.26 ,TOT BIT HRS=17.58 -JAR HRS=14.36 ENCOUNTERED HYDRATES AT 2,643'MD -CARRIED EXCESS CUTTINGS TO SURFACE -FLOWLINE BEGIN TO PACKOFF -CLEAR FLOW LINE -GAS CUT=8.3 PPG ON MUD BALANCE (UNPRESSURIZED) 12:00 - 23:00 11.00 DRILL P SURF DRILL 12-1/4"SURFACE HOLE F/2,713'MD TO 3,611'MD (3,134 ND) -750 GPM, 2740 PSI ON/2540 PSI OFF -9.3 PPG MUD WT -80 RPM,6K TO ON/5K TQ OFF - 20K WOB -P/U 117K,S/0 99K,ROT 105K -AST=0..42 ,ART=3.66,ADT=1..08,TOT BIT HRS=12.2 -JAR HRS=27.28 ENCOUNTERED HYDRATES AT 3,440'MD -CIRCULATED OUT WITH NO GAS CUT, OBSERVED EXCESS CUTTINGS 23:00 - 00:00 1.00 DRILL P SURF CBU 3X W/RECIPROCATION AND ROTATION F/3,611'MD T/3,526'MD -750 GPM,3100 PSI -80 RPM,4K-5K TO Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 6 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay t Site:PB Z Pad Rig Name/No.:DOYON 25 1 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:Z-66 actual©96.10usft(above Mean Sea Level) Date From-To Hrs I Task 1 Code I NPT NPT Depth ' Phase j Description of Operations (hr) (usft) 3/2/2013 00:00 - 00:30 0.50 DRILL P SURF CONT TO 3X CBU W/RECIPROCATION AND ROTATION F/3,611'MD T/3,526'MD -750 GPM,3100 PSI -80 RPM,4K-5K TQ 00:30 - 01:00 0.50 DRILL P I i SURF FLOW CHECK WELL(STATIC) 01:00 - 03:00 2.00 DRILL P SURF POOH ON ELEVATORS F/3,611'MD T/1,220' .MD -PULLED 40'ABOVE SIDETRACK DEPTH- - NO TIGHT SPOTS OBSERVED 03:00 - 04:00 1.00 DRILL P SURF RIH ON ELEVATORS F/1,220'MD T/3,611'MD -NO TROUBLE SPOTS ENCOUNTERED. 04:00 - 05:30 1.50 DRILL P SURF CBU WHILE ROTATING AND RECIPROCATING F/3,611'MD T/3,526'MD -750 GPM,3100 PSI -80 RPM,4K TQ 05:30 - 06:00 0.50 DRILL P SURF MONITOR WELL(STATIC) 06:00 - 08:30 I 2.50 DRILL P SURF POOH ON ELEVATORS F/3,594'MD T/283 08:30 - 10:30 ' 2.00 DRILL P SURF L/D BHA BHA#3 PER SLB DD 10:30 - 11:30 1.00 DRILL P SURF LD STAB,XO'S,BIT AND CLEAR AND CLEAN RIG FLOOR, 11:30 - 15:00 3.50 CASING P SURF RU TO RUN 9 5/8"CASING,C/O BAILS,PU BAIL EXTENSIONS, -PU FLUTED HGR AND PERFORM DUMMY RUN AND MARK,LD SAME. 15:00 - 22:00 7.00 CASING P SURF HELD AAR AND PJSM ON 9 5/8"CASING RUN AND VOLANT TOOL OPERATION -RUN 9 5/8"40#L-80 SURFACE CASING -MU SHOE TRACK AND CHECK FLOAT EQUIPMENT,OK -RUN CASING TO 2138'(53 JTS RAN)FILL PIPE EVERY JT, -BREAK CIRC AND WASH DOWN EVERY 10TH JT STAGING FROM 3 TO 5 BPM. I-C/O JT#27 AND COLLAR ON JT#26 DUE TO GALLED THREAD.NO CHANGE TO PIPE TALLY LENGTH. 22:00 - 22:30 0.50 CASING P SURF SERVICE PS-21 SLIPS, -CIRC AT 2 BPM 22:30 - 00:00 1.50 CASING I N I RREP ' 2,138.00 SURF PS-21 SLIPS NOT FUNCTIONING, BROKE FITTING,REMOVE FROM ROTARY TABLE TO REPAIR. -CIRCULATE AT 2 BPM,AND RECIPROCATE PIPE SLOWLY W/10'STROKE 3/3/2013 00:00 - 01:30 1.50 CEMT N RREP SURF CHANGE OUT SLIPS 01:30 - 05:30 4.00 CASING P SURF CONT RIH W/9-5/8",40#,L-80,BTC,CASING F/ 2135'MD TO 3560 MD.FILL PIPE EVERY 5 JTS, CIRC EVERY 10 JTS. MU HANGER -WASH DOWN AND LAND ON DEPTH©3601' MD 05:30 - 08:30 3.00 CASING P I SURF CIRC/COND MUD WHILE RECIPROCATE PIPE F/3601'MD TO 3585'MD, -STAGE PUMPS UP TO 7 BPM,200 PSI Printed 4/8/2013 11:07:06AM • 41) # � � . North America-ALASKA-BP s � Page ,-' Pas e7o' f 22 ' Aa rz . # �. " l• �z4> re '',f,,'•,‘.:', A1,.> � � � ,'"w.. FYV�3 0 � e���e - v, ,, Operation Summary Report , Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) I (— Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) i 08:30 - 14:30 1 6.00 CASING P SURF RU CEMENT LINE AND PJSM CEMENT 9-5/8"SURFACE CASING AS -_ FOLLOWS: -PJSM FOR 9-5/8"CEMENTING WITH II I SCHLUMBERGER AND CH2MHILL I-LINE UP TO SCHLUMBERGER CEMENTERS. I I . -PUMP 05-BBLS OF WATER,TEST LINES TO 300/3500 PSI,OK. -PUMP 100 BBLS OF 10.0-PPG MUDPUSH II. I- DROP BOTTOM PLUG �-PUMP 737-BBLS(2189 SX)11.0-PPG LEAD CITECRETE CEMENT.YIELD 1.89 CUFT/SK PUMP 87-BBLS(422 SX)15.8-PPG CLASS"G" II TAIL CEMENT.YIELD 1.16 CUFT/SK I-DROP TOP PLUG.KICK OUT PLUG WITH 10-BBLS OF WATER. -SWITCH OVER TO RIG PUMPS FOR DISPLACEMENT -DISPLACE WITH 9.4 PPG DRILPLEX MUD II-PUMP AT 8 BPM,WITH 420 PSI -SIDEWALK CEMENT BACK TO SURFACE @ I 11400 STKS DISPLACED SIDEWALK CEMENT BACK TO SURFACE 112 BBLS -TOTAL CEMENT BACK TO SURFACE 125 BBLS SHUT DOWN DUE TO JOES BOX AND FLOWLINE PLUGGED BY CUTTINGS AND ' I CONTAMINATED MUD JET AND CLEAR SAME -STAGE PUMPS UP TO 6 BPM,640 PSI PUMP MAX ALLOWABLE STKS 2582(DISP+ 1/2 SHOE TRACK), DID NOT BUMP PLUG I -SHUT DOWN,BLEED PRESSURE,_CHECK I I FLOATS,OK _ I -CIP @ 14:30 HRS i 14:30 - 00:00 9.50DIVRTR 1 P SURF RIG DOWN 9 5/8"CASING RUNNING TOOLS& DIVERTER SYSTEM DRAIN&RINSE STACK,WASH ALL SURFACE EQUIPMENT EXCESSIVE CEMENT IN FLOWLINE AND DRIP PAN TO CLEAN OUT I-RIG DOWN CEMENT HEAD,CEMENT LINES, 1350-TON ELEVATORS. CLEAR FLOOR OF CASING EQUIP. -PULL LANDING JOINT RINSE JOE'S BOX AND PULL OUT OF OPERATING POSITION. -PULL LOW PRESSURE RISER. FUNCTION,RINSE,AND NIPPLE DOWN 21-1/4"ANNULAR DIVERTER PULL SURFACE RISER&SEND OUT THE BEAVER SLIDE. 1-R/D DIVERTER LINE AND KNIFE VALVE. -CLEAN MUD PITS,TROUGH AND FLOW LINE. GAVE AOGCC 24 HOUR NOTIFICATION OF . I UPCOMING BOP TEST AT 16:30 HRS 3/4/2013 I 00:00 - 09:00 9.00 BOPSUR P SURF NU BOPE -:-NU CASING HEAD,,TUBING SPOOL,HIGH PSI i !RISER,AND BOP STACK _ Printed 4/8/2013 11:07:06AM i North America-ALASKA-BP Page B of 22," Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM r Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth , Phase Description of Operations (hr) __ (usft) 09:00 - 16:00 7.00 BOPSUR P SURF TEST BOPE PER BP/AOGCC/DDI REQUIREMENTS TO 250-PSI LOW/3500-PSI HI. TESTED 2-7/8"X 5-1/2"UPPER VBR'S AND LOCKS,2-7/8"X 5-1/2"LOWER VBR'S AND LOCKS WITH 4" TEST JT.TESTED BLIND SHEAR RAMS 250-PSI LOW/3500-PSI HI,2 EA.OF 4-1/2"IF FOSV'S, 1 EA.OF 4"DART VALVE&FOSV.TESTED CHOKE MANIFOLD VALVES 1-15,CHOKE AND KILL MANUAL& HCR VALVES,4"KILL LINE VALVE&UPPER AND LOWER TOP DRIVE IBOP'S. TESTED MANUALAND SUPER CHOKES TO 250-PSI LOW/3500-PSI FOR 5 CHARTED MINUTES EACH TEST. TESTED ANNULAR PREVENTER WITH 4" TEST JT.250-PSI LOW/3500-PSI HI. CHARTED ALL HI AND LO TESTS FOR 5-MINUTES EACH. "FIRST 5"FOSV PT(FAILED),PICKED UP SPARE PT(PASS) - CLOSING TIMES: -BLIND/SHEARS=17 SEC UPPER VBR'S=15 SEC LOWER VBR'S=15 SEC 'ANNULAR=24 SEC HCR KILL=2 SEC HCR CHOKE=2 SEC PERFORMED ACCUMULATOR DRAWDOWN TEST: -ACCUMULATOR PSI=3050,MANIFOLD PSI= 1550 -ACCUMULATOR PSI AFTER FUNCTIONING BOPE=1700-PSI -RECOVERY TO FULL SYSTEM PRESSURE= 2-MINUTES 54-SECONDS. -6 NITROGEN BOTTLES AVERAGE PRESSURE=2050-PSI REFERENCED DDI BOP TESTING SOP FOR ALL TESTING. BOPE TEST WITNESSED BY AOGCC-CHUCK SHEVE,DOYON i TOOLPUSHER-SAM DYE,AND BP WSL-MIKE HEFLEY 16:00 - 16:30 0.50 BOPSUR P SURF INSTALL 9"WEAR BUSHING 16:30 17:00 0.50 BOPSUR P SURF SERVICE TOP DRIVE 17:00 - 17:30 0.50 BOPSUR N RREP SURF C/O VALVE BLOCK ON TOP DRIVE 17:30 - 00:00 6.50 BOPSUR P SURF SINGLE IN W/ MULESHOE AND 4"DP AND STAND BACK 3/5/2013 00:00 - 02:00 2.00 CEMT P SURF RIH W/4"DP.POH STAND BACK. 02:00 - 04:00 2.00 CEMT P SURF PRESSURE TEST 9-5/8"CASING ✓ -250 PSI/3,500 PSI FOR 5/30 MIN CHARTED (PASS) 04:00 - 08:00 4.00 CEMT P SURF MU BHA#4 PER SLB DD LOAD SOURCE PER MWD 08:00 - 08:30 0.50 CEMT P SURF i SHALLOW HOLE TEST AT 684'MD(GOOD) 08:30 - 10:00 1.50 CEMT P SURF I SERVICE TOP DRIVE Printed 4/8/2013 11:07:06AM Page 9 of 22 North America-ALASKA-BP Operation Summary Report Common Well Name Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM 1 Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UW: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 12:00 2.00 CEMT P SURF RIH F/684'MD T/3,463'MD -TAGGED TOP CEMENT PLUG AT 3,463'MD 12:00 - 14:30 2.50 CEMT P i SURF CONT RIH F/3,463'MD TO 3,479'MD -200 GPM,980 PSI 4 -SLACKED OFF WITHOUT ROTATION 14:30 - 15:00 0.50 CEMT P SURF i WASH AND DRILL F/3,479'MD TO 3,591'MD TAGGED FC ON DEPTH AT 3,515', -450 GPM,2170 PSI,2K WOB -40 RPM,7-8K TO 15:00 - 15:30 0.50 CEMT P SURF DISPLACE WELL TO NEW 9.0 PPG LSND MUD -450 GPM,1230 PSI -40 RPM, 15:30 - 16:30 1.00 DRILL i P I SURF DRILL OUT REMAINING SHOE TRACK AND 20' OF NEW FORMATION FROM 3,591'TO 3.631' -450 GPM,2170 PSI -40 RPM,7-8K TQ -TAGGED FLOAT COLLAR AND CASING SHOE I ON DEPTH SPR'S AT 3,601'MD(3127'ND),TIME 15:30, MW 9.0 PPG #1 MP-20/30 SPM=200/250 PSI #2 MP-20/30 SPM=200/250 PSI 16:30 - 17:30 1.00 DRILL P SURF CBU 2X -470 GPM,1230 PSI -RU FOR LOT 17 30 - 18.30 1.00 DRILL P SURF PJSM FOR LOT OPERATIONS PULL UP INTO THE 9-5/8"SHOE AND, PERFORM FIT PERFORM FIT TO 14.3 EMW -ODE APPROVAL TO CONTINUE OPERATIONS WITH A GREATER THAN 50 BBL KICK TOLERANCE MONITOR WELL FOR 10 MIN-WELL STATIC _ I -MW IN-9.0 PPG,MW OUT-9.0 PPG 18.30 - 19:30 1.00 DRILL P INTI DRILL 8.75"INTERMEDIATE HOLE F/3,631'MD T/3,775'MD 19:30 - 21:00 . 1.50 DRILL N DFAL 3,775.00 INTI RESISTIVITY TOOL LOCKED UP. -TROUBLE SHOOT PROBLEM,AND ABLE TO UNLOCK TOOL -PULL BACK TO SHOE, -MAD PASS T/3,775'MD 21 00 - 00:00 3.00 DRILL P INTI DRILL 8.75"INTERMEDIATE HOLE F/3,775'MD T/4,107'MD 3,515'ND -582 GPM,1940 PSI ON/1740 PSI OFF -MW 9.0 IN/9.0 OUT -ECD 9.7 PPG(CALC ECD 9.48 PPG) -80 RPM,6K TQ ON/5K TQ OFF -4-6K WOB -AST=0.47 HRS,ART=1.52,ADT=1.99 HRS, TOTAL BIT HRS -P/U=123K,5/0=105K,ROT=110K 3/6/2013 00:00 - 12:00 12.00 DRILL P INTI DRILL 8.75"INTERMEDIATE HOLE F/4,107'MD T/5,626'MD (4,752'TVD) -580 GPM,2580 PSI ON/2360 PSI OFF -MW 9.3 IN/9.4 OUT ECD 9.7 PPG(CALC ECD 9.76 PPG) -100 RPM,9K TQ ON/8K TQ OFF -8K WOB • L-1 P/U=153K,S/O=121K,ROT=149K Printed 4/8/2013 11.07:06AM North America-ALASKA-BP Page 10 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date. I X3 011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay I Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs . Task , Code NPT NPT Depth ' Phase Description of Operations (hr) (usft) 12:00 - 00:00 : 12.00 DRILL P INTI 1DRILL 8.75"INTERMEDIATE HOLE F/5,627'MD T/6,860'MD /' -580 GPM,3522 PSI ON/3,180 PSI OFF -MW 10.2IN/10.1+OUT -ECD 11.4 PPG(CALC ECD 10.7 PPG) -100 RPM,11K TQ ON/10K TQ OFF -15K WOB -AST=1.01 HRS,ART=5.56,ADT=6.57 HRS, TOTAL BIT HRS=14.97 -P/U=174K,S/O=130K,ROT=149K 3/7/2013 00:00 - 03:30 ' 3.50 DRILL P INTI I DRILL 8.75"INTERMEDIATE HOLE F/6,910'MD V J TO 7,015'MD -580 GPM,3522 PSI ON/3,180 PSI OFF -MW 10.2 IN/10.1+OUT 03:30 - 04:30 1.00 DRILL N RREP 7,015.00 INTI STALLED MUD MOTOR WHILE MAKING A SLIDE -#1 PUMP PRESSURE RELIEF VALVE WAS TRIGGERED -HAD TO C/O PRV -RESUMED OPERATIONS.OBSERVED -500 PSI DROP IN PUMP PRESSURE -INSPECTED #1 PUMP&FOUND A DISCHARGE VALVE&SEAT WASHED OUT, CIO VALVE AND SEAT 04:30 - 12:00 7.50 DRILL P INTI CONT DRILLING 8.75"INTERMEDIATE F/7,015' ✓ T/7,525'MD(6,484'TVD) -550 GPM,3530 PSI ON/3260 PSI OFF _.. -MW 10.2 IN/ 10.2 OUT -ECD 11.23 PPG(CALC ECD 10.7 PPG) -100 RPM,12K TQ ON/11K TQ OFF 18K WOB -P/U=198K,S/O=136K,ROT=147K 12:00 - 00:00 12.00 DRILL P INTI DRILL 8.75"INTERMEDIATE HOLE F/7,525'MD T/8,285'MD (7,168'TVD) V' -550 GPM,3750 PSI ON/3467 PSI OFF -MW 10.4 IN/10.4 OUT -ECD 11.3 PPG(CALC ECD 10.9 PPG) -80 RPM,11K TQ ON/8K TQ OFF -15K WOB -AST=2.52 HRS,ART=4.64,ADT=7.16 HRS, TOTAL BIT HRS=29.04 -P/U=174K,S/O=146K,ROT=160K 3/8/2013 00:00 - 12:00 12.00 DRILL P INTI CONT DRILLING 8.75"INTERMEDIATE F/8,285' MD T/9,235'MD(8,021'TVD) -530 GPM,3,760 PSI ON/3340 PSI OFF -MW 10.5 IN/ 10.4+OUT -ECD 11.43 PPG(CALC ECD 10.81 PPG) -80 RPM,10K TQ ON/8K TQ OFF -16K WOB P/U=210K,S/O=153K,ROT=172K 12:00 - 21:30 9.50 DRILL P INTI CONT DRILLING 8.75"INTERMEDIATE F/9,235' MD TO (TD)AT 9,863'MD(8,597'TVD) -TSAG AT 9,853'MD,DRILL ADDITIONAL 10' -505 GPM,3,700 PSI ON/3,310 PSI OFF -MW 10.51N/ 10.4+OUT -ECD 11.43 PPG(CALC ECD 10.81 PPG) -80 RPM,10KTQ ON/8KTQ OFF 16K WOB -P/U=234K,S/O=160K,ROT=188K -AST=2.67 HRS,ART=12.72,ADT=15.39 HRS,TOTAL BIT HRS=44.43 Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 11 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:OOAM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual©96.10usft(above Mean Sea Level) Date From-To Hrs Task Code l NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 00:00 2.50 DRILL INTI CIRCULATE HOLE CLEAN -ROTATING AND RECIPROCATING F!9,859' MD T/9,805'MD j I -500 GPM,3250 PSI,TOTAL 3 X BU -PUMP 30 BBLS HI-VIS SWEEP 3/9/2013 00:00 - 01.00 1.00 DRILL P INTI CONT 3X CBU WHILE ROTATING AND RECIPROCATING F/9,859'MD T/9,805'MD -505 GPM,3250 PSI,80 RPM -TOTAL LOSS DURING CIRCULATION 12 BBLS 01:00 - 01:30 0.50 DRILL INTI 10 MIN FLOW CHECK BEFORE PULLING OFF BOTTOM. -STATIC LOSS RATE AT-8 BPH PUW-238K,SOW-156K,ROT-188K SPR'S AT 9,859'MD(7,227'TVD),TIME 1:15, MW 10.4 PPG #1 MP-20/30 SPM=340/460 PSI #2 MP-20/30 SPM=340/460 PSI 01:30 - 03:00 1.50 DRILL P INTI 'PUMP OUT OF THE HOLE FROM 9,859'MD TO 8,475' -84 GPM,400 PSI -P/U-238K,S/O-156K -PULL ON ELEVATORS FROM 8,475'TO 6,950' 03:00 - 04:30 1.50 DRILL P INTI POOH ON ELEVATORS F/8,475'MDT/6,958' MD 04:30 - 06:00 1.50 DRILL P INTI TIH ON ELEVATORS F/6,958'MD T/9,863'MD 06:00 - 10:00 4.00 DRILL P INTI CIRCULATE WHILE ROTATING AND RECIPROCATING -525 GPM,3350 PSI -100 RPM,15K TQ -PUMPED 4.5X BU UNTIL 9.3 PPG MUD IN AND 9.3 PPG MW OUT _ 10:00 - 11:30 1.50 DRILL P INTI MONITOR WELL -STATIC LOSS RATE:-6 BPH 1-PUMP OUT F/9,863'MD T/8,475'MD 1-80 GPM,410 PSI 11:30 - 12:00 0.50 DRILL P I INTI POOH ON ELEVATORS F/8,475'MD T/7,900' MD _ -NO TIGHT SPOTS OBSERVED WHILE POOH 12:00 - 14:00 2.00 EVAL P INTI MAD PASS PER ODE DISCUSSION AT 350 FT/MIN F/7,900'MDT/7,640'MD -500 GPM,2870 PSI -40 RPM,10K TQ -P/U WT=230K,S/O WT=125K 14:00 - 16:30 2.50 DRILL P INTI POOH ON ELEVATORS F/7,460'MD T/3,533' MD 16:30 - 17:00 0.50 DRILL P INTI ROTATE AND RECIPROCATE F/3,533'MDT/ 3,485'MD -570 GPM,2310 PSI -100 RPM 17:00 - 17:30 0.50 DRILL P INTI PUMP 20 BBL DRY JOB 17:30 - 19:30 2.00 DRILL P INTI POOH ON ELEVATORS F!3,485'MDT/684'MD 19:30 - 23:00 , 3.50 DRILL P INTI LID 5"HWDPAND BHA#4 PER SLB DD -STAND BACK 5"HWDP PJSM FOR REMOVAL OF RADIOACTIVE SOURCE -REMOVE SOURCE PER SLB MWD PROCEDURES. Printed 4/8/2013 11:07:06AM • North Amenca-ALASKA-BP Page 12 of 22 49 „ Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: 1X3-0111\AR-C:DRILL(9,245,086.00) Project:Prudhoe Bay I Site:PB Z Pad Rig Name/No.:DOYON 25 ' Spud Date/Time:2/26/2013 8:00:OOAM Rig Release:3/25/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 DRILL P INTI DRAIN STACK,PULL WEAR BUSHING, -INSTALL TEST PLUG,CLEAN AND CLEAR RIG FLOOR TOTAL LOSSES FOR THE DAY 33 BBLS 3/10/2013 00:00 - 01:00 1.00 BOPSUR P INTI I C/O UPPER VBR'S FROM 2-7/8"X 5-1/2" TO 7" CASING RAMS 01:00 - 03:00 1.00 BOPSUR P INTI 'PU 7"TEST JOINT,RU TEST EQUIPMENT TEST RAMS TO 250 LOW/3500 HIGH FOR 5/5 CHARTED MIN EACH(PASS) -UPLOAD TEST CHART TO OPENWELLS 03:00 - 04:00 2.00 CASING P INTI RU TO RUN 7",26#,L-80,VTHC CASING -C/O TOP DRIVE PIPE HANDLER DIES TO 6-5/8" 1-MU DOYON VOLANT CRT 04:00 - 05:30 1.50 CASING P INTI MU SHOE TRACK -BAKERLOCK CONNECTION UP TO LANDING COLLAR -CHECK FLOATS(GOOD) 05:30 - 12:00 6.50 CASING P INTI RUN 7",26#,L-80,VTHC CASING T/3,314'MD -FILL AND CIRCULATE EVERY 10TH JOINT 12:00 - 13:00 1.00 CASING P INTI RUN 7",26#,L-80,VTHC CASING F/3,314'MD T/3,558'MD RECALIBRATE HOOKLOAD BEFORE ENTERING OH -STAGE PUMP UP TO 7 BPM,660 PSI -CIRCULATE 2X BU -P/U WT=142K, S/O WT=118K 13:00 - 15:30 2.50 CASING P INTI RIH W/ 7",26#,L-80,VTHC CASING F/3,558' MD T/4,968'MD 15:30 1600 0.50 CASING P INTI CBU RECIPROCATING PIPE F/4,968'MDT/ 4,944'MD -5 BPM,500 PSI -P/U WT=142K,S/O Wr=118K 16:00 - 00:00 8.00 CASING P INTI RIH W/ 7",26#,L-80,VTHC CASING F/4,968' ✓ MD T MD T/8,658'MD -CONT TO FILL EVERY 10TH JOINT _ 3/11/2013 00:00 - 02:30 2.50 CASING P INTI RIH WITH 7",26#,L-80,VTHC CASING F/8,658' MD TO 9,858'MD. 02:30 - 03:00 0.50 CASING P INTI MU AND TAG CASING HANGER ON DEPTH. 03:00 - 05:00 2.00 CASING P INTI CONDITION 10.4 LSND MUD WHILE RECIPROCATING CASING -NO LOSSES OBSERVED WHILE 1 CIRCULATING -STAGED UP TO 7 BPM,900 PSI 05:00 - 07:00 ( 2.00 CASING N CEMT INTI WAIT ON SLB TO MIX RETARDER FOR LEAD MIX WATER. Printed 4/8/2013 11:07:06AM O • North America-ALASKA-BP Page 13 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date 1 From-To T Hrs Task Code , NPT i NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 13:30 6.50 CASING P INTI 'INTERMEDIATE CEMENT JOB AS FOLLOWS: PSI TEST CEMENT LINES TO 250/4500 FOR 5 CHARTED MINUTES-GOOD -PUMP 30 BBLS OF 11 PPG MUD PUSH @ 6 BPM,1200 PSI. -LAUNCH BOTTOM PLUG AND CHASE W/ 165.5 BBLS OF 11.5 PPG,1.76 FT3/SK, LITE CRETE+GASBLOK @ 5.5 BPM,720 PSI. - P 42 BBLS OF 15.8 PPG,1.17 FT3/$K, CLASS G+GASBLOK @ 5 BPM,600 PSI. -LAUNCH TOP PLUG. -DISPLACE WITH 374 BBLS OF 10.4 PPG LSND MUD @ 7 BPM,400 PSI. -DID NOT BUMP PLUG ON STROKES. -PUMPED ADDITIONAL 1.65 BBLS(HALF SHOE TRACK VOLUME). -SHUT DOWN PUMPS. -FLOATS-HOLDING-CIP @ 13:00 HRS. -CMT WILL ACHIEVE 500 PSI COMPRESSIVE I STRENGTH @ 23:38 HRS. I I LOST 8 BBLS OVER ENTIRE CEMENT JOB. 13:30 - 15:30 2.00 CASING P I INTI R/D CEMENTING EQUIPMENT. i -B/D CEMENTING LINES. -B/D SLB CEMENTING LINES. I -R/D CEMENTING LINES. -UD VOLANT CRT. I-UD LANDING JOINT. -CLEAN CEMENT MANIFOLD VALVES. 15:30 - 16:00 0.50 CASING P I INTI CLEAN AND CLEAR RIG FLOOR. 16:00 - 17:30 1.50 CASING P I INTI INSTALL PACKOFF AND TEST. 250 LOW/5000 HIGH FOR 15/30 CHARTED 'MINUTES EACH(PASS) -UPLOAD CHART TO OPENWELLS 17:30 - 19:00 1.50 BOPSUR P INTI C/O UPPER RAMS T/2-7/8"X 5-1/2"VBR'S 1-TEST FOLLOWING: -4"TEST JOINT: -3-1/2"IF DART VALVE -3-1/2"IF FOSV -2-7/8"X 5-1/2"VBR'S I '"TEST ALL TO 250 PSI LOW/3500 PSI HIGH FOR 5/5 CHARTED MIN EACH(PASS) 19:00 - 21:00 2.00 BOPSUR P INTI R/U INJECTION LINES FROM MANIFOLD TO CELLAR FOR FREEZE PROTECTING OA ' -PT LINES TO 250 PSI LOW/3500 PSI HIGH FOR 5/5 CHARTED MIN(GOOD) I INJECT DOWN THE OA: -1 BPM WITH BREAK OVER AT 1145 PSI,FCP =1280 PSI. -PUMPED TOTAL OF 67 BBLS. 21:00 - 00:00 3.00 CASING P INTI MU BHA#5 PER SLB DD: -6-1/8"INSERT BIT. -1.5"-BEND MOTOR. -D&I/GR/ADN/RES/NEU/DEN. -INSTALL SOURCE PER SLB MWD. -5"HWDP AS NECESSARY. I Printed 4/8/2013 11:07:06AM • Page 14 of 22�I North America-ALASKA-BP Operation Summary Report ' Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/12/2013 00:00 - 03:00 3.00 CEMT P INTI M/U&RIH WITH PRODUCTION 6-1/8" DRILLING BHA#5 PER SLB DD TO 327' I-6-1/8"HC VM-R18DVHX INSERT BIT,1.50° MOTOR, -IMPULSE -ADN475 -C/O PS-21 SLIP INSERTS TO 4" 03:00 - 03:30 0.50 CEMT P INTI RIH WITH BHA#5 ON 4"DP DOUBLES FROM THE PIPE SHED F/327'MD TO 1,625'MD -MONITOR DISLACEMENT FROM PITS 2-3 03:30 - 04:00 0.50 CEMT P INTI PERFORM MWD SHALLOW HOLE TEST (GOOD) -240 GPM,1410 PSI -BLOW DOWN THE TOP DRIVE 04:00 - 06:00 2.00 CEMT P INTI CONT RIH WITH BHA#5'ON 4"DP DOUBLES FROM THE PIPE SHED F/1625'MD TO 4,412' 06:00 - 08:00 2.00 CEMT P INTI TIH WITH BHA ON 4"DP STANDS FROM THE DERRICK -TIH F/4,412'MD TO 7,933'MD,FILLING PIPE -MONITOR DISLACEMENT FROM PITS 2-3 -FILLING PIPE EVERY 20 STANDS 08:00 - 12:30 4.50 CEMT P INTI RU AND TEST VT HC 7"CSG TO 250PSI LOW FOR 5 CHARTED MINUTES AND 3500 PSI HIGH FOR 30 CHARTED MINUTES-TEST DID NOT MEET STABILIZATION CRITERIA FROM AK DWOP 10-45 SEC 5C -RETEST CASING TO SAME PRESSURES AND SEND PRESSURE TEST RESULTS TO TOWN SECOND TEST-GOOD 12:30 - 14:30 2.00 CEMT P INTI PJSM FOR SLIP AND CUT DRILL LINE -SLIP AND CUT 141'OF DRILL LINE 14:30 - 16:30 2.00 CEMT • P INTI TIH WITH BHA ON 4"DP STANDS FROM THE DERRICK -TIH FROM 7,933'MD TO TO 9,637'MD -PUW-255K,SOW-107K -WASH DOWN F/9,637'MD TO 9,770'MD -105 GPM,1200 PSI,30 RPM,14K TQ, -TAG TOP CMT PLUG AT 9,770' 16:30 - 17:30 1.00 DRILL P INTI DRILL OUT SHOE TRACK F/9,770'MD T,O 9,848'MD(10'FROM THE SHOE) -230 GPM,2325 PSI,40 RPM,14 K TQ, WOB-3K -PUW-255 K,SOW-119K 17:30 - 19:00 1.50 DRILL P INTI DISPLACE WELL TO 8.8 PPG POWER-PRO -230 GPM,1793 PSI -60 RPM, ROTATE AND RECIPROCATE F/9,827'TO 9,848' SPR'S:9,846'MD(8583'TVD)-TIME=19:00, MW=8.8 PPG #1 MP-20/30 SPM=400/540 PSI _ #2 MP-20/30 SPM=440/560 19:00 20:00 1.00 DRILL P INTI DRILL SHOE TRACKAND 20'OF NEW FORMATION TO 9,883'MD -230 GPM,1330 PSI -40 RPM,51(TQ -3KWOB P/U 189K,S/O 158K Printed 4/8/2013 11:07:06AM • North America-ALASKA-BP Page 15 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: i X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -- t) 0:00 - 21:00 1.00 DRILL P INTI CIRCULATE BOTTOMS UP -250 GPM,1382 PSI -60 RPM,6K TQ MONITOR WELL FOR 10 MIN—STATIC 21:00 - 23:00 2.00 DRILL P INTI PULL BACK INTO SHOE&PERFORM FIT TO. 412.5 PPG EMW SURFACE PRESSURE TO 1660 PSI WITH !SHOE TVD @ 8,594' MW8.81N/8.8OUT 12.0 BBLS PUMPED,1.5 BBLS RETURNED -12.5 PPG FIT GIVES US AN INFINITE KICK }TOLERANCE SENT RESUrtS TO TOWN ODE AND FOR ,APPROVAL, 1-AUTHORIZATION TO PROCEED RECEIVED i 1 FROM ODE WITH GREATER THAN 50 BBL KICK TOLERANCE -CLEAN OUT SHAKER BELLY'S WHILE WAITING FOR APPROVAL FROM ODE / 23:00 - 00:00 1.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE FROM 9,883' MD TO 9,903"MD(8,636'TVD) 242 GPM,1,650 PSI ON/1,380 PSI OFF i WOB=18-22K I-mw=8.8 PPG IN/8.8 PPG OUT -P/U=190K,S/O=160K,ROT= AST=1.22 HRS,ART=0.00 HRS,ADT=1.22 HRS TOTAL BIT HRS=1.22,TOTAL JAR HRS=1.22 TOTAL LOSSES FOR LAST 24 HRS=0 BBLS 3/13/2013 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE SECTION .� FROM 9,903"MD TO 10,146'MD 8,822'TVD -251 GPM,1,706 PSI ON/1,520 PSI OFF WOB=15-25K,40 RPM,7K TQ -MW=8.8PPG IN/8.BPPG OUT ;-P/U=193K,S/O=163K,ROT=165K AST=5.88 HRS,ART=0.92 HRS,ADT=6.8 HRS TOTAL BIT HRS=8.02,TOTAL JAR HRS=8.02 SPR'S:10,139'MD(8,822'TVD)-TIME=11:50, MW=8.8 PPG #1 MP-20/30 SPM=520/640 PSI #2 MP-20/30 SPM=460/560 Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 16 of 22 Operation Summary Report Common Well Name.Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 ; Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual(g)96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE SECTION FROM 10,146'MD TO 10,552'MD,8,956'TVD -251 GPM,1,806 PSI ON/1,528 PSI OFF WOB=15-25K,40 RPM,7K TQ -MW=8.8PPGIN/8.8PPGOUT -P/U=193K,S/O=155K,ROT=165K AST=2.23 HRS,ART=4.79 HRS,ADT=7.02 HRS TOTAL BIT HRS=15,TOTAL JAR HRS=15 !TOTAL LOSSES FOR LAST 24 HRS=0 SPR'S:10,485'MD(8,944'TVD)-TIME=22:30, MW=8.8 PPG #1 MP-20/30 SPM=480/620 PSI #2 MP-20/30 SPM=440/560 3/14/2013 00:00 - 11:30 11.50 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE SECTION FROM 10,552'MD,TO 10,867'MD,8,931'TVD -251 GPM,1,770 PSI ON/1,600 PSI OFF -WOB=15-25K,40 RPM,8-9 K TO MW=8.8PPG IN/8.8PPG OUT -P/U=195K,5/0=155K,ROT=165K AST=4.34 HRS,ART=1.22 HRS,ADT=5.56 HRS TOTAL BIT HRS=20.56,TOTAL JAR HRS= 20.6 � I SPR'S:10,855'MD(8,931'TVD)-TIME=11:45, MW=8.8PPG IC MP-20/30 SPM=460/580 PSI #2 MP-20/30 SPM=440/600 11:30 - 12:30 1.00 DRILL P i PROD1 CIRCULATE BOTTOMS UP,ROT AND RECIPROCATE F/10,867'TO 10,772' -250 GPM,1570 PSI,40 RPM 12:30 - 20:30 8.00 DRILL P PROD1 MONITOR WELL FOR 10 MIN-WELL STATIC -BLOW DOWN TOP DRIVE I-POOH ON ELEVATORS F/10,867'MD TO 422' -MONITORING WELL VIA THE TRIP TANK, MAINTAIN ACCURATE TRIP SHEET -PUW-195K,SOW-155K,ROT 165K 20:30 - 21:30 1.00 DRILL P PROD1 MONITOR WELL PRIOR TO PULLING BHA THROUGH THE STACK -WELL STATIC. -POOH F/422'TO 202' -C/O PS21 SLIP INSERTS,LD BHA#5 PER SLB(DD)REP 21:30 - 22:00 0.50 DRILL P PROD1 PJSM FOR PULLING THE RADIOACTIVE SOURCE FROM THE BHA -PULL- SOURCE PER SLB PROCEDURE. --_---SSSS-- 22:00 - 23:30 1.50 DRILL P PROD1 FINISH LAYING DOWN 6-1/8"PRODUCTION BHA#5 - F/94 TO SURFACE - BIT GRADE:2-8-LT-G-E-6-RG-PR 23:30 - 00:00 0.50 DRILL P PROD1 CLEAN&CLEAR RIG FLOOR !-RIG UP FOR BOPE TESTING Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 17 of 22 4,0+r, e Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/15/2013 00:00 - 06:00 6.00 BOPSUR P PROD1 TEST BOPE PER BP/AOGCC/DDI 1 REQUIREMENTS TO 250-PSI LOW/3500-PSI HI. �U� TESTED 2-7/8"X 5-1/2"UPPER VBR'S,2-7/8"X 5-1/2"LOWER VBR'S WITH 4" TEST JT. TESTED BLIND SHEAR RAMS 250-PSI LOW/ 3500-PSI HI,2 EA.OF 4-1/2"IF FOSVS, 1 EA. OF 4"DART VALVE&FOSV.TESTED CHOKE MANIFOLD VALVES 1-15,CHOKE AND KILL MANUAL&HCR VALVES,4"KILL LINE VALVE& UPPER AND LOWER TOP DRIVE IBOP'S. TESTED MANUAL AND SUPER CHOKES TO 250-PSI LOW/3500-PSI FOR 5 CHARTED MINUTES EACH TEST. TESTED ANNULAR PREVENTER WITH 4" TEST JT.250-PSI LOW/ 3500-PSI HI. CHARTED ALL HI AND LO TESTS FOR 5-MINUTES EACH.. **UPPER IBOP (FAILED),C/0&RE TEST '(PASS) CLOSING TIMES: 'BLIND/SHEARS=18 SEC UPPER VBR'S=18 SEC !LOWER VBR'S=16 SEC ANNULAR=22 SEC HCR KILL=3 SEC HCR CHOKE=3 SEC PERFORMED ACCUMULATOR DRAW DOWN TEST: -ACCUMULATOR PSI=3000,MANIFOLD PSI= 1500 -ACCUMULATOR PSI AFTER FUNCTIONING BOPE=1600-PSI -RECOVERY TO FULL SYSTEM PRESSURE= 2-MINUTES 18-SECONDS. -6 NITROGEN BOTTLES AVERAGE PRESSURE=2000-PSI REFERENCED DDI BOP TESTING SOP FOR ALL TESTING. BOPE TEST WITNESSED BY i AOGCC-DOYON TOUR PUSHER-ROY FRITZ, AND BP WSL-ANTHONY KNOWLES JEFF JONES W/AOGCC WAIVED WITNESS. 06:00 - 07:30 1.50 BOPSUR P PROD1 RIG DOWN TEST EQPT,BLOW DOWN LINES& CHOKE MANIFOLD -PULL TEST PLUG&SET WEAR BUSHING _------------------- 07:30 - 08:00 0.50 BOPSUR P PROD1 PJSM FOR TOP DRIVE SERVICE LOCK OUT AND TAG OUT&SERVICE TOP DRIVE 08:00 - 12:30 4.50 BOPSUR N PROD1 PJSM FOR CHANGING OUT UPPER IBOP ON TOP DRIVE -CHANGE OUT UPPER IBOP -RE-TEST NEW IBOP-250 PSI LOW,3500 PSI LHIGH FOR 5 CHARTED MIN-(PASSED) Printed 4/8/2013 11:07:06AM "" North America-ALAKA-BP Page 18 of 22 Operation Summary Report Common Well Name.Z-66 AFE No Event Type:DRL-ONSHORE(DON) I Start Date:2/20/2013 I End Date: IX3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay I Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:30 - 16:00 3.50 DRILL P PROD1 PJSM FOR PICKING UP BHA#6 PU/MU&RIH WITH 6-1/8"PRODUCTION BHA #6-PER SLB DD REBUILT 6-1/8"HYCALOG PDC BIT, 4.75" I MOTOR W/1.5 DEG BEND, IMPULSE AND ADN 475-RIH TO 95' PJSM WITH SLB AND RIG CREW FOR LOADING THE SOURCE -LOAD SOURCE PER SLB PROCEDURE i-CONTINUE RIH F/95'TO 1,700'FOR SHALLOW HOLE TEST FOR MWD TOOLS- GOOD TEST -249.5 GPM,1100 PSI 16:00 - 22:00 6.00 DRILL P PROD1 TIH WITH 6-1/8"PRODUCTION BHA#6 F/1700' TO 10,775'MD TIH ON 4"DP FROM THE DERRICK. WASH AND REAM LAST STAND TO BOTTOM. -250 GPM,40 RPM,1570 PSI 22:00 - 00:00 2.00 DRILL P PROD1 IDRILL 6-1/8"PRODUCTION HOLE F/10,867' V' MD,8,931'TVD TO 10,939'MD 8,930'TVD -251 GPM,1,705 PSI ON/1,560 PSI OFF -WOB=15K,40 RPM,8 K TQ ON/7 K TQ OFF -MW=8.8 PPG IN/8.8 PPG OUT P/U=199K,S/O=149K,ROT=175K AST=.68 HRS,ART=.34 HRS,ADT=1.02 HRS TOTAL BIT HRS=1.02,TOTAL JAR HRS=1.02 SPR'S:10,871'MD(8,931'TVD)-TIME=22:30, MW=8.8 PPG #1 MP-20/30 SPM=420/540 PSI #2 MP-20/30 SPM=380/520 3/16/2013 00:00 - 12:00 12.00 DRILL PROD1 DRILL 6-1/8"PRODUCTION HOLE F/10,939'MD V , 8,930'TVD TO 11,537'MD,8,939'TVD 251 GPM,1,750 PSI ON/1,350 PSI OFF -WOB=3-15K,60-80 RPM,9 K TQ ON/8 K TQ OFF MW=8.8 PPG IN/8.8 PPG OUT -P/U=197K,S/O=153K,ROT=177K AST=1.48 HRS,ART=3.42 HRS,ADT=4.90 HRS TOTAL BIT HRS=5.92,TOTAL JAR HRS=26.5 SPR'S:11,347'MD(8,931'TVD)-TIME=08:00, MW=8.8PPG #1 MP-20/30 SPM=440/580 PSI #2 MP-20/30 SPM=420/560 Printed 4/8/2013 11:07:06AM • North America-ALASKA-BP ' " Page 19 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011 MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay 1 Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — (usft) 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/ 11,537'MD ✓' ,8,939'TVD TO 11,912'MD,8,939 TVD 251 GPM,1,750 PSI ON/1,350 PSI OFF -WOB=3-15K,60-80 RPM,9 K TO ON/8 K TQ OFF -MW=8.8 PPG IN/8.8 PPG OUT -P/U=201K,S/O=146K,ROT=174K AST=4.50 HRS,ART=1.61 HRS,ADT=11.01 HRS I TOTAL BIT HRS=12.03,TOTAL JAR HRS= 32.6 SPR'S:11,726'MD(8,945'TVD)-TIME=18:00, MW=8.8PPG #1 MP-20/30 SPM=460/620 PSI #2 MP-20/30 SPM=400/600 3/17/2013 00:00 - 12:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/11,912'MD 8,930'TVD TO 12,245'MD 8,937'TVD -251 GPM,1,950 PSI ON/1,800 PSI OFF -WOB=15-30K,60-80 RPM,10 K TQ ON/9 K TQ OFF -MW=8.8 PPG IN/8.8 PPG OUT AST=2.53 HRS,ART=2.36 HRS,ADT=4.89 IHRS TOTAL BIT HRS=17.0,TOTAL JAR HRS=37.6 I I i SPR'S:12,201'MD(8,933'TVD)-TIME=10:50, MW=8.8PPG #1 MP-20/30 SPM=520/640 PSI #2 MP-20/30 SPM=480/660 12:00 - 00:00 12.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/12245'MD 8,937'TVD TO 12,996'MD,8,942'TVD 251 GPM,1,985 PSI ON/1,792 PSI OFF V WOB=15-30K,60-80 RPM,10 K TQ ON/9 K TQ OFF -MW=8.8 PPG IN/8.8 PPG OUT I i AST=1.02 HRS,ART=5.22 HRS,ADT=6.26 HRS TOTAL BIT HRS=23.26,TOTAL JAR HRS= 43.4 SPR'S:12,676'MD(8,929'TVD)-TIME=19:00, MW=8.8 PPG #1 MP-20/30 SPM=500/680 PSI #2 MP-20/30 SPM=520/670 Printed 4/8/2013 11:07:06AM e North America-ALASKA-BP Page 20 of 22 Operation Summary Report Common Wet Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) 1 Start Date:2/20/2013 I End Date: !X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM I Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. j UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date I From-To ' Hrs Task Code ' NPT NPT Depth Phase Description of Operations (hr) (usft) _ 3/18/2013 00:00 - 08:00 8.00 DRILL P PROD1 DRILL 6-1/8"PRODUCTION HOLE F/12,996' MD,8,942'TVD � TD WELL @ 7:50 AM,13,386'MD,8,988 TVD 1-251 GPM,1,985 PSI ON/1,792 PSI OFF -WOB=15-30K,60-80 RPM,10 K TQ ON/9 K TQ OFF -MW=8.8 PPG IN/8.8 PPG OUT AST=0.49 HRS,ART=3.10 HRS,ADT=3.49 IFIRS TOTAL BIT HRS=26.58,TOTAL JAR HRS= 47.5 SPR'S:13,152'MD(8,958'TVD)-TIME=03:15, MW=8.8 PPG #1 MP-20/30 SPM=600/780 PSI #2 MP-20/30 SPM=640/780 PSI 08:00 - 11:00 3.00 DRILL P PROD1 1-CIRC 30 BBL HIGH VIS SWEEP T/SURFACE WHILE ROT&RECIP F/13,385'MD T/13,335' I MD @ 250 GPM,1630 PSI,21%F/O,80 RPM, 8-9K TQ. -OBTAIN SPR'S 13,386'MD(8,988'TVD)-TIME -=09:45,MW=8.8 PPG #1 MP-20/30 SPM=450/610 PSI #2 MP-20/30 SPM=470/610 PSI -CIRC ADDITIONAL 1.5 B/U WHILE ROT& RECIP F/13,342'MDT/13.40 MD @ 120 RPM, 9-10K TQ.,ALL OTHER PARAMETERS SAME - 00:00 13.00 EVAL P PROD1 (SLIGHT DROP 11:00 ,-MONITOR WELL FOR 10 MIN I IN LEVEL) -BROOH F/13,240'MD T/12,332'MD @ 60 RPM,250 GPM,1510 PSI,21%F/O,6-8K TQ, UP WT=202K,DOWN WT=147K -MAD PASS F/12,232'MD T/11,654'MD @ 250 GPM,1500 PSI,21%F/O,60 RPM,8K TQ -BROOH F/11,654'MD T/10,933'MD @ 60 RPM,250 GPM,1450 PSI,21%F/O,8K TQ -MAD PASS Ff 10,933'MD T/9,904'MD @ 250 !GPM,1500 PSI,21%F/O,60 RPM,8K TQ- 3/19/2013 00:00 - 01:00 1.00 DRILL P PROD1 -COMPLETE MAD PASS OPERATIONS -CIRCULATE BOTTOMS UP INSIDE THE SHOE -250 GPM,1440 PSI,40 RPM 01:00 - 01:30 0.50 DRILL P PROD1 RIG SERVICE -GREASE TOP DRIVE 01:30 - 05:00 3.50 DRILL P PROD1 TIH ON ELEVATORS FROM 7"SHOE TO(TD) ,AT 13,345'MD -MONITOR TRIP VIA THE TRIP TANK 1-TIGHT @ 11,995'MD Printed 4/8/2013 11:07:06AM • North America-ALASKA-BP : z 'k r Page 21 of 2'2 Operation Summary Report - . .. Commcn Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date X3-011 MR-C.DRILL(9,245,086.00) Project Prudhoe Bay I Site.PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8.00:00AM Rig Release:3/25/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 08:30 3.50 DRILL P PROD1 WASH F/13,345'MD TO 13,386 MD(8988'TVD) -ROTATE AND RECIPROCATE -CBU 1.5X j- 250 GPM,1530 PSI, -60 RPM,7-9 TQ RACK BACK STD#138 AND CONTINUE TO ROTATE AND RECIPROCATE 13,345'MD TO 13,250'MD WITH SAME PARAMETERS. -CBU 3X -OBTAIN SCR @ 13,247'MD,8971'ND -MP#1 20/30 SPM 420/580 PSI -MP#2 20/30 SPM 420/560 PSI _ -MONTIOR WELL,STATIC. 08:30 - 12:00 3.50 DRILL P PROD1 POOH ON ELEVATORS F/13,345'MD TO 9832' MD -MONITOR HOLE FILL VIA TRIP TANK -TIGHT SPOT F/11,810'MD TO 11,790'MD, PULL 25K OVER, WIPED 4X 12:00 - 14:00 2.00 DRILL P PROD1 DROP 1.76"OD BALL TO OPEN"WELL COMMANDER"CIRC SUB -OPEN WITH 2700 PSI -CBU 1.5X W/400 GPM,1050 PSI -RECIPROCATE PIPE F/9832'MD TO 9730'MD -PU WT 186K,SO WT 161 K -TOTAL STKS PUMPED 2920 -DROP 1.76"OD BALL AND CLOSE CIRC SUB W/3339 PSI 14:00 - 16:00 2.00 DRILL P PROD1 RIH F/9832'MD TO 12,110'MD -TAKING WT @ 11,675'MD 30K,@ 11,790'MD 15K,@11,856'MD25K,@11,875'MD30K 16:00 - 18:30 2.50 DRILL P PROD1 BACK REAM F/12,015'MD TO 11,630'MD -250 GPM, 1550 PSI -40/80 RPM,6-7 TO -PU WT 200K,SO-150K,ROT-167K 18:30 - 21:30 3.00 DRILL P PROD1 RIH ON ELEVATORS F/11,630'MD TO 11,945' MD !- TAKING WEIGHT @ 11,655'MD 30K,a '11,790'MD35K,@11,813'MD35K,@11,856'- -MD 20K,@ 11,945'MD 35K. -ATTEMPT TO WORK THROUGH 11,945'MD W/125/150 GPM,600/760 PSI,NO GO. 21:30 - 22:30 1.00 DRILL P PROD1 INCREASE TO 250 GPM,1500 PSI,ROTATE AND RECIPROCATE SUCCESSFULLY THROUGH OBSTRUCTION F/11,938'MD TO 11,980', -40 RPM -il -PU-200K,SO-150K,ROT-170K 22:30 - 23:30 1.00 DRILL P PROD1 RIH F/11,917'MD TO 13,345'MD 23:30 - 00:00 0.50 DRILL P PROD1 MU TDS AND WASH F/13,345'MD TO 13,386' MD -250 GPM,1575 PSI -40/100 RPM -7-8K TQ 3/20/2013 00:00 - 02:30 I 2.50 DRILL P PROD1 ROTATE AND RECIPROCATE F/13,386'MD TO 13,340'MD WHILE CBU -MONTIOR WELL,STATIC 02:30 - 06:30 4.00 DRILL P PROD1 POOH TO PU/RUN 4.5 PRODUCTION LINER F/ 13,340'MD TO 9832'MD -PULLED 20K OVER @ 11,950', DRY WIPED 3X,OK. Printed 4/8/2013 11:07:06AM sl4orth America-ALASKA BP, r r Page 22 of 22 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:DRL-ONSHORE(DON) Start Date:2/20/2013 End Date: X3-011MR-C:DRILL(9,245,086.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI. Active datum:Z-66 actual©96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 06:30 - 08:30 1 2.00 DRILL P PROD1 DROP 1.76"OD BALL AND OPEN WELL COMMANDER CIRC SUB,SHIFT OPEN W/ 2500 PSI -ROT/RECIP 9832'MD TO 9737'MD WHILE CBU 2X DROP BALL AND CLOSE W/3000 PSI MONTIOR WELL 10 MIN,STATIC -PUMP DRY JOB 08:30 - 14:30 6.00 DRILL P PROD1 POOH F/9832'MD TO 427'MD 14:30 - 18:00 3.50 DRILL P PROD1 C/O SLIPS -LD BHA EQUIPT -PJSM ON NUCLEAR SOURCE HANDLING, SLB MWD REMOVE SAME. -CONT LD BHA#6 -BIT GRADE 8-8-RO-A-X-1/8-TD Printed 4/8/2013 11:07:06AM North America-ALASKA-BP Page 1 of 4 Operation Summary Report Common Well Name:Z-66 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/20/2013 End Date:3/25/2013 X3-011 MR-C:DRILL(3,384,760.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8 00 00A Rig Release:3/25/2013 Rig Contractor.DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations 11 (hr) (usft) 3/20/2013 18:00 - 21:00 3.00 CASING P RUNPRD CLEAN/CLEAR RIG FLOOR RU TO RUN 4.5"12.6#13 CR-85 HYDRIL 521 LINER AND ASSOCIATED PRODUCTION _ EQUIPMENT 21:00 - 00:00 3.00 CASING P RUNPRD PJSM, PU SHOE TRACK,FILL AND CHECK FLOAT EQUIPMENT,OK RIH W/4.5"12.6#13 CR-85 HYDRIL 521 LINER,PU PUPS AND SWELL PACKERS F/0' TO 667'(11 OF 73JTS,) 3/21/2013 00:00 - 06:00 6.00 CASING P RUNPRD RIH W/4.5" 12.6#13 CR-85 HYDRIL 521 LINER 'AND PRODUCTION EQUIPMENTS F/667'MD I TO 366V MD 06:00 - 07:30 1.50 CASING P RUNPRD I C/O ELEVATORS,PU/MU BAKER FLEX LOCK III ZXP LINER HANGER -DRAIN STACK AND FILL PBR WITH PALL MIX -CIRC 2X LINER VOLUMES 07:30 - 12:30 5.00 CASING P RUNPRD PU 12 JTS OF 4"HWDP FROM SHED TO 4081' MD -RIH W/1 STD 4"HWDP AND 4"DP TO 9790' MD,FILL EVERY 1000' -MONITOR FLUID VIA PIT 2 12:30 - 13:30 1.00 CASING P RUNPRDCIRC LINER AT 9790', �-STAGE UP PUMPS TO 3.8 BPM,FCP 580 PSI, 1N0 LOSSES I I-PU WT 165,SO 146 K 13:30 - 16:30 3.00 CASING P RUNPRD CONT RIH W/4.5"LINER ON 4"DP F/9790'MD TO 13,384'MD -PU WT 210K,SO 146K 16:30 - 20:00 3.50 CASING P RUNPRD CIRC 4.5"LINER ON BOTTOM, -STAGE PUMPS UP TO 3.7 BPM, REDUCE RATE TO 2.5 BPM LOSSES DURING RIH AND CIRC 7 BBLS 1120:00 - 23:30 3.50 CASING P RUNPRD PJSM FOR PUMPING SPACERS PER MI PUMPING SCHEDULE. -DISCUSSED MI PROCEDURE AND ROLES AND RESPONSIBILITIES FOR THIRD PARTIES AND DDI PUMPED OBM SPACER PER MI SCHEDULE PUMP 150 BBLS OF 8.6 PPG NACL W/2%KCL, AT 2.5 BPM, ICP 660 PSI -25 BBLS OF LVT BASE OIL -50 BBLS OF 9.6 PPG RHELIANT -127 BBLS OF 8.8 PPG RHELIANT OBM -25 BBL HIGH VIS RHELIANT I i I -BREAK PIPE AND DROP 1.75"NEUTRAL WEIGHT BALL AND PUMP REMAINDER OF HIGH VIS RHELIANT OPM,10 BBLS CHASE WITH 8.8 PPG MOBM TO SEAT BALL IN WELLBORE ISOLATION VALVE -2 BPM,990 PSI.BALLON SEAT WITH 143 BBLS PUMPED. 4 BBL EARLY. TOATL FLUID LOSS DURING OBM CIRCULATION-2 BBLS Printed 4/8/2013 11.07.52AM NorthP.tnenca-ALASKA BP _ P,age2 of4 .-yxa .0 f s". '" ''' w it . v� .;P'`fL 'rt''fin fl i �y4.;k ,.z�, �' efamon uintnate �# w y � h _.. ._ .. ,..r. �. -,,,-,',;-- Common ,i .� m -� __� _._- e�� _ tx�'�c, .. Vis, . . .,, - - Common Well Name:Z-66 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/20/2013 End Date:3/25/2013 X3-011MR-C:DRILL(3,384,760.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs • Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 CASING P 1 ' RUNPRDSET LINER TOP HANGER AND PACKER -PRESSURE UP TO 3000 PSI TO SET HANGER SLIPS I-BLEED PSI,SLACK OFF TO 60 K TO VERIFY HANGER SET -PRESSURE UP TO 3800 PSI TO TO RELEASE HRD RUNNING TO PU TO 220 K I-- HRD-E TOOL DID NOT RELEASE PRESSURE BACK UP TO 4200 PSI TO RELEASE HRD SETTING TOOL 1-PU TO 198K,CONFIRM RELEASE FROM HANGER -PU 5'1 OFFTO 60KRELEASE,LINERDOG TOP PACKERON SET AT 25K.GOOD SURFACE INDICATION WT INDICATOR -P UAND THEN SLACK OFF 60K ROTATING 20 RPM ON PACKER TO CONFIRM SET 3/22/2013 00:00 - 02:30 2.50 CASING ' P RUNPRD j RU TO TEST 4 1/2"TBG BY 7"CASING LIFER TOP PACKER -250 PSI LOW FOR 5 CHARTED MIN -3500 PSI HIGH FOR 30 CHARTED MIN. -PRESSURE BLED DOWN 87 PSI IN THE FIRST 15 MIN,62 PSI IN THE SECOND 15, -FAILED TEST REPORT TO ODE -PUMP PRESSURBACK 00 RE - E BLEDUPTO DOWN3550FOR PSI INTEST THE FIRST 15 MIN,37 PSI IN THE SECOND 15 -FAILED RETEST 02:30 - 03:30 1.00 CASING P RUNPRD ROTATE AT 20 RPM'S,5 TQ,&SET 60 K ON PACKER TO CONFIRM SET OF LINER TOP PACKER 03:30 - 04:30 1.00 CASING P ' RUNPRD PU TO HAVE RUNNING TOOL ABOVE RS BUSHING AND LINER TOP RU AND TEST 4-1/2"TBG BY 7"CASING LINER TOP PACKER -250 PSI LOW FOR 5 CHARTED MIN 3500 PSI HIGH FOR 30 CHARTED MIN. PRESSURE BLED DOWN 56 PSI IN THE FIRST 15 MIN,12 PSI IN THE SECOND 15, -SUCCESSFUL TEST -hD TEST EQUIPMENT 04:30 - 06:30 2.00 CASING P RUNPRD DISP WELL TO 8.8 BRINE PUMP 50 BBL VISCOSIFIED 8.8 BRINE( 2.5#/BBL FLOZAN,5%DEEP CLEAN)&50 BBLS OF 8.8 BRINE(10%DEEP CLEAN) -380 GPM,1400 PSI i-PU-191 K,SO-158K, -CLEAN OUT UNDER SHAKERS -PUMP 355 BBLS 8.8 BRINE @ 9 BPM,1800 PSI ICP/1390 PSI FCP MONITOR WELL F/10 MIN(STATIC) 06:30 - 09:00 2.50 CASING P RUNPRD SLIP&CUT EDRILL LINE(12 WRAPS-94') 09:00 - 13:30 4.50 CASING P RUNPRD POOH UD DOUBLES F/9,866'T/3,180'MD 13:30 - 15:30 2.00 CASING P RUNPRD RIH W/STD'S 4"DP F/DERRICK F/3,180'T/ 7,400'MD 15:30 - 23:00 7.50 CASING P RUNPRD POOH UD SINGLES F/7,400'MD T/SURFACE Printed 4/8/2013 11:07:52AM Common Well Name:Z-66 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/20/2013 End Date:3/25/2013 1X3-011 MR-C:DRILL(3,384,760.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time:2/26/2013 8:00:00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual @96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 23:30 0.50 CASING P RUNPRD UD PACKER RUNNING TOOL T/PIPE SHED INSPECTED BY WSLAND BAKER REP ON SURFACE TO CONFIRM DOG SET SHEARED 23:30 - 00:00 0.50 RUNCOM P RUNCMP C/O SLIP INSERTS T/4-1/2",MOBILIZE CSG RUNNING EQUIP.T/RIG FLOOR,DRAIN STACK 3/23/2013 00:00 - 01:30 1.50 RUNCOM P RUNCMP CO ELEVATORS PULL SLIP INSERTS,PULL WEAR BUSHING,AND LD SAME 01:30 - 02:30 1.00 RUNCOM P RUNCMP C/O ELEVATORS,MAKE DUMMY RUN WITH TBG HANGER AND MARK, LD SAME. 02:30 - 03:00 0.50 RUNCOM P RUNCMP PJSM W/HALLIBURTON,SLB,DDI ON RUNNING COMPLETION 03:00 - 03:30 0.50 RUNCOM P j RUNCMP PU SLB I-WIRE SPOOLER,TOOLS,CLAMPS TO RIG FLOOR 03:30 - 23:00 19.50 RUNCOM P RUNCMP P _PU AND RIH W/4.5"12.6#13-CR80 VAM TO COMPLETION AS PER TALLY F/SURFACE TO 9682'MD(TAG ON DEPTH) -TEST"I-WIRE"EVERY 25 JTS -PU=151 K,SO=125K 23:00 - 00:00 1.00 RUNCOM P RUNCMP SPACE OUT W/PUP JTS,PU/MU HANGER, DRAIN STACK, 3/24/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP LAND HANGER,-RUN IN LOCK DOWN SCREWS -RU CIRC LINE AND TEST TO 4,000 PSI,OK 01:00 - 03:00 2.00 RUNCOM P RUNCMP PJSM,REVERSE CIRC 150 BBLS 80° 9.4 PPG BRINE @ 4 BPM/500 PSI FOLLOWED BY -106 BBLS 80° 9.4 PPG BRINE TREATED W/ CORROSION INHIBITOR FOLLOWED BY -76 BBLS 80°9.4 PPG BRINE -PUMP 5 BBLS DOWN TUBING TO CLEAN RHC-M PLUG PROFILE IN LOWER X NIPPLE. 03:00 - 06:00 3.00 RUNCOM P RUNCMP DROP BALL ROD TO RHC-M AND TEST TBG TO 250 PSI LOW/3500 HIGH AND CHART. —FIRST TEST FAIL CRITERIA, -PUMP BACK UP AND RETEST, FAILED CRITERIA -BLEED BACK PRESSURE TO ZERO AND RETEST 250 PSI LOW/3500 HIGH AND CHART, SUCCESSFUL TEST. 06:00 - 07:00 1.00 RUNCOM P RUNCMP TEST 4 1/2"X 7"ANNULUS AND PACKER,250 PSI LOW/3500 PSI HIGH AND CHART, SUCCESSFUL TEST 1-WO APPROVAL FROM TL. 07:00 - 07:30 0.50 RUNCOM P RUNCMP j BLEED OFF TBG PRESSURE AND SHEAR DCR VALVE. CONFIRM BBLS PUMPED TO BBLS BLED BACK,OK. -PUMP RATE DOWN TBG 3BPM @ 1150 PSI, DOWN ANNULUS 3BPM @ 1100 PSI. 07:30 - 10:00 2.50 RUNCOM , P RUNCMP PULL LANDING JT, -DRY ROD IN TWC -INSTALL LANDING JT -CHART TEST BELOW TWC 250 PSI 5 MIN LOW/30 MIN 3500 PSI HIGH,OK. -CHART TEST ABOVE TWC 250 PSI 5 MIN LOW/30 MIN 3500 PSI HIGH,OK. 10:00 - 15:00 5.00 RUNCOM P ' ' RUNCMP NIPPLE DOWN BOP -DSA,SPACER SPOOL -SKID BOP -PULL RISER. Printed 4/8/2013 11:07:52AM • forth menc2-7AU 4-1113- Pale Operation Summary Report Common Well Name:Z-66 AFE No Event Type.COM-ONSHORE(CON) Start Date 3/20/2013 End Date 3/25/2013 X3-011 MR-C:DRILL(3,384,760.00) Project:Prudhoe Bay Site:PB Z Pad Rig Name/No.:DOYON 25 Spud Date/Time-2/26/2013 8.00.00AM Rig Release:3/25/2013 Rig Contractor:DOYON DRILLING INC. UWI: Active datum:Z-66 actual©96.10usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 20:30 5.50 RUNCOM P RUNCMP PU/INSTALL XMAS TREE -FMC REP TEST VOID 250 PSI LOW 5 MIN, 5000 PSI HIGH 30 MIN,OK i-INSTALL LUBRICATOR AND CHART TEST 250 PSI LOW/3500 HIGH 5 MIN -REMOVETWC 20:30 - 00:00 3.50 RUNCOM P RUNCMP RU TO FREEZE PROTECT -PJSM,CHART TEST LINES AND INNER ANNULUS VALVES 250 PSI LOW/3500 PSI HIGH -REVERSE 74 BBL 80°DIESEL,1.5 BPM/2000 PSI. -STOP PUMPING AND ALLOW TO U-TUBE 3/25/2013 00:00 - 01:00 1.00 RUNCOM P RUNCMP ALLOW DIESEL TO U-TUBE -RD TBG CIRC LINES IN SUB 01:00 - 04:30 3.50 RUNCOM P RUNCMP INSTALL BPV,TEST BPV,INNER OA VALVE ✓ _ 250 PSI LOW/3500 PSI OK 04:30 - 06:00 1.50 RIGD P RUNCMP RIG DOWN TEST LINES, RELEASE RIG 06:00 HRS Printed 4/8/2013 11:07:52AM N O i 17MN14 sagassoaa. E i-rnlm o-n.EyA !!! EAo WW, ' o�i 3gco mmm Wammm WOiSWrm 'Wmmm WON.ONEOf. . . ....W Oita... ... 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Dispatched To: Christine Shartzer Well No Z-66PB1 Date Dispatched: 25-Mar-13 Installation/Rig Doyon25 Dispatched By: E.Greblova Data No Of Prints No of CDs Surveys 2 1 aa Received By: ' JAHN Please sign and return to: Hector Echeto Drilling&Measurements DSM 2525 Gambell Street,Suite 400 Anchorage,Alaska 99501 hecheto(&.slb corn Fax:907-561-8317 LWD Log Delivery V1.0,01/22/2010 Hunt, Jennifer L (DOA) From: Lastufka, Joseph N [Joseph.Lastufka@bp.com] Sent: Monday, May 06, 2013 2:34 PM To: Hunt, Jennifer L (DOA) Cc: Ramos, Tania ((Udelhoven Oilfield System Services (UOSS)) Subject: PBU Z-66/ PTD#212-195 Hi Jennifer, Please reference the following well: Well Name: PBU Z-66 Permit#: 212-195 API #: 50-029-23482-00-00 Jw Date of Test: 5/04/2013 Type of Test: IPT (Initial Production Test) Choke Size: 120 Choke Unit. 64ths Production Method: Flowing Duration (Hours Tested): 4 Top Reference (Top Perf MD): 10126' Bottom Reference (Bottom Perf MD): 12697' Tubing Flowing (Pressure). 400 Casing Pressure: 1540 Total Test (Rate f/O, W, G): 550/ 11 / 1752 24-Hour Rate (0, W, G): 3299/63/ 10511 Gravity (Oil, API): 26.3 GOR (Gas-Oil Ratio): 3186 This well began Production on Method of Operations on this date: May 1, 2013 RBDMS MAY - 7 2013 \ OF T I 7 s7 THE STATE Alaska Oil and Gas f�. --�_����M °fALASKA . . - == C©rise> Vati011 s�dn wh GOVERNOR SEAN PARNELL 333 West Seventh Avenue OFD Anchorage, Alaska 99501-3572 Main: 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, Prudhoe Bay Oil Pool, PBU Z-66 BP Exploration(Alaska), Inc. Permit No: 212-195 Surface Location: 4295' FSL, 2817' FEL, SEC. 19, Ti 1N, R12E, UM Bottomhole Location: 685' FSL, 971' FEL, SEC. 24, T11N, R11E, 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 A__t6 DATED this day of January, 2013. cc: Department of Fish& Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COMA ,ON �� 9 2012 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.Specs 'Vw s rsed for: 0 Drill. 0 Lateral 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed Gas 0 Gas Hydrates 0 Redrill 0 Reentry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Geothermal 0 Shale Gas 2.Operator Name: 5.Bond 0 Blanket 0 Single Well A 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193. PBU Z-66- 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD • 13594' TVD 9013'. Prudhoe Bay/Prudhoe Bay. 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number). Surface. ADL 028262&028245' 4295' FSL,2817'FEL, Sec 19,T11N, R12E, UM Top of Productive Horizon 8.Land Use Permit: 13.Approximate Spud Date: 3242' FSL,2176' FEL, Sec.24,T11N, R11 E, UM February 24,2013• Total Depth 9.Acres in Property: pv-8 14 Distance to Nearest Property: 685'FSL, 971' FEL, Sec.24,T11N, R11 E, UM 2660— /V-II i� I 2650' 4b Location of Well(State Base Plane Coordinates-NAD 27). 10.KB Elevation above MSL: • 103.15' feet 15.Distance to Nearest Well Open Surface: x 599861 y-5959100 Zone- ASP4 GL Elevation above MSL: . 56.2' feet to Same Pool: 180' 16.Deviated Wells: Kickoff Depth. • 300' feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) 1..b II2o` Maximum Hole Angle: • 97 degrees Downhole: 3895- 3$Sb Surface: 369 29S-9 101 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length MD 70,A0_ dItY-r) TVD (including stage data) 42" 20" 94# H-40 108' Surface 108' Surface 108' 260 sx Arctic Set(Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3599' ,Surface 3599' Surface 3128' 1346 sx DeepCrete,408 sx Class'G' 8-3/4" 7" 26# L-80 VamTop 9872' Surface 9872' Surface_ 8613' 489 sx Lite Crete, 184 sx Class'G' 6-1/8" 4-1/2" 12.6# 13Cr80 , Hydril 3872' 9722' 13594', 8478' _ 9013' Uncemented Slotted Liner,Swell Packers 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effective Depth MD(ft). Effective Depth 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: '0 Property Plat 0 BOP Sketch • 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 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 Zach Browning;564-4664 Printed Name Ken Allen Title Engineering Team Leader Email Zachary.Browning@bp.rom Si•nature Z,,..d 4 Phone 564-4366 Date /� // /2_ Commission Use Only Permit To Drill API Number Permit Appro I See cover letter for Number: Z( 9 5 50- O Z9- Q3�/$'•� - OO-00 I( � 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 Id 41- j� contained shales: Other: 35a�/�S� `J 6 �C� ~ /� Samples Req'd ❑Yes I'No Mud Log Req'd: 0 Yes [f-No pa aTj� f`y,.s,,,,e � O -- /000 H2S Measures: Elf Yes 0 No Directional Survey Req'd: E 'Yes 0 No ,L&-L ZO AAC zs33 E3cing exception req'd: 0 Yes 'No inclination-only svy Req'd. 0 Yes lallo i APPROVED BY APPROVED BY ilf COMMISSIONER THE COMMISSION Date /14 -7./.......•> Form 10-400eR. 10p12J I termit is valid for 24 months from the date of approval(20 C 25.005(g)) Submit Form and Attachments In Duplic 0, ' To: Alaska Oil & Gas Conservation Commission From: Zachary H. Browning, ODE Date: December 18, 2012 Re: Z-66 Permit to Drill The planned Z-66 well is currently scheduled to be drilled by Doyon 25 in February 2013. The grassroots well is a horizontal Ivishak producer. This well will be drilled by Doyon 25 using their 5000 psi four presenter BOP stack (3 rams and an annular). The BOP rams will be tested to 3500 psi and the annular will be tested to 3500 psi. A detailed operations summary is included with the permit application. Below is a brief summary of planned drilling operations: 1. Move in Doyon 25 and function test diverter. 2. Drill 12-1/4" surface hole to 3599 ft MD. 3. Run 9-5/8" surface casing and cement to surface. 4. Nipple up BOPE and test. 5. Pressure test surface casing. Drill out the shoe and perform LOT. 6. Drill 8-3/4" intermediate hole to top of the resen.oir at 9872 ft MD. 7. Run 7" casing and cement to 650 ft TVD above NA and pressure test. 8. Drill out of intermediate shoe and perform FIT. 9. Drill 6-1/8" horizontal production hole through Zone 4 of the Ivishak to TD at 13,594 ft MD. 10. Run a 4-1/2" cementless swell packer/sliding sleeve production liner. 11. Run 4-1/2" completion tubing. Sting into liner tieback sleeve and set production packer. 12. Pressure test the tubing and the inner annulus. 13. Rig down and move off the well. In addition to a planned well summary, a directional plan and proposed completion diagram is attached to the permit application. If there are any questions concerning information on Z-66, please do not hesitate to use the contact information below. Zachary Browning Office: 907-564-4664 Cell: 208-301-2214 Email: Zachary.Browninga@bo.com Z-66 PTD Page 1 12/18/2012 Planned Well Summary Well r Z-66 Well Producer Objecet tive Nishak• Current Status Grass Roots Well -Conductor Currently Installed Estimated Start Date: 02/24/2013 Time to Complete: 36.5 Days Surface Northing Easting Offsets TRS Location 5959100 599861 985' FNL/2816' FEL 11N 12E sec 19 Northing Easting TVDss Offsets TRS Tgt 1 5958044 595640 -8505' 1986' FNL/2097' FEL 11N 11E sec 24 TSGR Tgt 2 5957992 595562 -8675' 2037' FNL/2176' FEL 11N 11E sec 24 TSAD Productio 5957253 595135 -8810' 2771' FNL/2613' FEL 11N 11E sec24 n Tgt 3 BHL 5955450 596800 -8810' 685' FSL /971' FEL 11N 11E sec 24 Planned KOP: -300' MD/196.9' TVDss Planned ' 13594' MD/8910' TVDss TD: Rig: I Doyon 25 GL-RT: 47.0' RTE (ref MSL): 103.2'- Directional — Schlumberger P18 KOP: 300' MD Maximum Hole Angle: —39.63° in the 8-3/4" intermediate section 96.96° in the 6-1/8" production section Close Approach Wells: Z-66 well plan fails Major Risk Anti-collision with the exploration well Highland State#1. This well is abandoned with cement and has been Minor Risked to pass 1:200 rule Survey Program: Surface' to —1400' MD = GYD-GC-SS (single shot gyro) —1400' MD to TD = MWD+IFR+MS Nearest Property Line: 2650' - PBU boundary Nearest Well within Pool: —180' -from Z-33A a Z-66 PTD Page 2 12/18/2012 Formation Tops & Pore Pressure Estimate (SOR) Estimated Depth Fluid Most Likely Formation Formation Top Uncertainty Type Pore Pressure (TVDss) (+/-TVD ft) (for sands) (EMW ppg) G1 255 ± 20 No 8.40 SV6 1020 ± 20 No 8.40 EOCU 1590 ±20 No 8.40 SV5 1665 ± 20 No 8.40 BPRF 1850 ± 20 No 8.60 Hydrates _ _ _SV4 1785 ± 30 below BPRF 8.60 SV3 2255 ± 30 Hydrates 8.60 SV2 2455 ± 30 Hydrates 8.60 SV1 2750 ± 30 Hydrates 8.60 9 5/8"surf csg 3025 ± 30 Wet 8.60 UG4 3065 ± 30 Wet 8.70 UG4A 3110 ± 30 Wet 8.70 UG3 3445 ± 30 Wet 8.70 UG1 3855 ± 30 Wet 8.70 UG_Ma 4165 ± 30 Wet 8.70 UG_Mb1 4215 ± 30 Wet 8.70 UG_Mb2 4275 ± 30 Wet 8.70 UG_Mc 4370 ± 30 Heavy oil 8.70 SB_Na _ 4445 ± 30 Wet 8.70 SB_Nb 4475 ± 30 Oil 8.70 SB_Nc 4500 ± 30 Wet 8.70 SB_Ne 4515 ± 30 Wet 8.70 _ SB_OA 4640 ± 30 Oil 8.70 SB OBa 4705 ± 30 Oil 8.70 SB_OBb_ 4735 ± 30 Wet 8.70 SB_OBc 4785 ± 30 Wet 8.70 SB_OBd 4835 ± 30 Wet 8.70 SB_OBe 4905 ± 30 Wet 8.70 SB_OBf 4960 ± 30 Wet 8.70 SB_OBf_Base 5010 ± 30 No 8.70 CM2 5345 ± 30 No 8.70 Top 5900 ± 30 Poss O&GCM Overpressure 9.50 CM1 5940 ± 30 Poss O&GCM 10.00 TLBK 6230 ± 30 Poss O&GCM 10.00 Fault#1 Highland Fault 6530 ± 150 MD 10.00 THRZ Faulted ± 30 Poss O&GCM 10.00 TKLB Faulted ± 30 Poss O&GCM 10.00 TKC4** Faulted ± 30 Oil Possible * 10.00 TKB/ LCU** Faulted ± 30 Oil Possible * 10.00 TKA4** Faulted ± 30 Oil Possible * 10.00 TMLV** 6630 ± 30 Poss O&GCM 10.00 TKNG 7270 _ ± 30 Poss O&GCM 10.00 TJG 7300 ± 30 Poss O&GCM 10.00 TJF 7620 ± 30 Poss O&GCM 10.00 " Z-66 PTD Page 3 12/18/2012 TJE 7860 ± 30 Poss O&GCM 10.00 TJD 8085 ± 30 Poss O&GCM _ 10.00 TJC 8260 ± 30 Poss O&GCM _ 10.00 TJB 8365 ± 30 Poss O&GCM _ 10.20 TJA 8420 ± 30 Poss O&GCM 10.20 TSGR 8505 ± 30Yes Gas 8.53 7" intermed csg 8510 ± 30 Yes Gas 8.53 TSHU 8530 ± 30 Yes Gas 8.51 TEIL 8630 ± 30 Yes Gas 8.44 TSAD(46P) 8675 ± 30 Gas or Inj. Water 8.40 45N 8700 ± 30 Gas or Inj. Water 8.39 44N 8730 ± 30 Gas or Inj. Water 8.36 43N 8750 ± 30 Gas or Inj. Water 8.35 PGOC 8762 ± 30 Gas or Inj. Water 8.34 Yes Oil/Gas or inj 42N 8780 ± 30 wtr 8.31 41N 8810 ± 30 Yes Oil/Gas 8.31 41P 8825 ± 30 Yes Oil/Gas 8.31 Invert(41P1 8850 ± 30 Yes Oil/Gas 8.31 Revert(41P) 8810 ± 30 Yes Oil/Gas 8.31 Invert 2 (41P) 8850 ± 30 Yes Oil/Gas _ 8.31 Revert 2 (41P) 8840 ± 30 Yes Oil/Gas 8.31 31N Revert2 8880 ±30 Yes Oil/Gas 8.30 POWC 8885 ± 30 water 8.31 TD 8910 ± 30 water 8.31 Casing/Tubing Program Hole Liner/ Wt/Ft Grade Conn Burst Collapse Length Top Bottom Size Tbg O.D. (psi) (psi) MD/ TVDss MD/TVDss 42" 20" 94 H-40 - _ 1530 520 108' Surface 108'/4.85' ' 12-1/4" 9-5/8" 40# L-80 BTC-M 5750 3090 3599' Surface 3599'/3025' 8-3/4" 7" 26# L-80 VamTop 7,240 5,410 9872' _ Surface 9872'/8510' 6-1/8" 4 1/2" 12.6# 13Cr-80 Hydril 8,430 7,500 3872' 9722/8375 13,594'/8910' 521 (-150' lap) 9727'/8379.7' Tubing 4 %" 12.6# 13Cr-80 VamTop 8,430 7,500 9727' Surface (-5' into liner TBS) v Z-66 PTD Page 4 12/18/2012 Mud Program Surface Hole Mud Properties: Drillplex AR 12-1/4" Hole Section Density LSYP YP API FL Chlorides Funnel Depth Interval Viscosity 2x3-6 rpm Ib/100 ft2 m1/30min mg/I ppg sec/qt 0'-3599' MD To Section TD 8.8- 9.4w 30-50 45-80 NC <1000 10.8 60-120 Intermediate Mud Properties: LSND 8-3/4" hole section Depth Interval Density PV YP API FL HTHP FL MBT (PPg) pH 3599'-6492' MD To -500' above 9.0 - 9.5 ` 10 - 18 18 -28 <6 NC <18 9 - 10 Overpressure _ 6492'-9872' MD y 10.2 - 10.410 -22 18 -28 <6 NC <18 9 - 10 To Section TD Production Mud Properties: Water Based Polymer Fluid (PowerPro) 6-1/8" hole section Low Shear PV YP Depth Interval D(ppgjy (cp) (Ib/100ft2) API FL Rate MBT pH Viscosity 9872'-TD MD 8.8-8.9 " <12 10-20 >10 >15000 <4 8 - 9.5 Logging Program 12-1/4"Surface: Sample Catchers - not required for surface hole Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 8'/4" Intermediate: Sample Catchers -as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers -as required by Geology Drilling: Dir/GR/Res/Neu/Den Open Hole: None Cased Hole: None Z-66 PTD Page 5 12/18/2012 Cement Program Casing Size 9-5/8" 40#, L-80 Surface Casing Lead: Open hole volume + 250% excess through permafrost and 40% excess below permafrost. Basis: Port collar used if hole conditions dictate Lead TOC: Surface Tail: Open hole volume + 40% excess + 80 ft shoe track Tail TOC: -1000 ft MD above casing shoe Total Cement Lead 445.8 bbls, 2503 cuft, 1346 sks of 11.0 ppg DeepCRETE, Yiels1.86 ft3/sk Volume: Tail 84.2 bbls, 472.7 cuft, 407.5 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Casing Size 7" 26#, L-80 Intermediate Casing Lead: Open hole volume + 40% excess Basis: Lead TOC: 650 ft TVD above NA, -1000 ft MD below surface shoe Tail: Open hole volume+ 40% excess + 80 ft shoe track Tail TOC: -1000 ft MD above casing shoe Total Cement Lead 160.2 bbls, 899.5 cuft, 488.9 sks of 11.0 ppg LiteCRETE, Yield: 1.84 ft3/sk Volume: Tail 40.56 bbls, 212.8 cuft, 183.5 sks of 15.8 ppg Class G, Yield: 1.16 ft3/sk Casing Size 4.5" 12.6#, 13Cr-80 Production Liner Basis: NA-Swell packer/ sliding sleeve completion Surface and Anti-Collision Issues Surface Shut-in Wells: There are no wells requiring shut-in due to sub-surface anti-collision or well house removal to move Doyon 25 over the Z-66 conductor slot. Hydrogen Sulfide • Z-Pad is considered an H2S site. Recent H2S data from the pad is as follows: Well Name H2S Level Date of Reading #1 Closest SHL Well H2S Level Z-20 18 ppm 2/8/2012 #2 Closest SHL Well H2S Level Z-46 20 ppm 6/20/2012 #1 Closest BHL Well H2S Level Z-06A 6 ppm 6/21/2012 #2 Closest BHL Well H2S Level Z-67 80 ppm 5/5/2012 Max. Recorded H2S on Pad/Facility Z-100 120 ppm 2/7/2010 Other Relevant H2S Data H2S Levels of 0-120 ppm have been recorded at Z-pad Z-66 PTD Page 6 12/18/2012 Faults Formation Where Encounter Fault MD Intersect TVDss Throw Direction Uncertainty Lost Circ Intersect and Magnitude Potential Fault#1 Highland State Fault 7,684.0 6,530.0 SW 400 ft. +/-100 ft. MD Low (uphole penetration) Fault#2 (Ivishak) 12,500.0 8,842.0 West 10-20 ft. +/-100 ft. MD Low Fault#3 (not penetrated) n/a n/a SW 10-20 ft. +/-100 ft. Low Fault#4 (not penetrated) n/a n/a North 10-20 ft. +/-100 ft. Low Fault#5 (not penetrated - Highland State Fault south of n/a n/a SW 400 ft. +/-100 ft. Low Ivishak target polygon) Drilling Waste Disposal • There is no annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at e DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul Class I waste to DS-04 and/or Pad 3 for disposal/ Contact the GPB Environmental Advisors (659-5893)f/guidance. Well Control The 12-1/4" surface hole will be drilled with a diverter. The 8-3/4" intermediate and 6-1/8" production hole will be drilled with well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3500 psi. BOP test frequency for Z-66 will be 14 days with function test every 7 days. Except in the event of a significant operational issues that may affect well integrity or pose safety concerns, an extension to the 14 — day BOP test period should not be requested. Intermediate Interval Maximum anticipated BHP 3772ipsi at the TSGR at 8505' TVDss (8.53 ppg EMW) Maximum surface pressure 2921 psi (.10 psi/ft gas gradient to surface) 25 bbls with 13.1 ppg frac gradient Kick tolerance Assumes 10.0 ppg pore pressure in the Kuparuk + 0.5 ppg kick intensity and 10.2 ppg MW. Planned BOP test pressure Rams test to 3500 psi/250 psi. Annular test to 3500 psi/250 psi 7" Casing 3500 psi surface pressure Integrity Test—8-3/4" hole LOT after drilling 20'-50' from middle of window 7" Casing The VBRs will be changed to 7" rams to accommodate the 7"casing string. Z-66 PTD Page 7 12/18/2012 Production Interval L Maximum anticipated BHP 3850 psi 9 TD at 8910' TVDss (8.31 ppg EMW) Maximum surface pressure 2959 psi (.10 psi/ft gas gradient to surface) Infinite with >9.4 ppg frac gradient Kick tolerance Assumes an 8.53 ppg max pore pressure in the Sag/Ivishak + 0.5 ppg kick intensity and 8.8 ppg MW. Planned BOP test pressure Rams test to 3,500 psi/250 psi. Annular test to 3,500 psi/250 psi Integrity Test—6-1/8" hole FIT after drilling 20'-50' of new hole, target 12.5 ppg FIT 4-1/2" Liner Top Packer 3500 psi surface pressure Planned completion fluids 9.4 ppg Brine/6.8 ppg Diesel 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'). Procedures/Safeguards with paddle removed: • Fluid levels will be monitored in the pits for both gains and losses while drilling. Alarms will be set to indicate if gain or loss of more than 5 bbls has occurred. • The well will be monitored for flow when the pumps are off at each connection. • Over 50 surface holes have been drilled on Z-pad, including the recent Z-34 and Z-69 wells in 2012, providing a high level of confidence in the ability to drill surface hole on the pad without incident. • The planned 8.8- 9.4 ppg fluid will provide over balance to formation fluid. Z-66 PTD Page 8 12/18/2012 Z-66 General Operational Summary Proposed Drilling Rig Operations: 1. MIRU Doyon 25. Aib* l �iti 3 2. NU diserter spool & riser. Function test the diverter. 3. Take on Drillplex Spud Mud in the pits and stand back enough 4' drill pipe in the derrick to TD the surface interval. 4. MU 12-%" drilling assembly with DIR/GR/RES on bent housing motor. Spud and directionally drill surface hole to the base of the permafrost. A gyro will be needed for the first 1,400'. Perform wiper trip at the base of the permafrost. 5. Drill the remainder of the surface hole to the planned surface hole TD in lower SV1, —40' TVD above the UG4. 6. Circulate bottoms up until hole is clean and POH racking back 4" pipe. If pumping out of the hole is required, trip back to TD and make final trip out on elevators. Lay down BHA. 7. Run and cement the 9-%", 40#, BTC-Mod, L-80 casing with torque rings, displacing cement with mud. Bump plug and hold pressure for 5 minutes. A TAM Port collar is optional for poor hole conditions. 8. ND diserter spool and NU and test casing/tubing head. NU the BOPE configured from top to bottom with annular presenter, 2-7/8" x 5-1/2" VBR, blind/shear, mud cross, and 2-7/8" x 5-1/2"VBR. Test rams and annular @ 250-psi low/ 3500-psi high. 9. Pressure test the 9-%" casing to 250 psi low/ 3500 psi high for 5 minutes low/ 30 minutes high once 500 psi compressive strength has been achieved. G -A130^� 10. MU 8-%"drilling BHA with PDC bit, bent housing motor and DIR/GR/RES/NEU/DEN/PWD and RIH to float collar picking up 4" drill pipe as required to TD the intermediate hole. 11. Drill to within 10' of shoe track and displace well to 9.0 ppg LSND drilling fluid. 12. Drill new formation to 20' below 9-%" shoe and perform LOT. Target a minimum 13.1 ppg EMW for 25 bbl kick tolerance. 13. Drill 8-3/4" intermediate interval to section TD in TSGR at —9872 MD. Weight up drilling fluid using spike fluid maintaining the following density ranges: • 3599 ft MD-6492 ft MD:9.0- 9.5 ppg • 6492 ft MD- 9872 ft MD: 10.2 - 10.4 ppg 14. At TSGR, CBU until hole is clean (minimum 2x) and condition mud as necessary to run 7" casing. 15. Pump out to top Kingak, POH while rolling pump at 2 BPM to TKNG. Once at TKNG, POH on elevators only (if backreaming to get out of open hole is necessary, trip back to TD and POH on elevators final trip out). • MAD pass Kuparuk and Schrader formations as required for NEU/DEN data. 16. Change upper VBR casing rams to 7" casing rams and test to 250 psi low/ 3500 psi high. Z-66 PTD Page 9 12/18/2012 17. RU and run 7", 26#, L-80, VAM TOP casing to TD. Cement the 7" casing to —650' ND above the top of Na. 18. Pressure test the 7" casing to 250 psi low/ 3,500 psi high for 5 minutes low/ 30 minutes high when the plug bumps. 19. Immediately following pressure test, confirm that the OA is open by pumping —5 bbls of drilling fluid down to ensure annulus remains open for freeze protection. Continue to pump 1-2 bbls of drilling fluid down the OA every hour until the lead cement reaches 500 psi compressive strength. 20. Install the 7" casing pack-off through the stack and test to 250 psi low/ 5000 psi high for 5 minutes. 21. Change upper 7"cas,ing rams o VBR casing rams and test to 250 psi low/ 3500 psi high. 22. Freeze-protect the 9-%"x 7" annulus with dead crude, once the lead cement has reached 500 psi compressive strength. 23. MU 6-%" drilling BHA with Insert bit, bent housing motor, and DIR/GR/RES/NEU/DEN. RIH to the landing collar and begin drilling out shoe track. 24. Displace the well to 8.8—8.9 ppg Power-Pro SF fluid prior to fully drilling out shoe track. 25. Drill 20' of new formation and perform the planned FIT to 12.5 ppg. 26. Drill 6-1/8" hole though build and turn and continue per directional plan until ROP slows. Circulate bottoms up and POH on elevators for bit trip. 27. Stand back drilling BHA, change out insert bit with PDC bit. RIH with bent housing motor, and DIR/GR/RES/NEU/DEN and continue drilling to TD—13594' MD. Geo steer as required by onsite geologist. 28. Circulate bottom ups and condition the hole as necessary. Backream to the 7" shoe, MAD passing as required. 29. Trip in hole to TD and circulate/ condition the hole as necessary until shakers clean up. POH on elevators. 30. MU and run 4-W 12.6# 13CR Hydril 521 sliding sleeve/ swell packer liner to TD. 31. Displace water based mud with 8.8 ppg Rheliant mineral oil based mud. Drop a ball behind the required OBM volume and displace with additional OBM to land the ball on the ball seat in the toe of the well. 32. When the ball lands, set liner hanger and liner top packer. Prior to pulling the running tool, perform a pressure test on the liner top packer by testing the 7"casing x drill pipe annulus to 250 psi low/ 3500psi high for 5 min low/30 min high. 33. Pull liner running tool above liner top. Displace well to clean 8.8 ppg Brine. 34. POH, LID the liner running tool. 35. R/U and run a 4-W, 12.6#, 13CR, VAMTOP tubing completion with GLMS. Space out and land the tubing with tubing tail inserted into the liner tieback sleeve. 36. Make up tubing hanger per FMC Rep. Land the tubing hanger, and run in lock down screws. - Z-66 PTD Page 10 12/18/2012 37. Displace tubing and IA to 9.4 ppg brine. 38. Reverse circulate filtered 9.4 ppg brine and corrosion inhibitor into the tubing x casing annulus. 39. Drop ball/rod and set packer and individually test the tubing and annulus to 3,500 psi for 30 minutes. Record each test. 40. Shear the DCK valve. 41. Install TWO and test from above to 250 psi low/ 3500 psi high for 5 minutes each and from below to 250 psi low/ 3500 psi high for 5 minutes low/ 30 minutes high. 42. Nipple down the BOPE. Nipple up the adaptor flange and double master valves and test to 5,000 psi with diesel. 43. RU DSM lubricator and pressure test. Pull TWC. 44. RU circulating lines. Freeze protect the well to —100' MD below the base of permafrost and allow diesel to U-tube reaching equilibrium. 45. Install a BPV. 46. Secure the well. Rig down and Move Off. Planned Post-Rig Operations: Slickline : 1. Pull BPV, Pull Ball, Rod and RHC Plug with slickline. • 2. Pull shear valve and dummies, install GLVs. 3. Open sliding sleeves as required by NWD PE. Flow back and clean up the well. • 4. Close sleeves as needed to attain desired initial arrangement for production. 5. Install flow lines and well house. Z-66 PTD Page 11 12/18/2012 Z-66 Drilling Critical Issues POST THIS NOTICE IN THE DOGHOUSE I. Well Control / Reservoir Pressures: A. Surface Hole: No overpressure is expected in the surface hole and hydrates hake been a minimal concern on the pad. No free gas is present on this side of the Highland State Fault. B Intermediate Hole: Expect up to 10.0 ppg overpressure in the Colville starting at —5441 ft TVDss, —6492 ft MD (includes 500' MD safety factor). Mud weight must be increased to a minimum of 10.2 ppg prior to drilling the Colville overpressure. If the drilled path comes in lower than planned crossing the HSF through the Kuparuk there is a higher risk that there will be overpressure due to the Z-102 injector. The Z-102 well will be shut in prior to drilling to minimize this risk. C. Production Hole: The highest anticipated pore pressure in the production hole will be encountered in the Sag River at 8.53 ppg. The interval will be drilled with a minimum of 8.8 ppg drilling fluid to provide adequate trip margin. Higher pore pressures may exist in the Shublik, but this is a non-permeable formation and is considered an unlikely risk for flow. However gas breakout at surface and gas cut mud have been encountered in the Shublik on both Z-69 and Z-34. Neither well required the drilling fluid to be weighted up to kill the well. Any well flow must be shut-in and discussed per RAPID prior to proceeding. II. Lost Circulation/Breathing A. Surface Hole: Lost circulation is considered a minimal risk if mud properties remain in specification. B. Intermediate Hole: Breathing and/or lost circulation is a possibility due to the Highland State Fault crossing. The Z-67 wellbore crossed the HSF in a very similar position without problems. Breathing is also common in the Colville. The wellbore has been designed with a maximum mud weight of 10.4 ppg• for over balance and wellbore stability.10.4 ppg has historically been considered low enough to help prevent losses and breathing, however, ECD must be carefully managed to further reduce the risk. C. Production Hole: There is one minor fault crossing planned in the production hole, however lost circulation risk is considered moderate due to the proximity with the HSF (350 ft standoff). There are also possible unmapped faults/fractures due to drilling under the HSF shadow. Additionally, be prepared for losses/breathing in the Shublik if fractures exist in the area. This has been an occasional problem across Prudhoe. Z-66 has an increased risk for breathing than most Z-pad wells due to its higher MW. Ill. Kick Tolerance/Integrity Testing A. The 9-5/8" surface casing will be cemented to surface. The 7" intermediate casing will be cemented to —1000' MD below the 9-5/8" casing shoe. The 6-1/8" liner will not be cemented as this is a swell packer / sliding sleeve completion. All casing will be pressure tested to 3500 psi. B. With the planned mud weights, the kick tolerance for the intermediate section is 25 bbls with a 13.1 ppg leak-off, and the production section is infinite with a 9.4 ppg leak-off. If planned LOT/FIT values are not achieved, do not drill ahead without risk assessment and proper authorization. All kick tolerances are calculated based on a 0.5 ppg kick intensity over likely pore pressure. Test Point Test Depth Test type 61W(Ib/gal) 9-%"Shoe 20'-50'from the 9-5/8"Shoe LOT 13.1 ppg minimum(25 bbls) 14.3 ppg target(50 bbls) 7"shoe 20'-50'from the 7"shoe FIT 9.4 ppg minimum(infinite) 12.5 ppg target(infinite) Z-66 PTD Page 12 12/18/2012 IV. Hydrogen Sulfide A. Z-Pad is considered an H2S site; refer to the ADW "Hydrogen Sulfide" SOP for the appropriate operational guidelines. The max recorded H2S readings on the pad were 120 ppm in Z-100 March 2010, Z-20 (closest well at surface) recorded 20 ppm in March 2011. V. Faults Formation Where Encounter TVDss Throw Lost Circ Fault MD Intersect Intersect Direction Uncertainty Potential and Magnitude Fault#1 -Highland State Faun (uphole penetration) 7,677.0 6,530.0 SW 400 ft. +/-100 ft. MD Low Fault#2 (Ivishak) 12,500.0 8,840.0 West 10-20 ft. +/-100 ft. MD Low Fault#3 (not penetrated) n/a n/a SW 10-20 ft. +/-100 ft. Low Fault#4(not penetrated) n/a n/a North 10-20 ft. +/-100 ft. Low Fault#5(not penetrated-Highland State Fault south of Ivishak target n/a n/a SW 400 ft. +/-100 ft. Low polygon) VI. Anti-Collision Issues A. The Z-66 planned well path fails major risk anti-collision with Highland State1 exploratory well in the intermediate and production intervals. The Highland State #1 well is P&A'd with a cement plug in the production hole. It has been minor risked at 1:200 to pass anti-collision. In the unlikely event that Z-66 hits the abandoned Highland State#1 wellbore there is no risk to safety or the environment CONSULT THE Z-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. Z-66 PTD Page 13 12/18/2012 M 0 O)^ mm n� O,-ON N n 0 V•-N MM ONM MoN W o O ma Moo Nm,,o M C? MM m OM ON N W O M 0 M m0 MOO V V N-m V hm M c V 0M Oo)eref V f0 Y)C MM toONg 1N-01(]ma M N o5�ci0 NVOCN-ON 0 0N- m CMON M, � npeto0 d W y W OO m 0 0 ...... 0 0 o 0 0 0 0 0 0 0 0,000.. 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CD 0 00 >Nt ::,-ONCCC u-i — L7mC DN N U a)— 4) C c a W 1 1 1 1 1 1 1 1 1 1 i 1 1 l 1111111111111711M . 1 l ! „ I 1177TIIIIIIIIIIIIIIIIIIIIIIIIIIIIII 0 In 0 In 0 In 0 In o In 0 In 0 In 0 In 0 N- h- CO CO In In V C) C) N N (u VII 00 uogeiedag ailuaj o;allue BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Iv'Z-66(SC)v6 Project: Prudhoe Bay TVD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Reference Site: PB Z Pad MD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Site Error: 0.00ft North Reference: True Reference Well: Plan lvi Z-66(SC)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-66 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#18 Z-66 v6 Offset TVD Reference: Offset Datum Reference Plan#18 Z-66 v6 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 5.00ft Error Model: ISCWSA Depth Range: Unlimited Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,554.69ft Error Surface: Elliptical Conic , Survey Tool Program Date 11/15/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 46.95 1,200.00 Plan#18 Z-66 v6(Plan Z-66) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,700.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 1,200.00 3,599.00 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+IFR+Multi Station 3,599.00 5,100.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 3,599.00 9,872.00 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+ IFR+Multi Station 9,872.00 11,370.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 9,872.00 13,593.89 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+IFR+Multi Station 11/15/2012 9:32:33AM Page 2 of 5 COMPASS 2003.16 Build 73 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Ivi Z-66(SC)v6 Project: Prudhoe Bay ND Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Reference Site: PB Z Pad MD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Site Error: 0.00ft North Reference: True Reference Well: Plan Ivi Z-66(SC)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-66 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#18 Z-66 v6 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) EX HIGHLANDST HIGHLANDST-HIGHLANDST-HIGHLANDST 12,467.22 9,140.00 1,063.18 13,367.60 -11,987.93 FAIL-Major Risk PB Z Pad Plan Ivi Z-51 (NA)v6-Plan Ivi Z-Z51-Plan#2 Z-t 320.16 300.00 143.55 5.21 138.34 Pass-Major Risk Plan Ivi Z-55(SB)v6-Plan Z-55-Plan#4 Z-55 vE 584.82 570.00 15.39 10.56 4.84 Pass-Major Risk Plan Ivi Z-57(ND)v6-Plan Z-57-Plan#4 Z-57 vt 408.01 390.00 142.58 7.39 135.18 Pass-Major Risk Plan Ivi Z-61 (NF)v6-Plan Z-61 -Plan#12d Z-61 359.84 355.00 155.45 6.68 148.77 Pass-Major Risk Plan Ivi Z-62(NC)v6-Plan Z-62-Plan#2 Z-62 vt 510.55 495.00 125.79 8.35 117.56 Pass-Major Risk Plan Ivi Z-71 (SL)v6-Plan Z-71 -Plan#5 Z-71 515.36 505.00 165.82 9.42 156.39 Pass-Major Risk Plan Kup Z-114(27+45)v6-Plan Z-114-Plan#1 2,597.44 2,370.00 307.55 70.50 239.41 Pass-Major Risk Plan Sch Z-202(NB)v6-Plan Z-202-Plan#2 Z4 295.65 275.00 140.80 5.33 135.47 Pass-Major Risk Plan Sch Z-211 (SJ)v6-Plan Z-211-Plan#5 Z-2 528.53 510.00 135.66 9.63 126.04 Pass-Major Risk Plan Sch Z-213(NL)v6-Plan Z-213-Plan#3 Z-2 358.71 340.00 221.83 6.47 215.37 Pass-Major Risk Plan Sch Z-214(SK)v6-Plan Z-214-Plan#2 Z-'; 389.86 370.00 149.78 7.05 142.73 Pass-Major Risk Plan Sch Z-215(SH)v6-Plan Z-215-Plan#2 Z-'; 395.14 375.00 89.78 7.14 82.64 Pass-Major Risk Plan Sch Z-216(NI)v6-Plan Z-216-Plan#2 Z-2 354.01 335.00 189.05 6.38 182.67 Pass-Major Risk Plan Sch Z-218(NE)v6-Plan Z-218-Plan#2 Z 402.96 385.00 150.04 7.30 142.75 Pass-Major Risk Z-01-Z-01 -Z-01 2,354.54 2,165.00 207.59 57.74 151.59 Pass-Major Risk Z-01-Z-01A-Z-01A 2,354.54 2,165.00 207.59 57.90 151.44 Pass-Major Risk Z-01-Z-01 APB1 -Z-01 APB1 2,354.54 2,165.00 207.59 57.90 151.44 Pass-Major Risk Z-01-Z-01APB2-Z-01APB2 13,592.74 12,010.00 305.10 181.63 128.83 Pass-Major Risk Z-01-Z-01 B-Z-01 B 2,354.54 2,165.00 207.59 57.74 151.59 Pass-Major Risk Z-02-Plan Z-02B-Plan#3 2,400.98 2,190.00 214.52 62.08 154.23 Pass-Major Risk Z-02-Z-02-Z-02 2,401.71 2,200.00 214.55 61.96 154.38 Pass-Major Risk Z-02-Z-02A-Z-02A 2,403.65 2,195.00 214.62 62.06 154.39 Pass-Major Risk Z-02-Z-02BXX-Z-02BXX 2,401.71 2,200.00 214.55 62.12 154.23 Pass-Major Risk Z-03-Z-03-Z-03 2,467.22 2,250.00 138.90 62.35 78.83 Pass-Major Risk Z-03-Z-03A-Z-03A 2,467.22 2,250.00 138.90 62.35 78.83 Pass-Major Risk Z-04-Z-04-Z-04 2,520.88 2,295.00 219.23 63.57 157.73 Pass-Major Risk Z-04-Z-04A-Z-04A 2,520.13 2,285.00 219.21 63.53 157.73 Pass-Major Risk Z-05-Plan#3 Z-05APB1 -Plan#3 2,562.42 2,325.00 221.37 67.21 156.31 Pass-Major Risk Z-05-Plan#4 Z-05A-Plan#4 2,562.42 2,325.00 221.37 67.21 156.31 Pass-Major Risk Z-05-Z-05-Z-05 2,562.42 2,325.00 221.37 67.21 156.31 Pass-Major Risk Z-06-Z-06-Z-06 2,628.50 2,375.00 228.75 68.31 162.71 Pass-Major Risk Z-06-Z-06A-Z-06A 2,627.15 2,370.00 228.71 68.25 162.72 Pass-Major Risk Z-07-Z-07-Z-07 2,697.91 2,320.00 367.21 81.67 293.69 Pass-Major Risk Z-07-Z-07A-Z-07A 2,700.95 2,320.00 367.16 81.60 293.61 Pass-Major Risk Z-07-Z-07B-Plan 7 2,700.95 2,320.00 367.16 81.60 293.61 Pass-Major Risk Z-08-Z-08-Z-08 2,700.08 2,405.00 214.47 76.32 140.55 Pass-Major Risk Z-08-Z-08A-Z-08A 2,702.46 2,405.00 214.16 75.81 140.66 Pass-Major Risk Z-09-Z-09-Z-09 2,869.21 2,565.00 213.31 54.17 159.36 Pass-Major Risk Z-09-Z-09A-Z-09A 2,868.04 2,555.00 213.28 54.12 159.37 Pass-Major Risk Z-102-Z-102Z-102-Z-102-Z-102 7,364.55 8,725.00 717.45 365.57 390.10 Pass-Major Risk Z-103-Z-103-Z-103 2,111.55 2,035.00 163.79 47.53 117.69 Pass-Major Risk Z-103-Z-103PB1 -Z-103PB1 2,111.55 2,035.00 163.79 47.53 117.69 Pass-Major Risk Z-103-Z-103PB2-Z-103PB2 2,111.55 2,035.00 163.79 47.53 117.69 Pass-Major Risk Z-108-Plan Z-108A v5-Plan#2 Z-108A 2,349.99 2,105.00 422.35 58.34 370.31 Pass-Major Risk Z-108-Plan Z-108APB1 v5-Plan#2 Z-108APB1 2,349.99 2,105.00 422.35 58.26 370.21 Pass-Major Risk Z-108-Z-108Z-108-Z-108-Z-108 2,349.99 2,105.00 422.35 58.35 370.32 Pass-Major Risk Z-11-Z-11-Z-11 1,928.23 1,835.00 182.52 39.99 143.45 Pass-Major Risk Z-11-Z-11A-Z-11A 1,928.23 1,835.00 182.52 39.99 143.45 Pass-Major Risk Z-112-Z-112Z-112-Z-112-Z-112 2,351.08 2,150.00 278.39 60.62 221.67 Pass-Major Risk Z-112-Z-112PB1 -Z-112PB1 2,351.08 2,150.00 278.39 60.62 221.67 Pass-Major Risk 11/15/2012 9:32:33AM Page 3 of 5 COMPASS 2003.16 Build 73 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan lvi Z-66(SC)v6 Project: Prudhoe Bay TVD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Reference Site: PB Z Pad MD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Site Error: 0.00ft North Reference: True Reference Well: Plan lvi Z-66(SC)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-66 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#18 Z-66 v6 Offset TVD 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 Z-112-Z-112PB2-Z-112PB2 2,351.08 2,150.00 278.39 60.62 221.67 Pass-Major Risk Z-113-Z-113-Z-113 414.50 405.00 170.39 6.83 163.56 Pass-Major Risk Z-113-Z-113PB1 -Z-113PB1 414.50 405.00 170.39 6.99 163.41 Pass-Major Risk Z-115-Z-115-Z-115 337.13 325.00 162.55 5.51 157.06 Pass-Major Risk Z-12-Z-12-Z-12 1,863.53 1,780.00 188.92 38.43 151.24 Pass-Major Risk Z-13-Z-13-Z-13 1,793.43 1,720.00 178.79 33.87 145.52 Pass-Major Risk Z-13-Z-13A-Z-13A 1,796.97 1,715.00 178.87 33.98 145.52 Pass-Major Risk Z-13-Z-13APB1 -Z-13APB1 1,796.97 1,715.00 178.87 33.98 145.52 Pass-Major Risk Z-14-Z-14-Z-14 1,726.46 1,665.00 164.08 33.87 130.75 Pass-Major Risk Z-14-Z-14A-Z-14A 1,726.46 1,665.00 164.08 33.87 130.75 Pass-Major Risk Z-14-Z-14B-Z-14B 1,726.02 1,655.00 164.07 33.85 130.75 Pass-Major Risk Z-15-Z-15-Z-15 1,547.51 1,500.00 175.87 27.69 148.39 Pass-Major Risk Z-16-Z-16-Z-16 1,464.21 1,435.00 58.27 33.75 25.44 Pass-Major Risk Z-16-Z-16A-Z-16A 1,464.21 1,435.00 58.27 33.75 25.44 Pass-Major Risk Z-17-Z-17-Z-17 1,479.00 1,445.00 136.28 25.49 110.99 Pass-Major Risk Z-18-Z-18-Z-18 1,317.81 1,310.00 38.94 27.76 11.53 Pass-Major Risk Z-19-Z-19-Z-19 724.95 710.00 103.29 17.26 86.04 Pass-Major Risk Z-19-Z-19A-Z-19A 724.32 705.00 103.27 17.24 86.04 Pass-Major Risk Z-20-Z-20-Z-20 822.20 810.00 70.10 14.21 55.88 Pass-Major Risk Z-33-Z-33A-Z-33A 13,375.30 11,440.00 179.04 153.36 48.76 Pass-Major Risk Z-34-Z-34-Z-34 587.13 585.00 257.31 9.63 247.68 Pass-Major Risk Z-35-Z-35-Z-35 2,931.63 2,575.00 262.09 54.52 207.57 Pass-Major Risk Z-35-Z-35PB1-Z-35PB1 2,931.63 2,575.00 262.09 54.52 207.57 Pass-Major Risk Z-38-Z-38-Z-38 3,359.27 2,915.00 321.73 69.26 252.62 Pass-Major Risk Z-38-Z-38PB1-Z-38PB1 3,359.27 2,915.00 321.73 69.26 252.62 Pass-Major Risk Z-39-Z-39-Z-39 2,034.38 1,920.00 93.97 42.13 53.67 Pass-Major Risk Z-39-Z-39A-Z-39A 2,034.38 1,920.00 93.97 42.13 53.67 Pass-Major Risk Z-40-Z-40-Z-40 621.05 610.00 117.35 10.83 106.53 Pass-Major Risk Z-46-Z-46-Z-46 773.30 750.00 115.25 13.47 101.91 Pass-Major Risk Z-46-Z-46A-Z-46A 773.30 750.00 115.25 13.47 101.91 Pass-Major Risk Z-50-Z-50-Z-50 777.53 765.00 38.60 12.76 25.87 Pass-Major Risk Z-65-Z-65-Z-65 617.10 605.00 40.10 9.47 30.71 Pass-Major Risk Z-65-Z-65PB1-Z-65PB1 617.10 605.00 40.10 9.47 30.71 Pass-Major Risk Z-67-Z-67-Z-67 3,535.71 3,085.00 318.58 76.02 258.95 Pass-Major Risk Z-69-Z-69-Plan#14 Z-69 417.57 415.00 200.14 7.61 192.53 Pass-Major Risk Z-69-Z-69-Z-69 413.49 410.00 199.61 6.56 193.04 Pass-Major Risk 11/15/2012 9:32:33AM Page 4 of 5 COMPASS 2003.16 Build 73 BP Anticollision Report Company: North America-ALASKA-BP Local Co-ordinate Reference: Well Plan Ivi Z-66(SC)v6 Project: Prudhoe Bay TVD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Reference Site: PB Z Pad MD Reference: Z-66 plan P273 @ 103.15ft(Parker 273) Site Error: 0.00ft North Reference: True Reference Well: Plan Iv'Z-66(SC)v6 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore Plan Z-66 Database: EDM.16-ANC Prod-WH24P Reference Design: Plan#18 Z-66 v6 Offset TVD Reference: Offset Datum Reference Plan#18 Z-66 v6 Filter type: NO GLOBAL FILTER: Using user defined selection&filtering criteria Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 5,000.00 to 13,593.89ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 3,000.00ft Error Surface: Elliptical Conic Survey Tool Program Date 11/15/2012 From To (ft) (ft) Survey(Wellbore) Tool Name Description 46.95 1,200.00 Plan#18 Z-66 v6(Plan Z-66) GYD-GC-SS Gyrodata gyro single shots 1,200.00 2,700.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 1,200.00 3,599.00 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+ IFR+Multi Station 3,599.00 5,100.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 3,599.00 9,872.00 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+ IFR+Multi Station 9,872.00 11,370.00 Plan#18 Z-66 v6(Plan Z-66) MWD MWD-Standard 9,872.00 13,593.89 Plan#18 Z-66 v6(Plan Z-66) MWD+IFR+MS MWD+ IFR+ Multi Station 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) EX HIGHLANDST HIGHLANDST-HIGHLANDST-HIGHLANDST 12,470.29 8,900.00 1,038.45 79.91 1,037.69 Pass-Minor 1/200 11/15/2012 9:40:22AM Page 2 of 9 COMPASS 2003.16 Build 73 Project: Prudhoe Bay Site: PB Z Pad Well: Plan lvi Z-66 (SC)v6 Wellbore: Plan Z-66 From Colour To MD Design: Plan #18 Z-66 v6 1° 47 500 h ,� 500 1000 1000 1500 From Surface to 1500'md i 1500 2000 Scan interval 25 ft �-. 2000 5000 Scale 1 : 30 0, All wells pass major risk ti� by 5000 7000 0 oti \t' 7000 9000 \` ,4410�A 4' 9000 14000 \ 0 e. 1_ /' 330 /�'' 11852\, ---.7,- - '�� 30 % ; 1160 �� ` % � 113 rI w�kIr.it ' ''�r- IIgo �:4/44�� j t" ilbrAi oti & i1T1i ,6 70,3V5' �.�Y* i 41._; tit ► iii sT i -- �V,"--i�! 4� 300 + . ,IV 1 ' r,'�, 1 10 882 a '`•t4,4! 1 24 07 60 �� 11 r.i 10 721( 1 2 '9,1'• 31 .1.8 X12+11 X93.5 1 ' ` t:0V-�'O.. �iijp11"_- h 5$ it:0V— % AI��'�,� 886 / ;i 0 _ >= =�° /�f �i51. `�,��►_. ,a2 ---S„ J tokok -W fir r el i/iiirdp,..,1„ ,;10,,,,........ ,,kyll .0.,.../ v' '�// 1 ���•r��4b �� �•.� y,A ii41 Go,� I�_ ?011itiSliiir 4* �i:.L*✓ /-,. ;‘01111k.-IgiNnt111/1p er,,...11. , I . .p toi &I.,* i r 616 ,.. ......,._., ♦�. ,+ ri + 1.40 9� 4.15 \- • �� p'' ti ,j;0,-_ 270 ` I I.:f+► I .t 90 .295 �\` S" \ Ni318 �1 - V / 2 1365 1 21 ` ' 1 1388 14404 I40 Q 240 \\ \ �11,4 r ti� 120 1►t tiO 5<J"`1 Ilk 80,------ 210 150 100 180 Travelling Cylinder Azimuth (TFO+AZI)[O]vs Centre to Centre Separation [30 ft/in] Project: Prudhoe Bay Site: PB Z Pad Well: Plan Ivi Z-66 (SC)v6 Wellbore: Plan Z-66 From Colour To MD Design: Plan #18 Z-66 v6 47 500 500 — 1000 1000 1500 From 1400'md to 3600'md (9-5/8") 1500 __ 2000 Scan interval 25 ft 2000 5000 Scale 1 : 50 All wells pass major risk 42 5000 7000 ,:' �v — o ,^ 7000 - — 9000 �• C74 ' 4` ,, :' A' 9000 — 14000 L r 330i » - ♦?, wei Vi • .>- �j ,;,�'° g r.} ";,•,_°1A70 4 • • & fif+ , • ..; , ,1 `� *i4 '.± mo . q ' ti si > � 1.r ASO yi li ��� l r�1j�.=r''�II► ► i/11 440490d, ' AVo ms'sAU i��wippi�,y' -119 :A-199-AL �+: opikortitymtif �,300 i- .-��..;+1.��,.�.i�e��N�„ =1 -,,, .' ►l►A ,, '„i► 7 ` s )1,10i -Alp vyi-----aiv-lbza.AhmwaweAwowsvriaip• - . 6,,,f, 4 g 1 4 .40.4.4 ,,,,,,„ ...._,_-.........,:,., 11111401WNWAAIVIIVAti- ,- Ara' 413\x33 , ++� 1452 14 + 270 \ ] , j / 151 1525 15ti...4\'''° ,/ � -\ \ 1143 \ ov �1 - 'ilik-\\--- -- _ _ ��1 A! , • ,..tf,..f osk,- - __•,_ : ,,,iii,,,,,„ 240 ” ', `' ....„ 120 • filit10ik. 4,..,fil 150 \` 210 150 180 Travelling Cylinder Azimuth (TFO+AZI)[0] vs Centre to Centre Separation [50 ft/in] Project: Prudhoe Bay Site: PB Z Pad Well: Plan Wellbore: Plan Zlvi 66Z-66 (SC)v6 From Colour To MD Design: Plan #18 Z-66 v6 47 500 500 1000 _ 1000 1500 From 3600'md (9-518") to 9900'md (7") 1500 2000 Scan interval 25 ft m0 5000 Scale 1 : 100 e Hiland State fails major risk �0 5000 7000 passes risk 1:200 rule 0 /,b� 7000 9000 ,^N' / l9000 14000 ::„.$11:i04010Eroi 1�/��NOIVfttt'U/'1 94'1 ,�d1`;►S _ 330 ::�•• �s% Project: Prudhoe Bay Site: PBZ Pad From Colour To MD Well: Plan lvi Z-66(SC)v6 Wellbore: Plan Z-66 Design: Plan #18 Z-66 v6 47 500 500 1000 1000 1500 1500 2000 From 9800'md (7")to TD 2000 5000 Scan interval 25 ft 5000 7000 Scale 1 : 100 Hiland State fails major risk 7000 --- 9000 passes risk 1:200 ruleo 9000 11500 11500 13000 330 13000 13600 330 / 30 ^� 0 27 4/ V 4 Aid //� I Nli 1 :5 , " ,:,i� 300 11‘ 60 14"ill 10,'011•111 lippli4 3330 •440/111PRIVW4A\ ‘,c, 41111111m04&,4* iiiiheins- .A A .. ,A,,.. , , ,,A i,„gme.„„t,4.,t ',1 ,,270 iiiiiiiinc* holo po ` `;tt. 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'I II 71416\ 7,••••••,..—,..— 1.1111111 ; r-.....____ ---- -7.-_ • . ....",7:-. \144V yr . 1-1 A, -, I o 1 I • — c'...- . J,-- — : I I i ir— ,.,. :F_••• - i •`:-.' ----1 1, ........ 0 ..„._ J / III I \II./ 1 III III I 11 1 .... '—' (:) 111 ,.› wur I -.., E.• :'.. , '.T.' , 2 :] r rraCitrf d. ,... t C. 01 N - GRID C�) > Ii,- I N• T` -' i). SPINE RD 9 ■ ■ 33 ` '• l ��, a ■ ■ 32 ,.tit ( 4 `'._.\:4,v I' t � r 7 ■ ■ 31 +I C W-PAO' 6 ■ ■ 30 ��( 115 ■ ■• 29 Z-PAD 1I11; � t� , 108 • ■ 210i I.4 Ai 4 ■ ■ 28■ 1021 ��� 3 ■ ■ 27 THIS PROJECT N . r 1(;.- • 116i ) IQ2 ■ ■ 104i 1' %./....J.,1 ^ V c. I! II ■ 1141 1 5 31 il 1 ■ U SPARE-A • P-504A ® .. ■ P-5040 .1:1 1 t:1 , k4 .f2JV nO - VICINITY MAP El NTS ■ 21 ■ 22 39 ■ 11 ■ ■ 23 12 ■ ■ 24 13 ■ II 14 • ■ 26 OWIllq� 15 • i SLOT �`•�,r OF 4. ,Ia 16 ■ ■ SLOT 4 P�.• •. ,,..;.4' ♦ VII 17 ■ ■ 101 •'`Gj�.` 1-1•4"- ...I ,iii SURVEYOR'S CERTIFICATE. 18 ■ • I� s*• S I HEREBY CERTIFY THAT I AM • 46 • :.. PROPERLY REGISTERED AND LICENSED 19 • Z-PAD 00 TO PRACTICE LAND SURVEYING IN ki THE STATE OF ALASKA AND THAT 29 ■ 4••1• THIS AS-BUILT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT ' S0 „WM Ichard F, Allison oSUPERVISIONANDTHATALL51i • .a DIMENSIONS AND OTHER DETAILS ARE 68 202 % • 641$ . .4- CORRECT AS OF JULY 02, 2011. III SD 70 B18i gift ESSIG � %), SG 2155 - 113 '<<��«� ��0�`,`� 2161 i 21411 t N69K SL 2 3i I n LEGEND 10055 - 21071 • AS-BUILT CONDUCTOR 68 412i 11 EXISTING WELL CONDUCTOR NOTES: 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, HAD 27. 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. 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: - 34i, 40, 42, 50, 511, 55, 57, 61, 62, 65, 66, 68, 69, 70, 105, 113, 115, 201, 202, 203. 2111, 212, 2131, 214i, 215i, 216i, 2171, 2181, SD, SG, SL, NK F. Robert. CRAM BARNHART hit4. NEC• p x• r JAC08S ."f 7/1/11 b„,A rofto%AM: ISSUE. vRen NM z/ WOA Z-PAD U IJba o WRD PAD EXPANSION seux w 7/1/1116A4D RR 9V01 aAUa1 1111A; ,• . AS-BUILT WELL CONDUCTORS 1 DF 3 OM KR RIK•010 UleNO. DATE REVISION DT Cwc AM.Aau MY 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 511 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 7017'51.634" 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' FSL 61 X= 599,928.50 E= 2,009.98 149'11'26.695" 149.1907486' 55.9' 2,747' 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 14911'28.445" 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 55 X= 599,906.01 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 7017'51.592" 70.2976644' 4,291' FSL 68 X= 600,170.92 E= 1,870.22 149'11'19.683" 149.1888008' 55.9' 2,507' FEL Y=5,959,239.94 N= 1,301.49 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° I 559'' 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' 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 WELL CONDUCTORS: 34i, 40. 42, 50, 511, 55, 57, 61, 62, 65, 66. 68. 69, 70, 105. 113, 115, 201, 202, 203, 2111, 2121, 2131. 2141, 2151, 2161, 2171, 2181. SD, SG, SL, NK F. Robert upAavl BARNHART CHE,z:E)JACOBS b F � G0. yt: 1 7/1/11 p FRB11 WOZ 21 WOA Z PAD SHEET: aSSOC. JOS N�. - WRD PAD EXPANSION et 7/1/11 ISSUE:LW INFc DATION TFB JJ • = 20@. AS—BUILT WELL CONDUCTORS 2 of 3 MI Mt RPM.,4W 1NO DATE REVISION 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= 2,010.19 149'11'20.721" 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 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' S5 9' 4,293' FSL 211iX= 599,995.99 E= 1,870.22 149'11'24.783" 149.1902175' 2,682' FEL. Y= 5,959,240.11 N= 1,141.47 7017'52.969" 70.2980469' 56.4' 4,431' FSL 212i X= 600,163.45 E= 2,010.12 149'11'19.847" 149.1888464' 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= 2,010.05 149'11'23.635" 149.1898986' 56.12,642' FEL Y=5,959,100.25 N= 1,293.88 70'17'51.613" 70.2976703' 56 2' 4,293' FSL 214i X= 600,011.06 E= 1,870.24 149'11'24.343" 149.1900953' 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 70'17'52.992" 70.2980533' 4,433' FSL 2161 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= 2,009.99 149°11'20.281" 149.1889669' 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' S592,762' FEL Y= 5,959,100.11 N= 1,429.03 70'17'51.630" 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 7017'51.621" 70.2976725' 4,294' FSL SG X= 599,935.92 E= 1,870.08 149'11'26.533" 149.1907036' 56'2 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= 2,009.86 149'11'24.075" 149.1900208' 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, 2131, 214i, 215i, 2161. 217i, 2181, SD, SG, SL, NK F. Robert 01A11N• BARNHART , c.o. Øbp JACOBS „reoI k: "'7 1/11 +; DRAMNG SHEET: _gPp p FRB11 WQZ 21 WOA Z—PAD 'I��SSOC. �E WRD PAD EXPANSION so 7/1/1 ISSUED FOR INFORMATION 1F8 i) ae.me„o wo swwxa NO OF 3 M wn. ,,,E r - zea AS—BUILT WELL CONDUCTORS NO. DAZE REVISION BY CHB AwwaAx MAMA wen ....7. ..... .9 1.1.1. ,..... -,...... ---.......-2..,/ 10. -NI) er _.,1 ,L. gen?, 1 v II I I 0 Sid , FI t. 1 -0-- I __ai'! , I CA . . .---q, IT\. .......,—.—) H I _ 1 n , - E • in . 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I Xx--Ai3 1 A.u..•:.i.R. w.•vowN.+ nalt•OS To comm.n no.so..-z: 1 .xxx—•.005 1 WELLHEAD SYSTEM YAM= 07.20-0:1 0 1 ..•..e...Nv....../.m.s•"..` -I•EAEO TgEAOS TO C0✓aN.TO•NI C.1 - I I-5000 X 4 `./16-5000 4Ji.ra. ' r10.O.1..i M:::=7.•iOlo'.'0- T.ORAnNCS IN TNWO..RE PROJC0.ONS INCE-C X' 1 LEQJ.0 07-`•-•i$.....4 y..dp M•p.A .pI•ftom �.W ALL"..OE...T.0LE5.v7T ST..00LE c5 �': ...+0.E0.. 1 A•.N Q.fY...1.4•..l..OI. zs� , 1 20 X „/8 X 7 X ./z OD120M1080698 j .M/K+w O..>•NM9.Mh...r.t..�NA1 I CON.ON iFATEIC.NE '�M$N- LEaWC .01.20.02, Note: Dimensional information reflected on this drawing are estimated measurements only. 28.63" Est. 1 v Oo ono 4-1/16" 5,000# Q p 0 CD to ISU c O 93.38" O Est. (;-1- 4-1/16" 5,000# O 50.75" Est. ,00.2% 4-1/16" 5,000{ rrn BP Alaska SK-011583-03 a CAMERON Neme:Jeanette 4-1-05 # J-6816-3 agile: NorkinN Preeeurc: TREE= 4-1/16" WELLI-EAD= FMC ACTUATOR= Bectric Z- Proposed I" =n NOTES: ***CHROME TBG`** — KB.B_EV= 470' BF.B_EV= 562'0 ' KOP= 300' MaxAngle_ @09 — ax - 97 10900' 20"CONDUCTOR 108' , .- =---1 TBD —9-5/8"TAM PORT COLLAR Datum MD= 10260' I 2000' —4-112"HES X NP,ID=3.813" Datum TV Dss= 8800' -518",404, L-80,BTC-M,ID=8_835" —I 3599' Al 11 4598' TOC-650'TV D above Sb_Na -1000'MD below surface shoe GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID =3.813" 7 TBD 3295 42 KBG-2 DUM RK 1" 4-1/2" X Nipple @ 9608' MD 6 TBD 4603 42 KBG-2 DUM RK 1' 5 TBD 5451 39 KBG-2 DCK2 RK 1" 4 TBD 6092 12 KBG-2 DUM RK 1" 3 TBD 6735 12 KBG-2 DUM RK 1" L 2 TBD 7646 16 KBG-2 DUM RK 1" 1 TBD 8278 2 KBG-2 DUM RK 1 1" I 9547' —14-1/2"HES X NP,D=3-813" 4-1/2"NDPG SINGLE-SENSOR SUB,ID=x.xxx" — 9575' 9607' 7•X 4-1/2'HES TNT PKR I! ><- D=3.870" 9641' 1-14-112'HES X NIP,ID=3.813" 1-1/2'TBG, 12.6#,13-Cr,VT,.0152 bpf,D=3.958" — 9727' 9714' H4-112"HES X NIP,ID=3.813" 9722' 17°X 5'BKR ZXP PKR&Flexlock HGR w/ILBACK SLV,D=4.4" ,----------LIII 7"CSG,26#,L-80,VT HC,.0383 bpf,D=6.276" H 9872' I I 9727' W LE G 11017-14.1 '5Zi I I 8ea: 4-1/2"HES OBM Sw ell Packers @ ►Mi TBD,TBD,TBD',TBD I I ..] TBD,TBD",TBD,&TBD I I 8ea: 4-1/2"HES Sliding Sleeve @ I I TBEY,TBD,TBD',TBD, TBD,TBD,TBD,&TBD I I I I 13509' —1X0 4-1/2"Hydri 521 x 4-1/2"VTI I I 13619' 1BHI Locator Sub 0=3.91"VT I 4-1/2"CEP(Post Rig) H 13523' 3-1/2"HES OBMAnchor Swe®packer VT I--I 13538' 13527' —I XO 4-112'VT x 3-1/2"VT XO 3-1/2"VT box x 4-1/2"IBT pin 1—I 13672' 0 0 13582' —14-1/2'Float Colar BT I 3-1/2"LNR,12.6#,13085 Hydri 521,D=2.992'—I 13594' 1111111111 13593' -J4-1/2"Float Shoe ST 08/221111 KEH Proposed Completion WELL: Z-66 11/05/12 ZHB New Z-66 schematic FERMI!'No: 11/14/12 ZHB Update to depths API No: SECXXTWA'XXN RGEXXE FSL XXXX'FEL XXXX' BP Exploration(Alaska) Bettis, Patricia K (DOA) From: Browning, Zachary H [Zachary.Browning@bp.com] Sent: Monday, December 31, 2012 2:02 PM To: Bettis, Patricia K(DOA) Subject: Z-66 Anticipated pressures Patricia, The correct values for the Z-66 anticipated pressures are as follows: For the Intermediate Interval: Maximum anticipated BHP 3772 psi at the TSGR at 8505'TVDss (8.53 ppg EMW) Maximum surface pressure 2921 psi (.10 psi/ft gas gradient to surface) For the Production Interval Maximum anticipated BHP 3850 psi @ TD at 8910' TVDss (8.31 ppg EMW) Maximum surface pressure 2959 psi (.10 psi/ft gas gradient to surface) Thanks, Zach Browning Rotary Drilling Engineer BP Exploration (Alaska), Inc. W:(907)564-4664 C:(208)301-2214 Zachary.Browning@bp.com 1 OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME Palk 2- (ec PTD# l 9./ qS ? Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ?Ru1/4(.1 POOL: ?r,kc.iho/-_ cs,i ?r ,J Lo, 0,1 Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal 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. 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O C cN- O 0 .a N y a) E I- o a s W a COa 0 Q Q Q s Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. BP Exploration Alaska Inc Well: Z-66 Field: Prudhoe Bay North Slope, Alaska, USA Report Production Array Log Analysis Prepared For : BP Exploration Alaska Inc Logging Date : 01/31/2014 Report Date : 02/07/2014 Submitted by: Waqar Khan Phone: +1(281)575-5051 10200 Bellaire Blvd, Houston, Texas-77072 Email: waqar.khan2@halliburton.com HALLIBURTON DOES NOT GUARANTEE THE ACCURACY OF ANY INTERPRETA TION OF THE LOG DATA, CONVERSION OF LOG DATA TO PHYSICAL ROCK PARAMETERS OR RECOMMENDATIONS WHICH MAY BE GIVEN BY HALLIBURTON PERSONNEL OF WHICH APPEAR ON THE LOG OR IN ANY OTHER FORM. ANY USER OF SUCH DATA, INTERPRETATIONS, CONVERSIONS OF RECOMMENDATIONS AGREES THAT HALLIBURTON IS NOT RESPONSIBLE EXCEPT WHERE DUE TO GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, FOR ANY LOSS, DAMAGES, OR EXPENSES RESULTING FROM THE USE THEREOF BP Exploration Alaska Production Array Log Analysis 1 TABLE OF CONTENTS 1.0 EXECUTIVE SUMMARY ......................................................................................................................... 2 2.0 BACKGROUND AND OBJECTIVES ...................................................................................................... 3 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT .......................................................... 4 4.0 PRODUCTION LOG PROCESSING........................................................................................................ 7 4.1 FLOWING SURVEY ................................................................................................................................. 9 BP Exploration Alaska Production Array Log Analysis 2 1.0 EXECUTIVE SUMMARY Production logging was done in Well Z-66 on January 31st, 2014 using PDS in flowing conditions with the objective to estimate the production profile. As the well is deviated, Resistance Array Tool (RAT) and Spinner Array Tool (SAT) were included in the tool string to accurately estimate the holdup and phase velocities as there can be segregated flow of the three phases due to well deviation. Initially Halliburton had logged the interval but owing to memory sub failure, data wasn’t able to be retrieved. It was decided to re -run the Z-66 PLT with a PDS MAPS toolstring. The flowing PL analysis showed the bottom two sleeves (12697’ – 12701’ and 13100’ – 13104’) contributing 50% of the oil production. The bottom sleeve (13100’ – 13104’) is also the main contributor to the water production, 37%. The reported surface production rates February 1st, 2014 were The estimated flow rates at surface condition while flowing from each of the perforations and the production profile is given in the table below: Perforations Oil Rate Water rate From , ft To , ft STB/D % STB/D % 10325.5 10330.5 0 0.00 125 4.43 10646 10651 52.4 10.52 78.1 2.77 11111 11116.5 28.4 5.70 114 4.04 11295 11299.5 64.4 12.92 523 18.54 11606 11612 45.1 9.05 0 0.00 11831.5 11837 60 12.04 60.4 2.14 12393 12398.5 0 0.00 627 22.22 12696.5 12701.5 123 24.68 259 9.18 13100 13104.5 125 25.09 1035 36.68 Total 498.3 2821.5 BP Exploration Alaska Production Array Log Analysis 3 2.0 BACKGROUND AND OBJECTIVES The objective for running the PL was to identity if it’s possible to shut off sleeves to reduce water cut. BP Exploration Alaska Production Array Log Analysis 4 3.0 WELL INFORMATION AND DATA QUALITY ASSESSMENT Well Z-66 is completed with a sliding sleeve having an ID of 3.813” across the logged interval. The wellbore schematic is presented in the Figure 1. The tool string diagram used for the PL logged is presented in Figure 2. The tool string consisted of the following production logging sensors: Gamma Ray - Casing Collar Locator – Pressure - Resistance Array Tool - Spinner Array Tool – Radioactive Density – Capacitance Water Holdup – Temperature – Caged Fullbore Spinner. The data quality is summarized below TOOL USAGE LOG DESCRIPTION LOG QUALITY REMARKS WELL BORE PARAMETERS QP Well bore pressure Good Down 30 pass has a wavy pr. response TEMP Well bore temperature Good FLUID TYPE FDR Radioactive density tool uses radioactive source and detector to measure density and is a center sample device Good Down 30 pass spikes inconsistently as compared to the other passes CWH Uses capacitance to measure the differences between hydrocarbons and water Good RAT Resistivity Array Tool Good FLUID VELOCITY CFB Caged Fullbore Spinner Good SAT Spinner Array Tool Good . BP Exploration Alaska Production Array Log Analysis 5 Figure 1: Wellbore Schematic BP Exploration Alaska Production Array Log Analysis 6 Figure 2: PL Toolstring BP Exploration Alaska Production Array Log Analysis 7 4.0 PRODUCTION LOG PROCESSING The production log data from the flowing were processed using the PLATO software. The software uses a global probabilistic method for the production log analysis. In this method, known as the Maximum Likelihood method, a well flow model is compared to all available data and improved, by optimization, until the best possible match with the data is obtained. By using this method the result is the most likely interpretation. A comparison between the model and the data is shown in this report and allows the analyst or the reader to determine validity of the answer obtained. Potential sources of discrepancies include tool measurement errors, conflicts between the parameters or conditions that make the underlying empirical models (such as flow regimes) less applicable. The flow regimes were determined, directly from the flow rates and holdups, according to the Taitel- Dukler analytic model. The profile factors, to calculate the true fluid velocity from the apparent velocity, were based on the Reynolds numbers. Solution gas in oil was derived from the correlations (Vasquez-Beggs or Øistein- Glaso). The analysis was performed in six steps: The data preparation to filter the data, compute gradients and error estimates. The calibration of the array tools and full-bore flow meter. The computation of the layered holdup and layered flow -rates. The profile determination to identify the potential producing and/or injecting zones. The computation of the flow rates by global optimization. The computation of surface productions and reporting. BP Exploration Alaska Production Array Log Analysis 8 The water density and viscosity were calculated using a salinity of 20000 ppm. The Craft & Hawkins correlation was used. The oil density and viscosity were calculated using an oil gravity of 27.1 API. The Vasquez & Beggs correlation was used to calculate the solution gas. Viscosity was calculated using the Beggs & Robinson correlation. The Pc and Tc parameters were calculated using the Brown et al. correlation. The gas viscosity was calculated using the Lee Gonzales Eakin correlation. Utilizing the above fluid information, measured down hole oil density, temperature & pressure, the following fluid properties were calculated at well conditions: feet Twf Pwf Bwater water water Boil oil oil °F psi UNITY g/cc cP UNITY g/cc cP 10026.00 230 2562 1.04 .984 .289 1.07 .836 4.21 10377.00 230 2645 1.04 .984 .289 1.07 .836 4.21 10728.00 229 2633 1.04 .984 .290 1.07 .836 4.22 11078.50 229 2625 1.04 .984 .290 1.07 .836 4.22 11429.50 229 2654 1.04 .985 .290 1.07 .836 4.23 11780.50 229 2650 1.04 .985 .291 1.07 .836 4.23 12131.50 228 2638 1.04 .985 .291 1.07 .836 4.24 12482.00 228 2638 1.04 .985 .292 1.07 .836 4.25 12833.00 227 2666 1.04 .986 .294 1.07 .837 4.27 13184.00 225 2644 1.04 .986 .296 1.07 .837 4.30 Tool information The following capacitance tool characteristics were used HydroWater Hz 28626 (Downhole Measurement) HydroHyd Hz 31120 (Surface Estimation) BP Exploration Alaska Production Array Log Analysis 9 4.1 FLOWING SURVEY The raw data from the flowing surve y are presented in the Figures 3 to 8. Figure 3 has the data from conventional production logging sensors. Figure 4 has the same data that was presented in Figure 3 with the addition of the station measurements. To generate this plot, Emeraude software was used which allows overlay of the station measurements and the logging passes in the same track. Plato can only plot the st ation measurement against time. Because the DOWN 30 pass shows an inconsistent response compared to the other passes, it hasn’t been used in the interpretation. The response from the Resistance Array Tool is presented in Figure 5. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values. Only the active sensors were used in the interpretation. Figure 6 shows only the active RAT sensors along with the station measurements. The response from the Spinner Array Tool is presented in Figure 7. Both the full-bore and array spinners show good response across the logged interval. Figure 8 shows the station measurements. From the spinner response, the velocity profile was estimated u sing the slopes calculated from the spinner calibration (Figures 9 and 10). The calibrated RAT response is presented in Figure 11. The estimated SAT velocities and the RAT holdups are used to calculate the flow profile presented in the Figure 12. The final flow profile, after the global optimization, along with the comparison of the measured and theoretical tool values are presented in Figure 13. The production rates at surface conditions estimated from the production log ana lysis are presented in Figure 14 and are summarized in the table below: feet Profile Qp-Water-STP Qp-Oil-STP BFPD BFPD 10325.50 10330.50 Produce 125 0 10646.00 10651.00 Produce 78.1 52.4 11111.00 11116.50 Produce 114 28.4 11295.00 11299.50 Produce 523 64.4 11606.00 11612.00 Produce 0 45.1 11831.50 11837.00 Produce 60.4 60.0 12393.00 12398.50 Produce 627 0 12696.50 12701.50 Produce 259 123 13100.00 13104.50 Produce 1035 125 BP Exploration Alaska Production Array Log Analysis 10 Raw Data - The figure below summarizes the input data recorded at the well site. - Each pass is shown with a fixed predefined color. Figure 3: Input data from the conventional production logging sensors BP Exploration Alaska Production Array Log Analysis 11 Figure 4: Input data from the conventional production logging sensors along with the station measurements. BP Exploration Alaska Production Array Log Analysis 12 The figure below shows the RAT input data. The first track shows the RAT rotation curves for each pass. The next tracks show the RAT data: A curve for each pass for each of the 12 probes. In this well, RAT was run with only 6 sensors and hence only the sensors 1, 3, 5, 7, 9 and 11 are active. The remaining sensors are reading some default values and were not used in the interpretation. Figure 5: Input data from the Resistance Array Tool (RAT) BP Exploration Alaska Production Array Log Analysis 13 Figure 6: Input data from the Resistance Array Tool (RAT) showing just the active sensors along with station measurements BP Exploration Alaska Production Array Log Analysis 14 The figure below shows the SAT input data. The first track shows the SAT rotation curves for each pass. The next track shows the line speed for each pass. The remaining tracks show the array spinner data: A curve for each pass for each of the 6 array spinners, and fullbore spinner. Figure 7: Input data from the Spinner Array Tool (SAT) and conventional spinners BP Exploration Alaska Production Array Log Analysis 15 Figure 8: Input data from the Spinner Array Tool (SAT) and conventional spinners along with the station measurements. BP Exploration Alaska Production Array Log Analysis 16 Depth Matching No depth matching was required for this well. Pre- Processing Figure 8b: DOWN 30 pass has been excluded from data averaging. BP Exploration Alaska Production Array Log Analysis 17 Calibration of Spinner Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and measured Array Tool responses. Track 2: Line-speed for each pass. Track 3: 'Unwrapped' rotation curve for each pass. Track 4: Normalized layered velocity profile. This profile is optimized by comparing the measured and theoretical SAT response for each pass of each spinner. Tracks 5-10: Measured and theoretical SAT responses for each spinner. Track 11: Measured and theoretical responses for the full-bore spinner. Below are the results from the calibration of the SAT data. The determination of this calibration is a layered velocity profile. Figure 9: Velocity profile from SAT data (Displaying only DOWN 20 pass data) BP Exploration Alaska Production Array Log Analysis 18 The image below displays cross plots for each SAT spinner and the Inline spinner. The estimated slopes are used for converting the spinner response to flow velocities. Figure 10: Spinner cross plot BP Exploration Alaska Production Array Log Analysis 19 Calibration of Resistance Array Data Shown on the image below from left to right: Track 1: Incoherence between the theoretical and the measured RAT responses. Track 2: 'Unwrapped' rotation curve for each pass. Track 3: Normalized layered RAT profile. This profile is optimized by comparing the measured and theoretical RAT response for each pass for each probe. Tracks 4-9: Measured and theoretical RAT responses for each probe. Below are the results from the calibration of the RAT data. The determination of this calibration is a layered resistivity profile. To obtain this profile, calibrations for water/ hydrocarbon were entered for each probe. Figure 11: Calibrated RAT response. BP Exploration Alaska Production Array Log Analysis 20 Holdup and Velocity Profile: Shown on the image below from left to right: Track 3: Layered velocity profile. Track 4: Layered water holdup profile. Track 5: Layered oil holdup profile. Track 6: Layered gas holdup profile Track 7: Total holdup. Track 8: Cumulative flow rates Track 9: Density of fluid Track 10: Apparent Velocity from Fullbore Spinner Figure 12: Holdup and velocity profile BP Exploration Alaska Production Array Log Analysis 21 Flow Profile The quantitative production rates were determined by comparing the well flow model with all available data. The figure below is provided to verify the agreement of the flow model with the data. In this figure the data is represented by the blue curves, whi le the calculated tool values are shown in red. The uncertainty interval is represented as a gray band around the data. The uncertainty interval corresponds to one standard deviation. The small fluctuations around the data are to be expected, since the to ols have intrinsic errors. Large sustained discrepancies indicate problems with the data, conflicts between parameters or conditions that make the underlying empirical models less applicable. To the right of the figure the flow regimes are shown. Within the transition zones several regimes can exists intermittently. Figure 13: Flow profile at reservoir conditions BP Exploration Alaska Production Array Log Analysis 22 The production rates at surface conditions are presented in the figure below: Figure 14: Flow profile at surface conditions (Gas displayed is gas in solution)
