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HomeMy WebLinkAbout215-028MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, August 29, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-312 KUPARUK RIV UNIT 2N-312 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/29/2022 2N-312 50-103-20706-00-00 215-028-0 G SPT 5203 2150280 1500 3460 3460 3460 3460 300 320 320 320 4YRTST P Adam Earl 8/1/2022 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2N-312 Inspection Date: Tubing OA Packer Depth 485 1980 1950 1935IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220803211333 BBL Pumped:2.5 BBL Returned:2.4 Monday, August 29, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.29 15:52:24 -08'00' • • 2�5- 026 aN 31cg- ConocoPhillips RECEIVED Alaska OCT 13 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 11, 2015 Commissioner Cathy Foerster Alaska Oil& Gas Commission 333 West 7th Avenue, Suite 100 SCANNED JUN 0 3 2016 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor 0 • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor,Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/11/2015 2N&2K PAD Corrosion Initial top Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# of cement pumped cement date inhibitor sealant date ft bbls ft gal p�2N-312 50103207060000 2150280 Surface N/A 11" N/A 3 10/9/2015 'J 2K-15 50103201130000 1890890 Surface NA 10" NA 3.7 10/4/2015 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday,September 16,2015 I.Suupeerrvisor p �� t L1 9(is SUBJECT: Mechanical Integrity Tests P.I.P 1� CONOCOPHILLIPS ALASKA INC 2N-312 FROM: Chuck Scheve KUPARUK RIV UNIT 2N-312 Petroleum Inspector Src: Inspector Reviewed By P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2N-312API Well Number 50-103-20706-00-00 Inspector Name: Chuck Scheve Permit Number: 215-028-0 Inspection Date: 9/12/2015 Insp Num: mitCS150913072010 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - — Well 2N-312 Type Inj w TVD r 5203 - Tubing 165o 1225 - 1625 - 1625 PTD 2150280 Tyype Test SPT Test psi 1500 IA 994 2389 - 2366 _ 2352 Interval INITAL Pah' P " 1 OA 350 408 J 404 400 , Notes: G i Wednesday,September 16,2015 Page 1 of 1 • 0 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 1 .za I," - 0 aca'Well History File Identifier Organizing done Two-sided g g( ) ❑ Rescan Needed RESC N: OVERSIZED: NOTES: Color Items: ❑ Maps: rayscale Items: ogs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: C� {�' BY: 4/1.1,01a...)_____ Date: (c I U Iv /s/ I Project Proofing BY: 410 Date: l 4/3//5' is, rY)f3 Scanning Preparation 0 x 30 = I ' '0+ /5 = TOTAL PAGES 1 qs BY: Ml ac?-1/81/5' (Count does not include cover sheet) Mria Date: /s/ Production Scanning Stage 1 Page Count from Scanned File: 1 i T (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: �ES NO BY: al. Date:'d" jai f 5 /s/ 1(143 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: lig NO TOTAL PAGES:3' Digital version appended by: Meredith i!,• Michel Date: [7..,9;0 t /s/ NI Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: �c)--,5 Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked 7/8/2014 Well History File Cover Page_20140708.doc 0 • O o co o o •o rq o a m 0 o) •N p 0 0 co b 0 o } c N m H O O Z .ZOo Z°� Z Z o N > M U ! 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W w w w J W W W W W W W W J W W W LU W W W W • • 0 - O 11 Oo 9O iJ o ct N. >- E O >- >- >- I o N I 1 0 M U N m O 0 _ � >'-', O o_ 'b N Z C Qm Q .....a o I Z Za o $ Zi co > U a m a-', Z M Y 0 0 J Z QCt N Q ii d O co o ce Y a) Z a) O N wQ E ® A I— Q u 0 L0a O p to' cp J IO W 0 co I <Ce W N = ` D LE Oa 3 _ °' .. � _� co 1 a J U ENE @ p J O 10 3 p �w 2 �..,N co Z w aS LI o. O 6-.3 o@ O E W z z a o, P, (1) V0 Q O 0) V - E J E •y a) z m viIR co Q .0� 0) 0 0 coco O J a CI I J as M V E O m 2 0 U c/i U) C) 11 1 r 0 0 O C"-1 a E t co Vo 0c II d 0 O '" E N } O E ba < ,- C? I O 0. H N 0. E I I I I r H co U' O C Z o �o •. c I G D N d 0 y m CO > co c a) E (O C 0 T o' 9C m coI cts CO rc PZ) N U a) c p a o c t o QC - _ .� _ 1 Y U O c O a @ I Q Z E 11 Cl) o > 0 'di U @ 5 2 0 I0 f z in — m6 an I 3 `� co p N E N 1 r- m 2 0 ® 1 ch - v� co rn O w } I '1 — .. O J E CI ©LL, C L T N 0) 0) c b wo in co co N N N O W t O t CO d a m d' o c L = ai > E ECC E O i as (5 I 0 c2 N y V Q .. C p `r) IN z H ~ as Z c is O w v O N N Q CO CO - Q O 0 C C U E U U V W a �Uo o o. 0. a 2 H E •a O 0 p c:3 o m LL o o a0) 0 o o' d E 0 d d I`w J 3 Z 0 d 0 1 0 0 a' p 0 1 0 WELL LOG TRANSMITTAL �, (,5- 028 To: Alaska Oil and Gas Conservation Comm. October 7, 2015 Attn.: Meredith Guhl 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED OCT 092015 RE: Perforation Record: 2N-312 and CD3-130 AOGCC 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 FRS_ANC@halliburton.com 2N-312 and CD3-130 Perforation records for 2N-312 4 color logs zfo l OLI Perforation records for CD3-130 2 color logs O? ( 291O8 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.com °Ig Date: r 1 Signed: ' ' g r� S Guhl, Meredith D (DOA) From: Umlauf, Kelly K <Kelly.K.Umlauf@conocophillips.com> Sent: Wednesday, October 07, 2015 9:31 AM To: Brunswick, Scott A; Guhl, Meredith D (DOA) Cc: Bettis, Patricia K(DOA);Allsup-Drake, Sharon K Subject: RE: KRU 2N-312, PTD 215-028, Complete List of Geologic Markers Required Attachments: CPAI_2N-312_Final_tops_forState.xlsx Hi Scott, Attached you will find the tops for 2N-312. Please let me know if you need anything additional. Cheers, Kelly From: Brunswick, Scott A Sent: Wednesday, October 07, 2015 7:00 AM To: Guhl, Meredith D (DOA); Umlauf, Kelly K Cc: Bettis, Patricia K(DOA); Allsup-Drake, Sharon K Subject: RE: KRU 2N-312, PTD 215-028, Complete List of Geologic Markers Required Good morning Kelly. Could you please provide the information below as you did a couple weeks ago on the Moraine#1 well. Please &thanks Scott From: Guhl, Meredith D (DOA) [mailto:meredith.guhl@alaska.gov] Sent: Tuesday, October 06, 2015 4:01 PM To: Brunswick, Scott A Cc: Bettis, Patricia K (DOA) Subject: [EXTERNAL]KRU 2N-312, PTD 215-028, Complete List of Geologic Markers Required Scott, During a review of the 10-407 form submitted for KRU 2N-312, PTD 215-028, completed 6/3/2015, it was noted that the geologic markers box lacked detail. Box 29: Geologic Markers and Formations: Only the Campanian, C-37, and the Top& Base Bermuda are listed. Please provide a complete list of all geologic formations and markers encountered in this wellbore. The 10-407 form is designed to be a complete and concise record of all data obtained in the completion of a well. Please make sure each well completion form is filled out correctly and fully so that all data is readily available for future users of the AOGCC archive. Please provided the complete list of formations and markers by October 13, 2015. If you have any questions, please contact me. Thank you, • Meredith Meredith Guhl Petroleum Geology Assistant Alaska Oil and Gas Conservation Commission 333 W. 7th Ave, Suite 100,Anchorage,AK 99501 meredith.guhl@alaska.gov Direct: (907)793-1235 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Meredith Guhl at 907-793-1235 or meredith.guhl@alaska.gov. 2 • 0 CPAI Tarn 2N-312 * Name MD (feet) TVD (feet) TVDSS (feet) Base PFROST 1138 1126 967 CSG_10_34_Surf 2733 2415 2255 C-80 2918 2508 2349 CAMP SST 3046 2568 2409 C-50 7126 3864 3704 C-40 8017 4132 3973 C-37 8785 4372 4212 T-7 10589 4923 4763 T-6 10945 5032 4872 T-5 11266 5130 4970 T-4.1 11371 5162 5002 CSG_7_58Int 11678 5254 5094 T-4 11698 5259 5100 T-3.1 11897 5319 5160 T-3 11971 5342 5182 TOP BERM 12172 5402 5243 BASE BERM 12557 5534 5374 TOP PURPLE 12574 5541 5382 BASE_PURPLE 12684 5588 5428 C-35 12737 5611 5451 K-3 12862 5671 5512 TD 12950 5715 5558 r 21 5 ® 2ffi • 26195 WELL LOG TRANSMITTAL DATA LOGGED L1/3/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. August 18, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 " ; RE: SBHP Record and Radial Cement Bond Log: 2N-312 r u1 Run Date: 07/13/2015 and 07/17/2015 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 FRS_ANC@halliburton.com 2N-312 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20706-00-00 SBHP Record and Radial Cement Bond Log (Field Print) 1 Color Log- each 50-103-20706-00-00 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.com Date: Signed: / 2IL5 6-Eek-ea 25 .02 g • 2-Cry co(4 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 16, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 ' tK 4BENDER RUC . 3 2UL RE: Perforation Records: 2N-312 A) . Run Date: 7/1/15 to 7/12/15 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-312 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20706-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: G�✓��� io� /V���; STATE OF ALASKA } AL OIL AND GAS CONSERVATION CO .;SIGN s REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown fl Performed: Suspend r Perforate 17 Other Stimulate fl Alter Casing r Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well fl Other: 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fl Exploratory r 215-028-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ' Service 50-103-20706-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380053,390982,375074 KRU 2N-312 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 12950 feet Plugs(measured) none true vertical 5715 feet Junk(measured) none Effective Depth measured 12917 feet Packer(measured) 11505 true vertical 5697 feet (true vertical) 5202 Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158 158 SURFACE 2693 10.75 2734 2415 INTERMEDIATE 11639 7.625 11677 5251 3 1/2"LINER 1444 3.5 12949 5715 , C E Perforation depth: Measured depth: 12300-12430, 12510-12540 JUL2 9 2015 True Vertical Depth: 5440-5484, 5514-5526 AOGCC Tubing(size,grade,MD,and TVD) 4.5 x 3.5, L-80, 11549 MD, 5215 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER"2RH"ZXP LINER TOP PACKER @ 11505 MD and 5202 TVD NIPPLE-CAMCO DS NIPPLE @ 508 MD and 508 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.263) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service F.ro Stratigraphic Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Eectronic Fracture Stimulation Data r GSTOR r WINJ r WAG p' GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-348 Contact Tv Senden @ 265-1544 Email R.Tyler.Senden(c�conocophillips.com Printed Nae T :nden Title Well Integrity Director Signature \ \ ` \ \\ Phone:265-1544 Date 7/240 \ {ATL 4/ //P--'/ RBDMSTT AUG - 2 2015 Form 10-404 Revised 5/2015 Submit Original Only Ak2N-312 WELL WORK SUMMARY . DATE 'SUMMARY 6/15/2015 ASSISTED ASRC PULLING BRV. DRIFTED TBG TO 2.78"TO 11,396' SLM, SET 3"AVA CATCHER @ 11,448' SLM, PULLED 1" SOV. @ 11,345' SLM, JOB IN PROGRESS 6/16/2015 SET DMY @ 11,347' RKB, PASSING MITT & IA, PULLED AVA CATCHER F/TOP OF PLUG BODY @ 11,462' RKB, PULLED RHC PULL BODY @11,462' RKB, DRIFT WITH 30.5'X 2.73" DMY PERF GUN ASSEMBLY TO 12,686' SLM, READY FOR E-LINE 7/1/2015 PERFORATE 12530'- 12540' WITH 2.5"6 SPF 60 DEG PHASED GUNS. UNABLE TO FALL PAST DEVIATION AT7200'WITH SECOND LONGER GUN STRING. DECISION MADE TO TRY NEW TOOL CONFIGURATION IN THE MORNING, IN PROGRESS. 7/2/2015 PERFORATE WITH 2.5" 6 SPF 60 DEG PHASED PERFORATING GUNS FROM 12510'- 12530'AND 12430'- 12410', IN PROGRESS. 7/3/2015 PERFORATE ZONE 12390' - 12410', WITH A 2.5" HSC 6 SPF, 60 DEG PHASING, 11.1 GRAM MILLENNIUM DEEP PENETRATING CHARGE SECOND GUN DETONATOR FIRED BUT GUN DID NOT, GUN BEING SENT TO DEADHORSE FOR INSPECTION, ***JOB IN PROGRESS*** 7/4/2015 PERFORATE WITH 2.5" 6 SPF 60 DEG PHASED PERFORATING GUNS FROM 12370'TO 12390'AND 12350'TO 12370'. TOOLS STUCK ON PERFS AT 12350'TOOLS LEFT IN HOLE, CG/WB/ROLLER/WB/GPST/ROLLER/20' GUN/ROLLER OAL 43'WEIGHT 350 LBS. 1.375" FISHING NECK. TOOL DIAGRAM PROVIDED TO CPAI REP. READY FOR SLICKLINE TO FISH. 7/6/2015 RECOVERED E-LINE TOOL STRING @ 12,290' SLM; BRUSHED & FLUSHED LINER FROM 12,258'TO 12,388' RKB. READY FOR E-LINE (PERFS). 7/9/2015 PERFORATED FROM 12330'TO 12350' USING 2.5" HSC, 6 SPF, 60 DEG PHASING, 11.1 DEEP PENETRATING MILLENNIUM CHARGES. CORRELATED TO SLB RECORDED MODE LOG DATED 27-MAY-2015. 7/12/2015 PERFORATED FROM 12300'TO 12330' USING 2.5" HSC, 6 SPF, 60 DEG PHASING 11.1 GRAM DEEP PENETRATING MILLENNIUM CHARGES. CORRELATED TO SLB RECORDED MODE LOG DATED 27-MAY-2015. 7/13/2015 PERFORM STATIC BOTTOM HOLE PRESSURE SURVEY AT 12415'. PULLED UP TO 12100' TO PERFORM GRADIENT SURVEY. LOG CORRELATED TO HES PERFORATION RECORD DATED 12-JUL-2015. JOB COMPLETE. 7/17/2015 LOG RCBL FROM TAG AT 12880'TO 11295'. TOP OF CEMENT FOUND AT 11602'. LOG CORRELATED TO SLB VISION SERVICE LOG DATED 27 MAY 2015. JOB COMPLETE. Ai KUP INJ 410 2N-312 r ''. ConocoP'hillips ti Well Attributes Max Angle&MD TD In, Wellbore API/UWI Field Name Wellbore Status nein MD(ftKB) Act Btm(ftKB) caaoenrriilryx 501032070600 TARN PARTICIPATING AREA INJ 74.03 11,714.44 12,950.0 ... Continent H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 2N-312,7/22/20158.00:28 PM SSSV:NIPPLE Last WO: _ 39.79 6/4/2015 Vedical scnemaec{actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PERFORATIONS lehallf 7/22/2015 HANGER;37.0- ?(.0.( Casing Strings I @s I 1 Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(ND) Wt/Len(I...Grade Top Thread b CONDUCTOR 16 13.940 40.0 158 0 158 0 122.00 A106 u�'mom' ey Casing Description OD(in) ID(in) Top(ftKB) Set Depth 011,1.5)8.0 ftKB) Set Depth(ND).WtlLen(I...Grade Top Thread .,, SURFACE 10 3/4 9.950 40.4 2,733.8 2,415.5 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread INTERMEDIATE 75/8 6.625 38.6 11,677.1 5,2537 29.70 L-80 Hydril563 1 Dopeless r Casing Description OD lint ID lint Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ` li 31/2 LINER 31/2 2.992 11504.6 12949.0 5,714.9 9.30 L-80 Hyd 563 Liner Details Nominal lD Top(ftKB) Top(ND)(ftKB) Top!min v Item Des Com (in) i ill 11,504.6 5,201.9 72.37 PACKER BAKER"2RH"ZXP LINER TOP PACKER W/ 4.800 VAMTOP BOX DOWN 11,524.4 5207.9 72.38 HANGER BAKER FLEXLOCK LINER HANGER 4.810 11,533.5 5210.6 72.39 XO Reducing Crossover 5.5"17#BTC x 5"18#BTC Box x Box 4.810 .A.A/CONDUCTOR;40.0-158.OA-A� N.n.,oe 11,535.5 5,211.3 72.39 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 11,554.1 5216.9 72.40 XO Reducing Crossover,5"18#ETC box x 3 Va"9.3#EUE pin 2.930 12,917.1 5,697.8 57.76 COLLAR WEATHERFORD MODEL 402H FLOAT COLLAR 2.992 NIPPLE;507.9 - Tubing Strings Tubing Descnption Strinn Ma...ID('")2 in) Top(ftKB) Set Depth(ft.Set Depth(ND)(. Wt(Ib/ft) Grade Top Connection TUBING 41/2"x3 31/2 2.980 37.0 11,549.0 52153 930IL80 I EUE8rd 1/2"@71 79 f Completion Details Nominal ID _ Top(WEB) Top(ND)(ftKB) Top Incl(°) Item Des Com lie) m.` 37.0 37.0 0.13 HANGER CAMERON TUBING HANGER 3.900 ; �, 71.7 71.7 0.26 XO Reducing Crossover 4 1/2"IBTM b x 3 1/2"EUE 8rd pin 2.992 507.9 507.6 4.48 NIPPLE CAMCO DS NIPPLE 2.875 11,405.9 5,172.0 72.42 SLEEVE BAKER CMU SLIDING SLEEVE-CLOSED POS 2.810 [i : 1 11,461.7 5,188.9 72.35 NIPPLE CAMCO D NIPPLE W/RHC PLUG 2.750 F 11,510.9 5,203.8 72.37 LOCATOR BAKER GBH-22 MECHANICAL LOCATOR SUB 3.000 11,512.0 5,204.1 72.37 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 SURFACE;40.4-2733.8 Perforations&Slots ,,. ,¢ Shot GAS LIFT;2,939.9-11Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 12,300.0 12,430.0 5,440.3 5,483.7 7/12/2015 0.0 IPERF 60 DEGREE PHASING „„ MILLENIUM CHARGES " .4 12,510.0 12,540.0 5,514.1 5,525.9 7/12/2015 0.0 IPERF 60 DEGREE PHASING a MILLENIUM CHARGES t_. / Mandrel Inserts GAS LIFT;11,347.0 at ni y, c'''''' Top(ND) Valve Latch Port Size TRO Run S. N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (Psi) Run Date Corn 1, 2,939.9 2,519.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 5/31/2015 1. 2 11,347.0 5,154.2 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 2,500.0 5/31/2015 DCK-2 SLEEVE;11,405.9 . -rFil '' Notes:General&Safety _ End Date Annotation NOTE NIPPLE;11,461.7 Tv LOCATOR;11.510.9 4 't :': ';:iii '-''. SEAL ASSY;11,512.0 'IF +.. -r'?i r { '; INTERMEDIATE;38.6-11,677.1 r1 (PERF;12,300.0.12,430.07 i" -i+,. Yw-- IPERF;12,510.0-12,540.0 c, ilk _. 3 1/2°LINER,11,504.6-12.949.0- Ilk • • 21 5018 6062 itil. 23 201.1 SchlumbergerTransmittal#: 22JUL15-SPO1 Drilling & Measurements DATA LOGGED /2015 MWD/LWD Log Product Delivery Z- ::o. K..1B E3ENDEENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2N-312*REV-1* Date Dispatched: 22-Jul-15 Job#: 14AKA0123 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: N/A Contents on CD N/A VISION*Service 2" MD x VISION*Service 2'TVD x VISION*Service 5'MD x VISION*Service 5'TVD x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x Nad27 °w-1** As-Built Survey N/A Contents on CD N/A Nad83 x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt **Nad27 Rev-1** x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenterslb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707 / ,}; � � Received By: LE�QJ`y • • 215020 RixeivED 26 06 2 JUL 23 2U1`.; FINAL ,A0occ REVISED 12:53 pm,Jul 21,2015 NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-312 Definitive Survey Report 15 July, 2015 NAD 27 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 0.00 usft Northing: 5,911,977.02 usfl Latitude: 70°10'13.664 N +E/-W 0.00 usft Easting: 460,961.62 usfl Longitude: 150°18'51.070 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.79 0.00 0.00 39.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:3 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8:3' 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1:5 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +NI-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°I100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 0.00 0.00 5,911,977.02 460,961.62 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 0.12 -0.15 5,911,977.14 460,961.47 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 0.72 -0.80 5,911,977.75 460,960.82 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 1.00 -1.06 5,911,978.02 460,960.56 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 -0.65 -0.10 5,911,976.37 460,961.51 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 -5.01 2.60 5,911,972.00 460,964.19 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 -10.69 6.75 5,911,966.30 460,968.31 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 -17.53 12.68 5,911,959.42 460,974.20 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 -26.43 20.95 5,911,950.48 460,982.43 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 -37.46 31.70 5,911,939.40 460,993.12 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 -50.15 44.41 5,911,926.65 461,005.77 2.25 -11.02 GYD-GC-SS(1) 7/15/2015 I1:01:28AM Page 2 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 978.85 13.11 133.85 972.74 815.25 -59.24 53.68 5,911,917.51 461,014.99 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 -75.40 71.28 5,911,901.26 461,032.50 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 -93.70 92.15 5,911,882.86 461,053.28 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 -110.98 116.54 5,911,865.45 461,077.58 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 1,356.78 19.98 113.66 1,333.15 1,175.66 -125.15 144.62 5,911,851.14 461,105.58 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 -136.42 174.84 5,911,839.71 461,135.74 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 -144.32 207.78 5,911,831.64 461,168.63 3.63 18.60 MWD+IFR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 -147.69 244.17 5,911,828.09 461,205.00 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 -148.08 285.57 5,911,827.48 461,246.39 2.68 64.63 MWD+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 -146.18 329.00 5,911,829.16 461,289.83 4.52 93.45 MWD+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 -138.94 377.77 5,911,836.15 461,338.63 4.48 129.76 MWD+IFR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 -126.53 428.68 5,911,848.30 461,389.60 3.36 171.45 MWD+IFR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 -111.63 481.98 5,911,862.92 461,442.97 1.59 216.57 MWD+IFR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 -96.56 536.31 5,911,877.70 461,497.38 3.08 262.47 MWD+IFR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 -78.90 596.09 5,911,895.05 461,557.24 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 -57.55 659.86 5,911,916.07 461,621.11 4.39 370.53 MWD+IFR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 -31.84 727.06 5,911,941.44 461,688.43 4.15 432.81 MWD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 -3.11 796.52 5,911,969.80 461,758.04 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 21.42 854.18 5,911,994.03 461,815.81 3.75 554.20 MWD+IFR-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 46.58 909.36 5,912,018.91 461,871.12 3.14 608.48 MWD+IFR-AK-CAZ-SC(3) 10314"x13-1/2 2,758.81 59.33 63.63 2,428.38 2,270.89 55.91 928.50 5,912,028.14 461,890.31 3.14 627.78 MWD+IFR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 94.01 1,000.29 5,912,065.86 461,962.28 2.93 702.56 MWD+IFR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 137.44 1,071.07 5,912,108.92 462,033.28 3.88 780.86 MWD+IFR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 184.93 1,139.95 5,912,156.05 462,102.40 3.52 861.11 MWD+IFR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 235.85 1,207.85 5,912,206.61 462,170.55 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 290.43 1,274.53 5,912,260.84 462,237.50 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 349.42 1,339.01 5,912,319.49 462,302.28 3.71 1,114.21 MWD+IFR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 411.57 1,399.00 5,912,381.33 462,362.59 3.34 1,200.27 MWD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 477.49 1,457.12 5,912,446.94 462,421.04 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 545.92 1,512.50 5,912,515.08 462,476.76 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 617.91 1,567.23 5,912,586.78 462,531.86 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 690.08 1,619.48 5,912,658.67 462,584.48 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 766.24 1,670.24 5,912,734.56 462,635.63 2.32 1,646.60 MWD+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 842.12 1,719.97 5,912,810.17 462,685.74 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 915.54 1,770.70 5,912,883.32 462,736.84 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 989.36 1,822.61 5,912,956.87 462,789.13 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 1,063.01 1,875.23 5,913,030.23 462,842.12 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 1,136.98 1,928.56 5,913,103.93 462,895.83 0.78 2,097.28 MWD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 1,210.77 1,979.89 5,913,177.44 462,947.54 1.17 2,186.93 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 11:01:28AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100) (ft) Survey Tool Name 4,555.72 72.90 33.56 3,073.19 2,915.70 1,284.84 2,029.68 5,913,251.25 462,997.70 0.71 2,275.83 MWD+1FR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 1,361.41 2,080.15 5,913,327.55 463,048.56 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 1,437.72 2,129.56 5,913,403.59 463,098.36 0.77 2,457.49 MWD+IFR-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 1,513.20 2,177.78 5,913,478.82 463,146.96 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 1,589.12 2,225.65 5,913,554.49 463,195.22 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 1,665.47 2,273.52 5,913,630.58 463,243.47 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 1,740.29 2,322.20 5,913,705.14 463,292.53 1.66 2,813.86 MW D+I FR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 1,815.06 2,372.59 5,913,779.64 463,343.31 0.23 2,903.68 MW D+I FR-AK-CAZ-SC(3) 5,314.27 71.88 34.89 3,306.85 3,149.36 1,889.38 2,423.65 5,913,853.68 463,394.74 0.80 2,993.57 MW D+I FR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 1,963.49 2,474.11 5,913,927.53 463,445.58 1.29 3,082.92 MWD+1FR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 2,038.97 2,523.11 5,914,002.75 463,494.97 1.25 3,172.42 MWD+IFR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 2,114.45 2,571.52 5,914,077.97 463,543.76 0.68 3,261.55 MWD+IFR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 2,190.20 2,621.54 5,914,153.45 463,594.17 0.92 3,351.90 MWD+IFR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 2,264.62 2,672.44 5,914,227.60 463,645.45 0.95 3,441.76 MWD+IFR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 2,338.85 2,723.75 5,914,301.56 463,697.13 0.38 3,531.74 MWD+1FR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 2,413.05 2,774.83 5,914,375.48 463,748.58 0.17 3,621.54 MWD+IFR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 2,487.11 2,825.61 5,914,449.27 463,799.75 0.38 3,711.06 MWD+IFR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 2,560.97 2,876.08 5,914,522.87 463,850.58 0.22 3,800.22 MW D+I FR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 2,635.95 2,926.91 5,914,597.58 463,901.80 0.59 3,890.48 MW D+I FR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 2,711.25 2,976.69 5,914,672.61 463,951.96 0.75 3,980.33 MW D+I FR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 2,786.48 3,025.74 5,914,747.58 464,001.39 0.03 4,069.66 MW D+I FR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 2,861.37 3,074.46 5,914,822.21 464,050.50 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 2,937.26 3,123.57 5,914,897.84 464,099.99 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 3,013.60 3,172.61 5,914,973.92 464,149.42 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 3,089.22 3,220.82 5,915,049.28 464,198.02 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 3,165.17 3,268.83 5,915,124.98 464,246.41 0.35 4,516.94 MWD+IFR-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 3,241.70 3,317.54 5,915,201.25 464,295.51 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 3,316.22 3,366.89 5,915,275.50 464,345.24 1.52 4,696.04 MWD+IFR-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 3,390.64 3,418.72 5,915,349.65 464,397.45 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 3,463.43 3,471.84 5,915,422.16 464,450.94 1.28 4,876.49 MWD+IFR-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 3,535.74 3,525.91 5,915,494.18 464,505.38 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 3,608.77 3,579.80 5,915,566.93 464,559.63 0.83 5,057.38 MWD+1FR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 3,681.62 3,632.08 5,915,639.50 464,612.28 0.74 5,146.90 MWD+IFR-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 3,755.78 3,684.23 5,915,713.37 464,664.81 0.40 5,237.35 MWD+IFR-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 3,829.75 3,735.42 5,915,787.08 464,716.37 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 3,904.22 3,786.13 5,915,861.27 464,767.46 0.37 5,416.84 MW D+I FR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 3,979.21 3,836.33 5,915,935.99 464,818.05 0.54 5,506.70 MWD+IFR-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 4,054.38 3,885.30 5,916,010.91 464,867.40 1.14 5,595.95 MW D+I FR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 4,130.20 3,933.12 5,916,086.47 464,915.60 0.79 5,684.96 MW D+I FR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 4,207.07 3,980.43 5,916,163.09 464,963.30 0.48 5,774.47 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 11:01:28AM Page 4 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 21\I-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 8,343.16 71.71 31.21 4,234.52 4,077.03 4,284.49 4,027.48 5,916,240.25 465,010.75 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 4,360.68 4,073.98 5,916,316.20 465,057.64 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 4,436.97 4,121.53 5,916,392.23 465,105.57 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 4,512.70 4,170.17 5,916,467.71 465,154.60 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 4,587.64 4,220.16 5,916,542.38 465,204.98 1.17 6,221.10 MWD+IFR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 4,661.58 4,270.95 5,916,616.05 465,256.14 0.40 6,310.53 MWD+IFR-AK-CAZ-SC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 4,735.26 4,322.57 5,916,689.46 465,308.13 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 4,808.80 4,374.38 5,916,762.72 465,360.32 0.36 6,490.02 MWD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 4,882.29 4,425.55 5,916,835.94 465,411.86 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 4,957.10 4,476.81 5,916,910.48 465,463.50 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 5,031.89 4,527.09 5,916,985.00 465,514.16 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 5,107.21 4,575.36 5,917,060.06 465,562.82 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 9,477.42 72.26 30.26 4,583.36 4,425.87 5,184.90 4,621.94 5,917,137.50 465,609.79 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 5,262.61 4,666.99 5,917,214.97 465,655.23 0.33 7,026.85 MWD+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 5,341.59 4,712.10 5,917,293.71 465,700.74 0.42 7,116.61 MWD+IFR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 5,419.95 4,757.32 5,917,371.82 465,746.37 0.95 7,205.97 MWD+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 5,496.18 4,803.63 5,917,447.81 465,793.06 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 5,572.65 4,853.67 5,917,524.01 465,843.49 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 5,646.19 4,903.41 5,917,597.29 465,893.61 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 5,721.59 4,954.96 5,917,672.41 465,945.54 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 5,794.30 5,007.70 5,917,744.85 465,998.65 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 5,866.33 5,062.35 5,917,816.58 466,053.66 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 5,937.30 5,117.19 5,917,887.27 466,108.87 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 6,008.89 5,173.20 5,917,958.56 466,165.23 0.15 7,925.39 MWD+IFR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 6,079.74 5,227.30 5,918,029.12 466,219.70 1.39 8,014.50 MWD+IFR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 6,153.53 5,279.56 5,918,102.63 466,272.33 2.78 8,104.72 MWD+IFR-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 6,203.38 5,311.07 5,918,152.32 466,304.10 4.98 8,163.30 MWD+IFR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 6,228.35 5,325.85 5,918,177.20 466,319.00 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 6,307.78 5,372.66 5,918,256.39 466,366.21 0.19 8,283.19 MWD+IFR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 6,385.17 5,418.08 5,918,333.53 466,412.03 0.15 8,371.92 MWD+IFR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 6,462.61 5,465.36 5,918,410.72 466,459.71 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 6,538.05 5,514.23 5,918,485.90 466,508.96 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 6,613.12 5,564.01 5,918,560.70 466,559.12 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 6,687.56 5,613.97 5,918,634.88 466,609.46 0.47 8,730.20 MWD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 6,762.68 5,664.91 5,918,709.72 466,660.78 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 6,837.98 5,715.59 5,918,784.75 466,711.84 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 6,883.04 5,745.21 5,918,829.66 466,741.69 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,677.00 73.37 33.29 5,253.64 5,096.15 6,930.66 5,776.27 5,918,877.11 466,773.00 1.86 9,021.26 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 11,714.45 74.03 33.50 5,264.15 5,106.66 6,960.67 5,796.06 5,918,907.01 466,792.93 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 7,036.14 5,846.17 5,918,982.22 466,843.43 1.86 9,147.22 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 11:01:28AM Page 5 COMPASS 5000.1 Build 74 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°l100') (ft) Survey Tool Name 11,905.96 72.27 31.26 5,321.07 5,163.58 7,113.97 5,895.69 5,919,059.78 466,893.34 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 7,191.48 5,943.81 5,919,137.04 466,941.86 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 7,267.66 5,992.12 5,919,212.96 466,990.55 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 7,302.73 6,014.35 5,919,247.92 467,012.96 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 7,378.24 6,062.96 5,919,323.16 467,061.96 0.81 9,549.52 MWD+IFR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 7,454.63 6,112.47 5,919,399.29 467,111.86 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 7,531.33 6,158.95 5,919,475.74 467,158.73 4.59 9,728.89 MWD+IFR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 7,605.55 6,205.15 5,919,549.72 467,205.31 4.75 9,815.65 MWD+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 7,677.67 6,253.74 5,919,621.58 467,254.26 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 7,748.57 6,301.56 5,919,692.23 467,302.45 1.65 9,987.48 MWD+IFR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 7,817.27 6,349.43 5,919,760.67 467,350.67 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 7,883.90 6,397.70 5,919,827.04 467,399.28 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57.76 35.26 5,696.83 5,539.34 7,895.13 6,405.81 5,919,838.23 467,407.44 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 7,919.16 6,422.80 5,919,862.17 467,424.55 0.00 10,196.35 PROJECTED to TD 3 1/2"x 6-1/2" 7/15/2015 11:01:28AM Page 6 COMPASS 5000.1 Build 74 • DATA LOGGED 2 1 5 0 l 8 • ivi KNO R 2 6 0 6 1 Conoco fillips TRANSMI TAL RECEIVED -CONFIDEAt Won JUL 2 2 2O3 FROM: Sandra a Lemke,ATO3-0340 TO: Makana Bender AOGCC ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W.7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RE: 2N-312 DATE: 07/17/2015 Transmitted: Kuparuk River Unit, Alaska 1 2N-312 1 hardcopy report with digital data on CD I Halliburton Surface Data logging-End of well report; May 30;2015; General information, daily summary, days vs 1 depth, after action review, mud log, bit record, Morning reports, survey data 11 11 11 12"MD Formation Evaluation log 12"MD Drilling Engineering log I1 2"MD Gas ratio log P CD contains Final Log files, Final End of well report, Final LAS exports, Log viewers. 9 Please promptly sign, scan and return electronically to Sandra.D.Lemke()COP.com 11 CC: 2N-312 transmittal folder, production well files, eSearch <17) Receip t ôate: ui5=Technical Data Management 1 ConocoPhillips 'Anchorage, Alaska I Ph: 907.265.6947 • • D.Brunswick Drilling Engineer RECEIVED • Drilling&Wells P.O. Box 100360 IUI_ 2 0 2015 Anchorage,AK 99510-0360 ConocoPhillips �'?f� Phone: 907-263-4249 OC July 17, 2U15 A AOGCC Commissioner 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Subject: Revised Completion Report for KRU 2N-312 PTD#215-028 Dear Commissioner: Attached for your review is the revised completion report for KRU 2N-312. Correction to the original completion report include the revised bottomhole location data in box 4a and 4b. Also attached is the revised directional survey. This package should be added to the data we already sent with the original completion report which includes the daily operations summary and a schematic. If you have any questions, please feel free to call me at anytime. Sincerely, S. Brunswick Drilling Engineer CPAI Drilling SB/skad RECEIVED • STATE OF ALASKA • 'l '' 9 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a.Well Status: Oil ❑ Gas❑ SPLUG Li Other ❑ Abandoned ❑ Suspended❑ 1b.Well Class: 2OAAc 25.105 2OAAc 25.110 Development El Exploratory ❑ GINJ ❑ WINJ ❑ WAGE] WDSPL❑ No. of Completions: Service ❑✓ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp.,Susp., or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 6/3/2015 215-028 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,AK 99501 5/9/2015 50-103-20706-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number Surface: 30'FNL,632'FEL,Sec. 3,T9N, R7E, UM 5/26/2015 KRU 2N-312 Top of Productive Interval: 9. KB(ft above MSL): 157.5' 17. Field/Pool(s): 2016'FSL, 131'FWL, Sec. 25,T1ON, R7E, UM GL(ft above MSL): 117' Kuparuk River Field/Tarn Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 2606'FSL, 523'FWL, Sec.25,T1ON, R7E, UM 12917'MD/5697'TVD ADL 380053, 390982, 375074 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 460962 y- 5911977 Zone- 4 12950'MD/5715°TVD 4602 TPI: x- 467030 y- 5919274 Zone- 4 12.SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 467424.6 y- 5919862 Zone- 4 nipple @ 508'MD/508'TVD 1138'MD/1126'TVD 5. Directional or Inclination Survey: Yes ❑(attached) No ❑ 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 not applicable (ft MSL) not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Neutron-Density 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT. PULLED 16" 165# ATO6B 40' 158' 40' 158' 24" Driven 10.75" 45.5# L-80 40' 2734' 40' 2416' 13.5" 947 sx ALC,219 sx LiteCRETE 7.625" 29.7# L-80 39' 11677' 39' 5254' 9.875" 941 sx Ckass G 3.5" 9.3# L-80 11505' 12949' 5202' 5715' 6.5" 291 sx Class G 24. Open to production or injection? Yes ❑ No ❑ 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 11054' none not perf'd LA ( 15 I c - '0 - q c If / 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No ❑� Per 20 AAC 25.283(i)(2)attach electronic and printed information kt4 `3 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 1 RBDM AUG 3 1 2015 none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API (corr): Press. 24-Hour Rate �-' Form 10-407 Revised 5/2015 CONTINUED ON PAGE 2 Submit ORIGINIAL only 28.CORE DATA Conventional Core Yes ❑ No ❑✓ Sidewall Cores: fa ❑ No ❑✓ If Yes,list formations and intervals cored(MD/TVD, From/To),and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No Q Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1138' 1126' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Campanian 3046' 2568' C-37 8785' 4372' Top Bermuda 12172' 5402' NONE Base Bermuda 12557' 5534' Formation at total depth: Bermuda 31. List of Attachments: Summary of Daily Operations,final directional survey,schematic,cement reports Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. G/ Contact: Scott Brunswick @ 263-4249 Email: scott.a.brunswickcop.com Printed Name: G. Alvord Title: Alaska Drilling Manager Signature: 4),A1 ��v�' �or Phone: 265-6120 Date: "(7.20(5- INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item 1a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips,photographs,and all subsequent laboratory analytical results, including,but not limited to:porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical,or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including, but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only • • NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-312 Definitive Survey Report 15 July, 2015 NAD 27 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 0.00 usft Northing: 5,911,977.02 usfl Latitude: 70° 10'13.664 N +E/-W 0.00 usft Easting: 460,961.62 usfl Longitude: 150° 18'51.070 W Position Uncertainty 0.00 usfl Wellhead Elevation: usfl Ground Level: 117.70 usft Wellbore 2N-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.79 0.00 0.00 39.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:3' 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8:3' 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1:5 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 0.00 0.00 5,911,977.02 460,961.62 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 0.12 -0.15 5,911,977.14 460,961.47 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 0.72 -0.80 5,911,977.75 460,960.82 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 1.00 -1.06 5,911,978.02 460,960.56 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 -0.65 -0.10 5,911,976.37 460,961.51 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 -5.01 2.60 5,911,972.00 460,964.19 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 -10.69 6.75 5,911,966.30 460,968.31 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 -17.53 12.68 5,911,959.42 460,974.20 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 -26.43 20.95 5,911,950.48 460,982.43 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 -37.46 31.70 5,911,939.40 460,993.12 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 -50.15 44.41 5,911,926.65 461,005.77 2.25 -11.02 GYD-GC-SS(1) 7/15/2015 11:01:28AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 978.85 13.11 133.85 972.74 815.25 -59.24 53.68 5,911,917.51 461,014.99 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 -75.40 71.28 5,911,901.26 461,032.50 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 -93.70 92.15 5,911,882.86 461,053.28 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 -110.98 116.54 5,911,865.45 461,077.58 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 1,356.78 19.98 113.66 1,333.15 1,175.66 -125.15 144.62 5,911,851.14 461,105.58 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 -136.42 174.84 5,911,839.71 461,135.74 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 -144.32 207.78 5,911,831.64 461,168.63 3.63 18.60 MWD+IFR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 -147.69 244.17 5,911,828.09 461,205.00 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 -148.08 285.57 5,911,827.48 461,246.39 2.68 64.63 MWD+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 -146.18 329.00 5,911,829.16 461,289.83 4.52 93.45 MWD+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 -138.94 377.77 5,911,836.15 461,338.63 4.48 129.76 MWD+IFR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 -126.53 428.68 5,911,848.30 461,389.60 3.36 171.45 MWD+IFR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 -111.63 481.98 5,911,862.92 461,442.97 1.59 216.57 MWD+IFR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 -96.56 536.31 5,911,877.70 461,497.38 3.08 262.47 MWD+IFR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 -78.90 596.09 5,911,895.05 461,557.24 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 -57.55 659.86 5,911,916.07 461,621.11 4.39 370.53 MWD+IFR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 -31.84 727.06 5,911,941.44 461,688.43 4.15 432.81 MWD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 -3.11 796.52 5,911,969.80 461,758.04 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 21.42 854.18 5,911,994.03 461,815.81 3.75 554.20 MWD+IFR-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 46.58 909.36 5,912,018.91 461,871.12 3.14 608.48 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,758.81 59.33 63.63 2,428.38 2,270.89 55.91 928.50 5,912,028.14 461,890.31 3.14 627.78 MWD+IFR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 94.01 1,000.29 5,912,065.86 461,962.28 2.93 702.56 MWD+IFR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 137.44 1,071.07 5,912,108.92 462,033.28 3.88 780.86 MWD+IFR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 184.93 1,139.95 5,912,156.05 462,102.40 3.52 861.11 MWD+IFR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 235.85 1,207.85 5,912,206.61 462,170.55 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 290.43 1,274.53 5,912,260.84 462,237.50 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 349.42 1,339.01 5,912,319.49 462,302.28 3.71 1,114.21 MWD+IFR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 411.57 1,399.00 5,912,381.33 462,362.59 3.34 1,200.27 MWD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 477.49 1,457.12 5,912,446.94 462,421.04 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 545.92 1,512.50 5,912,515.08 462,476.76 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 617.91 1,567.23 5,912,586.78 462,531.86 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 690.08 1,619.48 5,912,658.67 462,584.48 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 766.24 1,670.24 5,912,734.56 462,635.63 2.32 1,646.60 MWD+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 842.12 1,719.97 5,912,810.17 462,685.74 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 915.54 1,770.70 5,912,883.32 462,736.84 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 989.36 1,822.61 5,912,956.87 462,789.13 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 1,063.01 1,875.23 5,913,030.23 462,842.12 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 1,136.98 1,928.56 5,913,103.93 462,895.83 0.78 2,097.28 MWD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 1,210.77 1,979.89 5,913,177.44 462,947.54 1.17 2,186.93 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 I1:01:28AM Page 3 COMPASS 5000.1 Build 74 • • Schlumberger S Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,555.72 72.90 33.56 3,073.19 2,915.70 1,284.84 2,029.68 5,913,251.25 462,997.70 0.71 2,275.83 MWD+IFR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 1,361.41 2,080.15 5,913,327.55 463,048.56 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 1,437.72 2,129.56 5,913,403.59 463,098.36 0.77 2,457.49 MWD+IFR-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 1,513.20 2,177.78 5,913,478.82 463,146.96 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 1,589.12 2,225.65 5,913,554.49 463,195.22 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 1,665.47 2,273.52 5,913,630.58 463,243.47 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 1,740.29 2,322.20 5,913,705.14 463,292.53 1.66 2,813.86 MWD+IFR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 1,815.06 2,372.59 5,913,779.64 463,343.31 0.23 2,903.68 MWD+IFR-AK-CAZ-SC(3) 5,314.27 71.88 34.89 3,306.85 3,149.36 1,889.38 2,423.65 5,913,853.68 463,394.74 0.80 2,993.57 MWD+IFR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 1,963.49 2,474.11 5,913,927.53 463,445.58 1.29 3,082.92 MWD+IFR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 2,038.97 2,523.11 5,914,002.75 463,494.97 1.25 3,172.42 MWD+IFR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 2,114.45 2,571.52 5,914,077.97 463,543.76 0.68 3,261.55 MWD+IFR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 2,190.20 2,621.54 5,914,153.45 463,594.17 0.92 3,351.90 MWD+IFR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 2,264.62 2,672.44 5,914,227.60 463,645.45 0.95 3,441.76 MWD+IFR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 2,338.85 2,723.75 5,914,301.56 463,697.13 0.38 3,531.74 MWD+IFR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 2,413.05 2,774.83 5,914,375.48 463,748.58 0.17 3,621.54 MWD+IFR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 2,487.11 2,825.61 5,914,449.27 463,799.75 0.38 3,711.06 MWD+IFR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 2,560.97 2,876.08 5,914,522.87 463,850.58 0.22 3,800.22 MWD+IFR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 2,635.95 2,926.91 5,914,597.58 463,901.80 0.59 3,890.48 MWD+IFR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 2,711.25 2,976.69 5,914,672.61 463,951.96 0.75 3,980.33 MWD+IFR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 2,786.48 3,025.74 5,914,747.58 464,001.39 0.03 4,069.66 MWD+IFR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 2,861.37 3,074.46 5,914,822.21 464,050.50 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 2,937.26 3,123.57 5,914,897.84 464,099.99 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 3,013.60 3,172.61 5,914,973.92 464,149.42 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 3,089.22 3,220.82 5,915,049.28 464,198.02 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 3,165.17 3,268.83 5,915,124.98 464,246.41 0.35 4,516.94 MWD+IFR-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 3,241.70 3,317.54 5,915,201.25 464,295.51 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 3,316.22 3,366.89 5,915,275.50 464,345.24 1.52 4,696.04 MWD+IFR-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 3,390.64 3,418.72 5,915,349.65 464,397.45 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 3,463.43 3,471.84 5,915,422.16 464,450.94 1.28 4,876.49 MWD+IFR-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 3,535.74 3,525.91 5,915,494.18 464,505.38 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 3,608.77 3,579.80 5,915,566.93 464,559.63 0.83 5,057.38 MWD+IFR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 3,681.62 3,632.08 5,915,639.50 464,612.28 0.74 5,146.90 MWD+IFR-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 3,755.78 3,684.23 5,915,713.37 464,664.81 0.40 5,237.35 MWD+IFR-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 3,829.75 3,735.42 5,915,787.08 464,716.37 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 3,904.22 3,786.13 5,915,861.27 464,767.46 0.37 5,416.84 MWD+IFR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 3,979.21 3,836.33 5,915,935.99 464,818.05 0.54 5,506.70 MWD+IFR-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 4,054.38 3,885.30 5,916,010.91 464,867.40 1.14 5,595.95 MWD+IFR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 4,130.20 3,933.12 5,916,086.47 464,915.60 0.79 5,684.96 MWD+IFR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 4,207.07 3,980.43 5,916,163.09 464,963.30 0.48 5,774.47 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 11:01:28AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,343.16 71.71 31.21 4,234.52 4,077.03 4,284.49 4,027.48 5,916,240.25 465,010.75 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 4,360.68 4,073.98 5,916,316.20 465,057.64 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 4,436.97 4,121.53 5,916,392.23 465,105.57 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 4,512.70 4,170.17 5,916,467.71 465,154.60 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 4,587.64 4,220.16 5,916,542.38 465,204.98 1.17 6,221.10 MWD+IFR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 4,661.58 4,270.95 5,916,616.05 465,256.14 0.40 6,310.53 MWD+IFR-AK-CAZ-SC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 4,735.26 4,322.57 5,916,689.46 465,308.13 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 4,808.80 4,374.38 5,916,762.72 465,360.32 0.36 6,490.02 MWD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 4,882.29 4,425.55 5,916,835.94 465,411.86 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 4,957.10 4,476.81 5,916,910.48 465,463.50 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 5,031.89 4,527.09 5,916,985.00 465,514.16 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 5,107.21 4,575.36 5,917,060.06 465,562.82 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 9,477.42 72.26 30.26 4,583.36 4,425.87 5,184.90 4,621.94 5,917,137.50 465,609.79 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 5,262.61 4,666.99 5,917,214.97 465,655.23 0.33 7,026.85 MWD+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 5,341.59 4,712.10 5,917,293.71 465,700.74 0.42 7,116.61 MWD+IFR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 5,419.95 4,757.32 5,917,371.82 465,746.37 0.95 7,205.97 MWD+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 5,496.18 4,803.63 5,917,447.81 465,793.06 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 5,572.65 4,853.67 5,917,524.01 465,843.49 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 5,646.19 4,903.41 5,917,597.29 465,893.61 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 5,721.59 4,954.96 5,917,672.41 465,945.54 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 5,794.30 5,007.70 5,917,744.85 465,998.65 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 5,866.33 5,062.35 5,917,816.58 466,053.66 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 5,937.30 5,117.19 5,917,887.27 466,108.87 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 6,008.89 5,173.20 5,917,958.56 466,165.23 0.15 7,925.39 MWD+IFR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 6,079.74 5,227.30 5,918,029.12 466,219.70 1.39 8,014.50 MWD+IFR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 6,153.53 5,279.56 5,918,102.63 466,272.33 2.78 8,104.72 MWD+IFR-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 6,203.38 5,311.07 5,918,152.32 466,304.10 4.98 8,163.30 MWD+IFR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 6,228.35 5,325.85 5,918,177.20 466,319.00 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 6,307.78 5,372.66 5,918,256.39 466,366.21 0.19 8,283.19 MWD+IFR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 6,385.17 5,418.08 5,918,333.53 466,412.03 0.15 8,371.92 MWD+IFR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 6,462.61 5,465.36 5,918,410.72 466,459.71 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 6,538.05 5,514.23 5,918,485.90 466,508.96 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 6,613.12 5,564.01 5,918,560.70 466,559.12 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 6,687.56 5,613.97 5,918,634.88 466,609.46 0.47 8,730.20 MWD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 6,762.68 5,664.91 5,918,709.72 466,660.78 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 6,837.98 5,715.59 5,918,784.75 466,711.84 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 6,883.04 5,745.21 5,918,829.66 466,741.69 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,677.00 73.37 33.29 5,253.64 5,096.15 6,930.66 5,776.27 5,918,877.11 466,773.00 1.86 9,021.26 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 11,714.45 74.03 33.50 5,264.15 5,106.66 6,960.67 5,796.06 5,918,907.01 466,792.93 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 7,036.14 5,846.17 5,918,982.22 466,843.43 1.86 9,147.22 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 11:01:28AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,905.96 72.27 31.26 5,321 07 5,163.58 7,113.97 5,895.69 5,919,059.78 466,893.34 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 7,191.48 5,943.81 5,919,137.04 466,941.86 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 7,267.66 5,992.12 5,919,212.96 466,990.55 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 7,302.73 6,014.35 5,919,247.92 467,012.96 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 7,378.24 6,062.96 5,919,323.16 467,061.96 0.81 9,549.52 MWD+IFR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 7,454.63 6,112.47 5,919,399.29 467,111.86 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 7,531.33 6,158.95 5,919,475.74 467,158.73 4.59 9,728.89 MWD+IFR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 7,605.55 6,205.15 5,919,549.72 467,205.31 4.75 9,815.65 MWD+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 7,677.67 6,253.74 5,919,621.58 467,254.26 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 7,748.57 6,301.56 5,919,692.23 467,302.45 1.65 9,987.48 MWD+IFR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 7,817.27 6,349.43 5,919,760.67 467,350.67 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 7,883.90 6,397.70 5,919,827.04 467,399.28 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57.76 35.26 5,696.83 5,539.34 7,895.13 6,405.81 5,919,838.23 467,407.44 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 7,919.16 6,422.80 5,919,862.17 467,424.55 0.00 10,196.35 PROJECTED to TD 3112"x6-112" 7/15/2015 11:01:28AM Page 6 COMPASS 5000.1 Build 74 RECEIVED • STATE OF ALASKA S JUN 3 0 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND4 1a.Well Status: Oil jJ Gas❑ SPLUG 0 Other [IJ Abandoned ❑ Suspended 1b.Well Class: 20AAC 25.105 20AAC 25.116 Development El Exploratory 11 GINJ El WINJ 0 WAG❑ , WDSPL❑ No.of Completions: Service . Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp.,Susp.,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc., Aband.: .6/3/2015 215-028 3.Address: 7. Date Spudded: 15.API Number: P. O. Box 100360,Anchorage,AK 99501 •5/9/2015 50-103-20706-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 30'FNL,632'FEL, Sec.3,T9N, R7E, UM •5/26/2015 KRU 2N-312 Top of Productive Interval: 9. KB(ft above MSL): 157.5' 17. Field/Pool(s): 2016'FSL, 131'FWL,Sec.25,T1ON, R7E, UM GL(ft above MSL): 117' Kuparuk River Field/Tarn Oil Pool Total Depth: ".i-1: A 10. Plug Back Depth MD/TVD: 18. Property Designation: „--11-92'FNL,720'FEL, Sec.26,T1ON, R7E, UM 12917'MD/5697'TVD ADL 380053,390982,375074 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 460962 y- 5911977 Zone- 4 •12950'MD/5715'TVD 4602 TPI: x- 467030 rd, y- 5919274 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: Vic-'466185 eiii--11)' y- 5920749 Zone- 4 nipple @ 508'MD/508'TVD 1138'MD/1126'TVD 5. Directional or Inclination Survey: Yes . []✓(attached) No C 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 not applicable (ft MSL) ,not applicable 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion,suspension, or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray,caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature, cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary GR/Res/Neutron-Density 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16" 165# ATO6B 40' 158' 40' 158' 24" Driven 10.75" 45.5# L-80 40' 2734' 40' 2416' 13.5" 947 sx ALC,219 sx LiteCRETE 7.625" 29.7# L-80 39' 11677' 39' 5254' 9.875" 941 sx Ckass G 3.5" 9.3# L-80 11505' 12949' 5202' 5715' 6.5" 291 sx Class G 24.Open to production or injection? Yes ❑ No Ei 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 11054' none not perfd s I r_ 1,i; 26.ACID, FRACTURE,CEMENT SQUEEZE, ETC. /' Was hydraulic fracturing used during completion? Yes Li No ❑✓ (Az 1c. Per 20 AAC 25.283(i)(2)attach electronic and printed information J '. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED (Ky/r- none 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): waiting on facility hook-up Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period -0. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 R vi ed 5/29151 a. 'V, %L q/z 57/5 CONTI DON PAGE 2 RBDM$4460 t y hit Submit ORIGINIAL on'y 28. CORE DATA Conventional Core Yes ❑ No 0 Sidewall Cores: • ❑ No ❑ If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed).Submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No El Permafrost-Top surface surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1138' 1126' Attach separate pages to this form, if needed,and submit detailed test information, including reports,per 20 AAC 25.071. Campanian 3046' 2568' C-37 8785' 4372' Top Bermuda 12172' 5402' NONE Base Bermuda 12557' 5534' Formation at total depth: Bermuda 31. List of Attachments: Summary of Daily Operations,final directional survey,schematic,cement reports Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Scott Brunswick @ 263-4249 Email: scott.a.brunswickcop.com Printed Name: G. L.Alvord Title: Alaska Drilling Manager Signature: A_(_ 4,,,( Phone: 265-6120 Date: 6 (,o 11 INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled 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.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: 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 1 b: Well Class-Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23: Attached supplemental records 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. Pursuant to 20 AAC 25.071,submit detailed descriptions,core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. 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. Item 31: Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including, but not limited to:core analysis,paleontological report, production or well test results. Form 10-407 Revised 5/2015 Submit ORIGINAL Only KUP INJ 2N-312 ConocoPhillips '� Well Attributes •Max Angle 8 MD TO AlaakaInc Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB)cmarcmriiurn 501032070600 TARN PARTICIPATING AREA INJ 74.03 11,714.45 12,950.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-312,624201510:08:18 AM 39.79 Vertical schematic{acNah Annotation Depth(kKB) End Date Annotation Last Mod By End Date Hanger;370- .ti r .. Casing Strings II I( Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread ti iI; Conductor 16 13.940 40.0 158.0 158.0 122.00 A106 Casing Description OD lin) ID(in) Top(ftKB) Set Depth(COB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Surface 103/4 9.950 40.4 2,733.8 2,415 5 45.50 L-80 TSH 563 Casing Description OD(in) ID(in) Top(itKB) Set Depth(RKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread t i. Intermediate 7 5/8 6.625 38.6 11,677.1 5,253.7 29 70 L-80 Hydrl1563 ` # Dopeless 3: 2 Casing DescriptionOD(in) ID(in) Top(kKB) Set Depth(kKB) Set Depth(ND)... WtlLen(I...Grade Top Thread ° 3 1/2"Liner 3 1/2 2.992 11,504.6 12,949.0 5,714.9 9.30 L-80 Hyd 563 Liner Details Nominal ID Top(ftKB) Top(ND)(kKB) Top Incl(°) Item Des Corn (in) X0 Reducing(Tubing);71 8 * 11,524.4 5,207.9 72.38 Hanger Baker 5.5"x 7.625"Flex lock liner hanger VamTop 4.810 pin up,BTC pin down 11,533.5 5,210.6 72.39 XO Reducing Crossover 5.5"17#BTC x 5"18#BTC Box x Box 4.810 (Casing) r11,535.5 5,211.2 72.39 Seal Bore Baker 80-40 Seal Bore Extension 5"18#BTC Pin x 4.000 -:. Extension Pin AAA W,Conductor;40.0-t5e.o . 11,554.1 5,216.9 72.40 XO Reducing Crossover,5"18#BTC box x 3 h"9.3#EUE pin 2.930 (Casing) Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) I 1 Set Set Depth(ft..Set Depth(ND) (W[lb/ft Grade TopConnection l Tubing-Water 31/2 2.980 37.0 115490 5,215.3 9.30 L-80 EUE8id Injection Completion Details Nominal ID 4 Top(ftKB) Top(ND)(ftKB) Top Incl(") Item Des Com (i n) 37.0 37.0 0.00 Hanger Cameron Tubing Hanger SN:120309096-2 3.900 "' 55 507.9 507.6 4.48 Nipple-DB, 2.875"DS Nipple SN:T061441 2.875 XN,DS,D w11,405.9 5,172.0 72.42 Sliding Sleeve Baker CMU Sliding Slv(w/2.812"DS profile)in closed 2.810 ` position 11,461.7 5,188.9 72.35 Nipple-DB, 2.75"D Nipple w/RHC plug installed @-72° 2.750 f j XN,DS,D SN:T051138 11,510.9 5203.8 72.37 Locator Baker GBH-22 mechanical Locator sub 3.000 (( 11,512.0 5,204.1 72.37 Seal Assembly Baker 80-40 seal assembly 3.000 Surface;404-2,733.8 .I Mandrel;2,9399 17: I,:.,-;,,..,. .. 7 .. Mandrel.11,347.0 ° I; Sliding Sleeve;11.4059 `� la is: Mi Locator,11,510.9 1 Seal Assembly;11,512.0 ", I I1 1 i.i! 1 '". [: ' Intermediate;38.6-11,677.1 - I Iz I:4 312"Liner;11,504.6-12,949.0 • it CPAI Tarn 2N-312 * Name MD (feet) TVD (feet) TVDSS (feet) Base PFROST 1138 1126 967 CSG_10_34_Surf 2733 2415 2255 C-80 2918 2508 2349 CAMP SST 3046 2568 2409 0-50 7126 3864 3704 0-40 8017 4132 3973 0-37 8785 4372 4212 1-7 10589 4923 4763 T-6 10945 5032 4872 T-5 11266 5130 4970 T-4.1 11371 5162 5002 CSG_7_58_Int 11678 5254 5094 1-4 11698 5259 5100 T-3.1 11897 5319 5160 T-3 11971 5342 5182 TOP BERM 12172 5402 5243 BASE BERM 12557 5534 5374 TOP PURPLE 12574 5541 5382 BASE_PURPLE 12684 5588 5428 0-35 12737 5611 5451 K-3 12862 5671 5512 TD 12950 5715 5558 • S Conor©Phillips Time Log & Summary WeAview Web Reporting Report Well Name: 2N-312 Rig Name: DOYON 25 Job Type: DRILLING ORIGINAL Rig Accept: 5/7/2015 8:00:00 AM Rig Release: 6/3/2015 6:00:00 AM Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 05/05/2015 24 hr Summary RDMO of 2L-316 18:00 00:00 6.00 0 0 MIRU MOVE MOB P RDMO 2L-316 well; separate modules at interconnects and stamp apart to position for trucking. Skid rig floor to move position, Depart 2L with power and pump modules. Transport to 2N pad. Move distance =3.4 miles. Lower derrick, raise and remove chinking. Stomp pipe shed out from sub,transport pits to 2N. 05/06/2015 Split rig modules and move to 2N pad. Change stomper on Sub. Move modules together and start marrying modules with interconnects. 00:00 12:00 12.00 MIRU MOVE MOB P Transport pit module to 2N, Move equipment to 2N pad. Change out voltage regulator on cold start on Sub. Change out#1 stomper on Sub. Transport Drill pipe module to 2N, Pin Jeep to Sub and hook up to truck. Same with Casing shed. 12:00 00:00 12.00 MIRU MOVE MOB P Staging and positioning modules at 2N. Move Sub and casing shed to 2N,spot Sub over conductor. Stomp in and pin Casing shed and pipe shed to Sub. Level and shim. Lower cellar box, install grating and lower stairs. 35/07/2015 Continue to level and marry modules. Make crane pick with DDV spool, not plausible for rig floor. Load and PU5" DP. Page 1 of 35 r Time Logs > •` Date From To Dur S. Depth E. Depth Phase Code Subcode T <'Comment 00:00 12:00 12.00 0 MIRU MOVE RURD P Continue with cellar work, level modules and marry with interconnects on steam and electrical. Install Hand-Y-Berm around cellar. Rig stairs and landings. Lower C-section, Bridle up and un-pin top drive and blocks for scoping. Scope derrick with PU= 167K. Bridle down, Remove bridle yokes for top drive. Raise C-section. Accept Rig at 08:00 5/7/2015 PJSM with ASRC/DDI/CPAI reps for crane lift. Hoist DDV spooler to floor, weight= 10500 lbs. Remove DDV spooler from rigfloor; no room to move with it on the rigfloor. Lower C-section, calibrate block height, MU Kelly hose to top drive and raise cattle chute. Crew change. 12:00 20:00 8.00 MIRU MOVE RURD P Complete cattle chute and secure hydraulic lines and controls. Move and secure BOP carrier and MPD choke skid. PU riser and lower to cellar, set and NU same. NU surface annular atop riser, NU flow line and hole fill lines with jet lines. Install backer rod and secure flow box. NU pincher nipple. SIMOPs; load and strap 5"drill pipe, 291 joints and 12 joints of 4". Take on water to pits for testing and spud. Perform TOTCO calibrations, modify Hand-Y-Berm around cellar, post diverter signage and barricades. install spill containment for diverter. Perform derrick inspection and Pits PMs. 20:00 21:15 1.25 MIRU MOVE RURD P Change out saver sub to 4 1/2"IF, Cameron rep grease and energize slip flange,test same to 500 psi for 10 minutes,witnessed by P. Smith CPAI rep. 21:15 22:45 1.50 MIRU MOVE PULD P MU stands and PU 4" DP,stand back 12 stands. Tag up at 44.5' below RKB. PU and install mouse hole after 1st stand. 22:45 00:00 1.25 MIRU MOVE PULD P Change out elevators and PU 5"DP and stand back 9 with singles from pipe shed with mouse hole. 35/08/2015 Continue to PU 5"DP, PM Koomey and energize same. Cut and Slip, hold Pre Spud meeting, MU BHA#1 and clean out conductor. 00:00 05:30 5.50 MIRU MOVE PULD P PU 5"drill pipe and stand back 39 stands in derrick. PM Koomey and energize same. Page 2 of 35 Time Logs 4111 • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 12:00 6.50 MIRU MOVE PULD P PU 5"drill pipe singles and doubles. MU in the mouse hole and stand them back in the derrick. 12:00 14:30 2.50 MIRU MOVE PULD P Continue to PU 5"drill pipe singles and doubles. PU remainder of 121 to stand back in derrick. 14:30 16:00 1.50 MIRU MOVE PULD P LD mouse hole and PU 5 stands of 5" HWDP and stand back. 16:00 16:45 0.75 MIRU MOVE BOPE P Perform diverter test, function diverter with 5" DP, knife valve open in 14 seconds,Annular close in 34 seconds, 3000 psi IP accumulator, 2125 psi after function, 13 seconds for 200 psi recovery,49 seconds for full recovery. 6 bottle average= 1967 psi.Witness of test waived by AOGCC insp Matt Herrera. 16:45 18:45 2.00 MIRU MOVE SLPC P Slip and cut drill line;78'cut and slip on same. Calibrate blocks. 18:45 19:15 0.50 MIRU MOVE SVRG P Service rig and top drive. Service blocks. 19:15 20:00 0.75 MIRU MOVE SFTY P Pre Spud meeting with crew and drilling team. Hold table top diverter drill for Shallow Gas. 20:00 21:15 1.25 MIRU MOVE BHAH P MU Clean out BHA#1 as per SLB DD. 21:15 22:30 1.25 MIRU MOVE SEQP P Flood all lines with water and pressure test all lines to 3500 psi for 10 minutes. Flood jet line and verify flow line jet operation. Onload and fill surface lines and stack with 9.6 ppg DrilPlex mud. 22:30 00:00 1.50 MIRU MOVE DRLG P Clean out conductor from 44'to 158' with 550 GPM with 470 psi, 66%FO, 60 RPM with 5K Torque. 05/09/2015 Spud well(00:01)and drill to 190'. PU BHA#2, RIH and drill ahead in 13 1/2"surface to 1819'. 00:00 00:30 0.50 158 192 SURFA( DRILL DDRL P Spud 00:01 and drill 13 1/2"surface hole from 158'to 192'at 600 GPM " with 520 psi, 68% FO, 60 RPM with 5K torque and 4K WOB. AST/ART/ADT=0.25 hours. 00:30 01:15 0.75 192 0 SURFA( DRILL TRIP P POOH to motor, blow down top drive. 01:15 03:45 2.50 0 121 SURFA( DRILL BHAH P Change motor bend from 0 to 1.5° bend per SLB DD. MU BHA#2 per SLB DD and MWD to 93'. Perform scribe on motor/MWD/Gyro. 03:45 04:45 1.00 121 192 SURFA( DRILL SRVY P Obtain Gyro surveys while RIH. 04:45 05:00 0.25 192 215 SURFA( DRILL DDRL P Drill ahead from 192' to 215'at 550 GPM with 600 psi, 76% FO, 60 RPM with 2K torque. 05:00 06:15 1.25 215 215 SURFA( DRILL BHAH P POOH from 215'to 125' MD. Stand back the 5"HWDP and PU 3 joints of 7 1/4" NMDC. RIH from 125' MD to 215'MD----KOP 246'@ 0647 hrs 5/9/2015 Page 3 of 35 Time Logs ill • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 11:30 5.25 215 683 SURFA( DRILL DDRL P Drill 13 1/2"surface hole from 215'to 683'MD, 681'TVD,450 gpm, 539 psi. During directional work, 600 gpm, 669 psi, 79%F/O, 60 RPM,TQ 5K,WOB 15K, Off bottom pressure 600 psi. 11:30 12:00 0.50 683 683 SURFA( DRILL BHAH P PU Jar stand and RIH to 683' MD. Crew change. Tour losses=0 BBL. 12:00 18:30 6.50 683 1,250 SURFA( DRILL DDRL P Drill from 683'to 1250'MD, 600 gpm, 1290 psi. 32%F/0,60 RPM, TQ 3K,WOB 26K. PU=97K, S0= 93K, Rot=95K. AST=2.24,ART= 1.85,ADT=4.09,Ttl Bit hours=7.05, Jar hours=7.05. At 855'losses were realized 72 BPH, but quickly tapered off to no losses by 1025',with total losses for the event at 108 BBLS over about 3.5 hour time interval. 18:30 00:00 5.50 1,250 1,819 SURFA( DRILL DDRL P Drill from 1250'to 1819'MD, 600 gpm, 1540 psi. 38%F/0, 60 RPM, TQ 3K,WOB 26K. PU=97K, S0= 93K, Rot=95K. AST=2.24,ART= 1.85,ADT=4.09, Ttl Bit hours=6.28, Jar hours=6.28. Crew change. Tour losses= 108 BBL. X5/10/2015 Continue to drill Surface section to TD at 2743'MD, 2380'TVD. Circulate 8 BU while BROOH. Attempt to pull on elevators, after 5 stand, BROOH to HWDP, pull BHA to surface. 00:00 06:00 6.00 1,819 2,290 SURFA( DRILL DDRL P Drill 13 1/2"surface from 1819' to 2290'MD, 650 gpm, 1528 psi. 51% F/0, 80 RPM, TQ 6K,WOB 26K. PU= 120K, S0= 106K, Rot= 111K. AST=2.26,ART= 1.27,ADT=3.53, Ttl Bit hours= 13.62,Jar hours= 15.79. 06:00 12:00 6.00 2,290 2,645 SURFA( DRILL DDRL P Drill from 2,305'MD to 2,645'MD, 2,378'TVD. 750 GPM, 2015 psi. 86%F/O, 90 RPM, TO 5K,WOB 20K. PU= 120K, S0= 106K, Rot= 111K. AST=2.85,ART=0.75,ADT= 3.60, Ttl Bit hours= 17.22,Jar hours= 19.39. Pump 60 BBL nut plug sweep of 10 PPB Nut plug fine, 1%ScreenKleen, 1% DrilZone and chase at 750 GPM for 313 BBLs of mud. No losses this tour 12:00 13:45 1.75 2,645 2,743 SURFA( DRILL DDRL P Drill from 2,305'MD to 2,645'MD, 2,378'TVD. 750 GPM, 2015 psi. 86% F/0, 90 RPM,TQ 5K,WOB 20K. PU= 120K, S0= 106K, Rot= 111K. AST=2.85,ART=0.75,ADT= 3.60, Ttl Bit hours= 17.22,Jar hours= 19.39. Page 4 of 35 Time Logs ! Date From To Dur S. Depth E. DepthPhase Code Subcode T Comment 13:45 18:00 4.25 2,743 2,001 SURFA( CASING CIRC P Circulate and stand back a stand each BU. Circ at 775 GPM 1850 psi, 33%FO, 90 RPM with 5K Torque. Mud 9.9 ppg in and out. Pumped total of 2471 BBLs. 18:00 18:30 0.50 2,001 2,001 SURFA( CASING OWFF P Observe well for flow. No flow, Hydrates breaking out with slight drop in mud. Good. 18:30 19:15 0.75 2,001 1,530 SURFA( CASING TRIP P Pull on elevators from 2001'to 1530'. At 1586'encountered overpull of 50K and worked pipe and wiped out overpull. At 1514'encountered 50K overpull and could not work through. Made up topdrive for back-reaming. 19:15 21:30 2.25 1,530 780 SURFA( CASING BKRM P BROOH from 1530'to 780'at 750 GPM with 1520 psi,26%FO, 80 RPM with 2K torque, 21:30 21:45 0.25 780 690 SURFA( CASING PMPO P Pump OOH from 780'to 690'at 500 GPM with780 psi, 24%FO. 21:45 23:00 1.25 690 125 SURFA( CASING TRIP P POOH racking back the HWDP and DCs from 690'to 125'. Monitor fill via TT. 23:00 00:00 1.00 125 0 SURFA( CASING BHAH P LD BHA#2 per SLB DD and MWD; milk motor and break bit. X5/11/2015 LD BHA#2, RU to run 10 3/4"casing, Run casing per detail. BakerLok shoe track, check floats(Good)and RIH with casing. RIH toTD and circulate. 00:00 01:45 1.75 0 0 SURFA( CASING BHAH P Continue to LD BHA#2. 01:45 02:15 0.50 0 0 SURFA( CASING RURD P Clean and clear floor of BHA and stage casing running equipment. 02:15 03:00 0.75 0 0 SURFA( CASING RURD P Perform dummy run with 10 3/4" hanger per Cameron rep. Good at 40.35', mark landing joint. 03:00 03:45 0.75 0 0 SURFA( CASING RURD P RU casing running equipment and verify running order and staging of casing in shed. 03:45 04:00 0.25 0 0 SURFA( CASING SFTY P PJSM for running casing with crew, Tenaris rep, and GBR hand. 04:00 07:00 3.00 0 746 SURFA( CASING PUTB P Run 10 3/4"45.5#L-80 HyD 563 Dopeless casing, MU with Volant tool with MU torque of 19400 ft-lbs. BakerLok shoe track and check floats; Good. RIH to 373'. Plan to fill on the fly and top off every ten joints. 07:00 11:00 4.00 746 414 SURFA( CASING PULL T POOH with 10 3/4"casing from 746' to 414'due to loss of returns. Pump 1.5 bpm at 96 psi with minimal returns.At 414'established circulation and started staging pumps up to 3.5 bpm/190 psi,4 bpm/203 psi,4.5 bpm/215 psi, 5 bpm/247 psi. 15%flow, circulate 270 bbls. Page5of35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode- T Comment 11:00 12:00 1.00 414 455 SURFA( CASING PUTB T RIH with 10 3/4"casing from 414'to 455',washing down at 5 bpm, 230 psi, 73%flow. L/D joint#12, could not remove thread protector. Replace joint#12 with joint#69. Crew change. Losses for tour=64 BBL 12:00 14:30 2.50 455 746 SURFA( CASING PUTB T RIH with 10 3/4"casing from 455'to 746',washing down at 5 bpm, 230 psi, 73%flow. 14:30 23:15 8.75 746 2,734 SURFA( CASING PUTB P Continue running in the hole with 10 3/4"casing from 746 to 2734, washing down at 5 bpm 23:15 23:30 0.25 2,734 2,734 SURFA( CASING HOSO P MU hanger and landing joint and wash down to 2734'@ 5 BPM with 235 psi, 18%FO. 23:30 00:00 0.50 2,734 2,734 SURFA( CEMEN-CIRC P Circulate at 5 BPM with 230 psi, 16% FO,while reciprocating from 2733'to 2713'. Crew change. Losses for tour = 25.5 BBL. Day losses=89.5 BBL 05/12/2015 Circulate with casing on bottom, RU cementers and perform surface cement per program, bump plugs OK increase to 922 psi and hold. Check floats-not holding. Hold 600 psi on floats for 6.5 hrs to 100 psi UCA, check floats OK. N/U diverter and N/U wellhead. Test seals 5000 psi. Continue N/U BOPE. 00:00 03:36 3.60 2,734 2,734 SURFA( CEMEN-CIRC P Circulate at 5 BPM with 230 psi, 16%FO,while reciprocating from 2733'to 2713'. Stage pumps to 8 BM with 240 psi. Stage trucks and RU for cmenting while circulating. Clean cuttings tank. 03:36 04:00 0.40 2,734 2,734 SURFA( CEMEN RURD P Set on slips and blow down top drive and RU cement hose after circulating 1481 bbls @ 8bpm. 04:00 04:45 0.75 2,734 2,734 SURFA( CEMEN CIRC P Stage circulate to 8 BPM with 350 psi, 10%FO,while reciprocating from 2733'to 2713'. Continue to stage products on trucks and pits. 04:45 05:15 0.50 2,734 2,734 SURFA( CEMEN-SFTY P PJSM for cementing job with SLB cementers,Truck drivers, rig crew and CPAI rep. Sim ops: Continue to circulate @ 8 bpm and reciprocate 20'f/2734'to 2714'. 05:15 05:45 0.50 2,734 2,734 SURFA( CEMEN CIRC P Continue circulating while Dowell prepares to take on water for cement job. Circulated 824 bbls @ 8 bpm through cement hose. Final mud properties: MW 9.7 ppg, PV/YP 16/19,gels 12/14/15. 05:45 06:00 0.25 2,734 2,734 SURFA( CEMEN-SEQP P Dowell pump 5 bbls water, then test lines to 3500 psi-good. 06:00 06:15 0.25 2,734 2,734 SURFA( CEMEN CMNT P Dowell batch up MudPushll @ 10.5 ppg w/2-1/2 gallons of red dye. Page 6 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T : Comment 06:15 06:45 0.50 2,734 2,734 SURFA( CEMEN.CMNT P Dowell Pump 94.1 bbls of 10.5 ppg MudPush II w/2-1/2 gallons of red dye,average 5.5 bbl/min. Reciprocate casing 20'. PU wt 160k, SO wt 116k. Load bottom plug, install with the Volant casing running tool. 06:45 07:45 1.00 2,734 2,734 SURFA( CEMEN-CMNT P Dowell mix ALC cement(Yield 1.93 cuft/sx, mix H2O 6.496 gal/sx, Thickening time 4.35 hrs) to 11 ppg, then pump @ average of 6.6 bpm w/ 240-260 psi. Pumped a total of 304 bbls(884 sx)when MudPush w/red dye was seen at the shakers. Finished pumping down tanks for a total of 325.5 bbls(947 sx)of ACL cement. Reciprocate casing 20'. PU wt 168k, SO wt 113k. 07:45 08:00 0.25 2,734 2,734 SURFA( CEMEN-CMNT P Dowell batch up LiteCrete tail cement to 12 ppg(Yield 1.62 cuft/sx, mix water 5.463 gal/sx, Thickening time 4.55 hrs). 08:00 08:15 0.25 2,734 2,734 SURFA( CEMEN-CMNT P Dowell pump LiteCrete tail cement (Yield 1.62 cuft/sx, mix water 5.463 gal/sx, Thickening time 4.55 hrs). , then pump @ average of 5 bpm w/ 206-300 psi. Pumped a total of 63.1 bbls(219 sx). Reciprocate casing 20'. Broke over @ 190k,then PU wt 160k, SO wt 105-95k. 08:15 08:30 0.25 2,734 2,734 SURFA( CEMEN-CMNT P Load top plug, install with the Volant casing running tool. Dowell pump 10 bbls of water to clear lines @ 6 bpm w/218 psi. Attempt to reciprocate pipe and did not break free @ 288k PU wt. Landed casing on hanger. opened(2) 4"valves on conductor to take returns to the cellar. Page 7 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 09:15 0.75 2,734 2,734 SURFA( CEMEN-CMNT P Rig displaced cement w/9.8 ppg Drilplex mud. Initially displacing @ 8 bpm w/500 psi taking returns to the cellar, had to slow down to keep up sucking returns. Slowed to 7 bpm w/ 404 psi at 40 bbls pumped,then 6 bpm w/250 psi after pumping 60 bbls.Was able to increase rate to 7 bpm after pumping 100 bbls of mud and continued at that rate until slowing down to 3 bpm prior to bumping plug @ 240 bbls pumped. Initial pressure @ 7 bpm was 450 bbls after 100 bbls pumped, final pressure before slowing to 3 bpm was 600 psi. Slowed to 3 bpm w/ 340 psi after pumping 240 bbls and bumped the plug with 245.1 bbl pumped(95%pump efficiency, 2420 strokes)@ 0900 hrs. Increased pressure to 900 psi. 94.7 bbls of good 11 ppg cement returns. Held pressure f/5 minutes, bleed off pressure to check floats-did not hold. Repressure to 900 psi, bled off to check floats-did not hold, repressured to 600 psi and shut in until cement achieves 100 psi compressive strength.Will hold 600 psi until 1600 hrs. 09:15 12:00 2.75 2,734 2,734 SURFA( CEMEN-WOC T Flush stack of cement, clear some tools f/floor. Clean pits, manifest loads of mud and cement returns to disposal. Function 21-'/4'annular several times, drain stack fill with black water, drain, blow down hole fill and jet lines. Continue holding up to 615 psi shut in waiting on 100 psi compressive strength. 12:00 16:00 4.00 2,734 2,734 SURFA( CEMEN-WOC T Continue to hold 600 psi on casing until 100 psi compressive strength. SIMOPS-Rig down diverter, Rig down hole fill and jet lines. R/D& clean out flowline. Inspect cuttings tank butterfly valves. 16:00 17:00 1.00 2,734 0 SURFA( CEMEN-RURD P Bleed off pressure and check floats- (Holding). Rig down Volant CRT, Pull and L/D landing joint. 17:00 21:00 4.00 0 0 SURFA( CEMEN-NUND P Nipple down surface bag, pitcher nipple, 17'riser,diverter tee. Remove knife valve and L/D. Slide back Joes box. 21:00 22:00 1.00 0 0 SURFA( WHDBO NUND P Nipple up Cameron MBS T-104 Wellhead and test seals to 5000 psi 15 minutes witness by Co Rep. Page 8 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 SURFA( WHDBO NUND P Nipple up BOPE. M/U 2'adapter spool, 1.5'spool, 1'double stud and 14'riser. Install BOP, remove 1' spool to install Joes box over MPD RCD. 05/13/2015 Continue N/U BOPE, MPD. R/U and test BOPE to 250/3500 psi 5 min ea.Test MPD choke skid 250/1000 psi. Pull test plug, install wear bushing, R/D test equip. P/U BHA#3 and RIH to 2541' MD. C&C, R/U and begin casing test 3000 psi 30 min. 00:00 04:00 4.00 0 0 SURFA( WHDBO NUND P Continue N/U BOPE and riser spools. 04:00 07:30 3.50 0 0 SURFA(WHDBO MPDA P Remove MPD RCD air valve and Katch Kan, Rotate RCD air valve'/4 turn, N/U 13-5/8"risers, 11x13-5/8" adapter, 1.5'and 1' DSA, 14'riser spools. Install Katch Kan, install 1502 flanges on OA and IA valves. Install flowline. Install RCD trip nipple,shim BOP carrier, chink Joes box, install PS-21 slips. 07:30 09:00 1.50 0 0 SURFA( WHDBO RURD P R/U to test BOPE. Install lower test plug. 09:00 12:00 3.00 0 0 SURFA(WHDBO BOPE P Perform initial BOPE test to 250/3500 psi with 5"test joint 5 min ea charted.AOGCC Matt Herrera waived witness of test. Manual operated and super choke tested to 250/2000 psi 5 min ea charted. Tested annular preventer,2-7/8"x 5-1/2" UPR,2-7/8"x 5-1/2"LPR, choke valves 1-15, manual and auto choke, choke and kill manuals and HCR valves, 4"valve on kill line, 5" TIW, 5"Dart valve, upper and lower [BOP. 12:00 13:45 1.75 0 0 SURFA( WHDBO BOPE P Perform Koomey drawdown test. Accumulator PSI=3000 psi, Manifold=1500 psi, System pressure1575 psi after all functions on bottles.200 psi attained=21 sec with 2 electric pumps, full system pressure attained 113 sec with 2 electric and 2 air pumps.6 bottle N2 average=2029 psi. 13:45 14:15 0.50 0 0 SURFA( WHDBO BOPE P Perform CPAI pump performance test,2 electric pumps=56 seconds, 2 air pumps= 147 sec. Closing times;Annular=22 sec, UPR=17 sec, Blind/shear=l8 sec, LPR=16 sec, Choke HCR=2 sec, Kill HCR= 2 sec. 14:15 14:30 0.25 0 0 SURFA( WHDBO MPDA P Pull power slips, remove trip nipple and install RCD test plug. 14:30 16:45 2.25 0 0 SURFA( WHDBO MPDA P Test MPD choke skid, all tests 250/1000 psi 5 min ea charted. Perform body test against BV-6 and LT-4,test air valve. Page 9 of 35 Time Logs 411 Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 18:00 1.25 0 0 SURFA( WHDBO RURD P Blow down MPD skid, choke and kill lines. Remove RCD test cap and install trip nipple. Pull test plug, drain stack and install wear bushing. R/D all test equipment. 18:00 19:45 1.75 0 182 SURFA( CEMEN-BHAH P P/U BHA#3 to 182' MD per DD/MWD, install RA source in Ecoscope. 19:45 20:45 1.00 182 747 SURFA( CEMEN TRIP P RIH with HWDP from 182' MD to 747' MD. 20:45 21:00 0.25 747 747 SURFA( CEMEN-BHAH P L/D jars from stand in derrick, change out to new jars. Monitor well via TT. 21:00 22:30 1.50 747 2,449 SURFA( CEMEN-TRIPP RIH on 5"DP from 747' MD to 2449' MD. P/U ghost reamer on stand#15. 22:30 23:30 1.00 2,449 2,541 SURFA( CEMEN CIRC P Fill pipe and circulate while R&R from 2446'MD to 2541' MD @ 450 gpm, 1050 psi, 12%flow out, 50 rpm, 5.5k Tq. Condition mud for casing test. S/D and B/D top drive. 23:30 00:00 0.50 2,541 2,541 SURFA( CEMEN PRTS P R/U for casing test. Test 10%"45.5# L-80 casing to 3000 psi charted, pumped 3.8 bbl. 05/14/2015 Complete casing test. P/U RCD bearing and pressure test MPD system with bearing installed. Rack back bearing stand, install trip nipple and drill out cement, float equip, 20'formation. Displace to 9.6 ppg LSND and perform FIT 16.6 ppg EMW. Begin drilling 9-7/8"intermediate from 2763' to 3302' MD 00:00 01:00 1.00 2,541 2,541 SURFA( CEMEN-PRTS P Continue testing 10%4"45.5#L-80 casing to 3000 psi for 30 minute charted(3350 psi). Pumped 3.8 bbl, bled back 3.7 bbl. Blow down cement and kill lines, rig down test equipment. 01:00 04:00 3.00 2,541 2,541 SURFA( CEMEN MPDA P PJSM, pull PS-21 slips, remove trip nipple, install master bushings. P/U stand#20 and install MPD bearing. Pump thru MPD choke skid 300 gpm, 455 psi, 5%flow out. 04:00 05:00 1.00 2,541 2,541 SURFA( CEMEN MPDA P R/U and Test MPD BV-5 Gut line valve, chokes A and B to 300 psi low, 1000 psi high. Bleed off pressure, open chokes and kill line. 05:00 06:00 1.00 2,541 2,541 SURFA( CEMEN-MPDA P PJSM, remove MPD bearing, rack back bearing on stand#80. Install trip nipple, blow down MPD choke skid. 06:00 06:30 0.50 2,541 2,644 SURFA( CEMEN COCF P Obtain parameters at 2549' MD, P/U=121k, S/O=96k, ROT=108k,30 rpm, 6k Tq off, 150 gpm 137 psi, 12%flow out. RIH and locate TOC @ 2644'MD, 3-5k WOB. SPR's @ 2575'MD, 2329'TVD, 9.7 ppg, 05:50 hrs. #1-20 spm=70 psi, 30 spm=80 psi #2-20 spm=60 psi, 30 spm=80 psi Page 10 of 35 Time Logs ill • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 12:00 5.50 2,644 2,704 SURFA( CEMEN-DRLG P Drilling cement and float equipment from 2644'MD to 2647'MD,60 rpm, 6-7k Tq, 500 gpm @ 1789 psi, 13% flow out, 6-15k WOB. Increase pump rate to 550 gpm, 2089 psi, 15%flow out. Drill cement from 2647' MD to 2704'MD, 100 rpm, 3-7k Tq, 2-5k WOB, 550 gpm @ 1450 psi, 14% flow out. 12:00 13:15 1.25 2,704 2,732 SURFA( CEMEN'DRLG P Continue drilling shoe track from 2704'MD to 2732'MD @ 550 gpm, 1340 psi, 15%flow out, 60 rpm, 5.5k Tq. Top of shoe @ 2730.5'MD. 13:15 13:45 0.50 2,732 2,732 SURFA( CEMEN-SVRG P Service topdrive and crown. SIMOPS C/O washpipe. 13:45 14:45 1.00 2,732 2,743 SURFA( CEMEN-DRLG P Continue drilling out shoe from 2732' MD, rathole to 2743'MD. 14:45 15:00 0.25 2,743 2,763 SURFA( CEMEN DDRL P Drill 20' New formation to 2763'MD, 550 gpm, 1350 psi, 15%flow out, 8k WOB,6k Tq.ADT= .18 hrs. 15:00 16:00 1.00 2,763 2,763 SURFA( CEMEN-DISP P Displace well to 9.6 ppg LSND @ 600 gpm with 50 bbl high vis spacer followed with 9.6 ppg mud. 1400 psi, 17%flow out, 60 rpm, 6k Tq until MW in/out 9.6 ppg. Obtain SPR's, P/U=119k, S/0=99k, ROT=107k. 16:00 17:00 1.00 2,763 2,763 SURFA( CEMEN FIT P Blow down topdrive, R/U for FIT. Lower pulsation dampener to 300 psi. Perform LOT to 875 psi with 9.6 ppg mud for 16.6 ppg EMW. 1.2 bbl pumped, 1.2 bbl bled back. 17:00 17:30 0.50 2,763 2,763 INTRM1 DRILL RURD P Rig down and blow down test equipment. Raise pulsation dampener to 750 psi. SIMOPS- re-install PS-21 slips. 17:30 00:00 6.50 2,763 3,302 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate hole from 2763' MD to 3302' MD, 2678'TVD. 700 gpm, 1920 psi, 20% flow out, 130 rpm,Tq on/off=7k/4.5k, 8k WOB. P/U=125k, S/0=108k, ROT=108k,ADT=4.66, Total bit hrs=4.84, Total jars=4.84. Campanian sands©—3047', no gas observed drilling or on connections. 35/15/2015 Continue drilling 9-7/8"intermediate section from 3302'MD to 5574'MD, 3386'TVD. Stop drilling due leaking upper IBOP valve. BROOH to 4635'MD. 00:00 05:30 5.50 3,302 3,965 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 3302'MD to 3965'MD, 2998' TVD. 700 gpm-2180 psi,20%flow out, 150 rpm, Tq on/off=10k/7k. WOB=6k, ECD=10.84 ppg, P/U=131k, S/0=104k, ROT=111 k, ADT=3.89,Total bit/Jar hrs=8.73, Pumped 42 bbl Hi Vis sweep @ 3583' MD, no noticable increase in returns. Page 11 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 06:30 1.00 3,965 3,965 INTRM1 DRILL RGRP T M/U stand#35 @ 3965' MD, 2998' TVD. Reset Amphion due to high line power surge. Reset Amphion, re-calibrate block height. Establish circulation 3 bpm 170 psi,4%flow out. Flow check 5 min. 06:30 12:00 5.50 3,965 4,533 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 3965'MD to 4533'MD,2998' TVD. 700 gpm-2340 psi, 20%flow out, 150 rpm, Tq on/off=9k/5k. WOB=9k, ECD=11.0 ppg, P/U=130k, S/0=105k, ROT=111k, ADT=3.41,Total bit/Jar hrs=12.14. SPR's @ 3961'MD, 2897'TVD, 9.65 ppg, 05:20 #1-20 spm=140 psi, 30 spm=160 psi #2-20 spm=120 psi, 30 spm=160 psi 12:00 18:00 6.00 4,533 5,274 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 4533'MD to 5274' MD, 3293' TVD. 700 gpm-2580 psi,20%flow out, 130 rpm, Tq on/off=11k/6k. WOB=10k, ECD=11.2 ppg, P/U=143k, S/0=102k, ROT=116k, ADT=4.74,Total bit/Jar hrs=16.88. SPR's @ 5100'MD, 3239'TVD, 9.6 ppg, 16:30 #1-20 spm=160 psi, 30 spm=200 psi #2-20 spm=160 psi, 30 spm=200 psi 18:00 21:15 3.25 5,274 5,574 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 5274'MD to 5574'MD,3386' TVD. 700 gpm-2660 psi,20%flow out, 140 rpm, Tq on/off=12k/6k. WOB=10k, ECD=11.27 ppg, P/U=137k, S/O=93k, ROT=120k, ADT=2.34,Total bit/Jar hrs=19.22. Pumped Hi Vis sweep @ 5200', 5% increase in cuttings. SPR's©5573'MD, 3386'TVD, 9.6 ppg,21:15 #1-20 spm=160 psi, 30 spm=200 psi #2-20 spm=160 psi, 30 spm=200 psi 21:15 21:30 0.25 5,574 5,574 INTRM1 DRILL OWFF T Obtain SPR's, Observe well for flow- static with very slight drop. Prep for BROOH due leaking upper IBOP. Page 12 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 00:00 2.50 5,574 4,625 INTRM1 DRILL IBKRM T BROOH from 5574'MD to 4625' MD @ 700 gpm, 2700 psi, 140 rpm, 8-10k Tq,21%flow out, 1500 fph. Slowed rate to 600 fph as ECD rise from 11.3 pg to 11.5 ppg, hole unloaded ECD back to 11.1-11.2 ppg, resume 1500 fph. 05/16/2015 CBU x 3 @ 4625',flow check and pull to shoe on elevators. C/O IBOP upper and lower, saver sub.Test IBOP's to 250/3500 charted. RBIH and dilute LSND. Continue drilling 9-7/8"intermediate section from 5547' MD to 6922' MD. 00:00 00:30 0.50 4,625 4,625 INTRM1 DRILL CIRC T Circulate total 3 bottoms up @ 4625' MD(ghost reamer inside casing)700 gpm, 2700 psi, 22%flow out, 140 gpm, 8-10k Tq. Shakers cleaned up. 00:30 00:45 0.25 4,625 4,625 INTRM1 DRILL OWFF T Monitor well 10 minutes static, blow down top drive. 00:45 02:30 1.75 4,625 2,734 INTRM1 DRILL TRIP T POOH on elevators from 4625' MD to 2734' MD. Monitor displacement via trip tank, good fill lost.25 bbl for trip. 20k overpull @ 4190', 3730', 3620' MD,wiped through tight spots and cleaned up. P/U=130k, S/O=87k. 02:30 03:00 0.50 2,734 2,734 INTRM1 DRILL CIRC T Circulate bottoms up @ shoe reciprocating from 2734'MD to 2640' MD 600 gpm, 1765 psi, 70 rpm,4-5k Tq, 16%floiw out. No major cuttings returns. 03:00 03:30 0.50 2,734 2,734 INTRM1 DRILL OWFF T Blow down top drive, PJSM, monitor well=Static 03:30 06:30 3.00 2,734 2,734 INTRM1 DRILL RGRP T C/O Upper IBOP, Lower IBOP, NC50 saver sub. 06:30 07:30 1.00 2,734 2,734 INTRM1 DRILL BOPE T R/U and test Upper IBOP and Lower IBOP to 250/3500 psi 5 min each charted. 07:30 10:15 2.75 2,734 5,482 INTRM1 DRILL TRIP T RIH on elevators fom 2734' MD to 5482'MD, monitor displacement via TT-2. Fill pipe every 1500 ft. P/U=130k, S/O=92k. 10:15 10:30 0.25 5,482 5,547 INTRM1 DRILL REAM T M/U top drive to wash/ream down to 5547'MD stage pumps to 500 gpm, 1772 psi, 16%flow out, 100 rpm, 8-9k Tq. 10:30 12:00 1.50 5,547 5,547 INTRM1 DRILL CIRC T Circulate while R&R from 5543' MD to 5480'MD @ 500 gpm, 100 rpm while dumping and diluting 490 bbl LSND. Page 13 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 18:00 6.00 5,547 6,332 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 5574'MD to 6332'MD, 3619' TVD. 700 gpm-2590 psi,20%flow out, 170 rpm, Tq on/off=11k/7k. WOB=10k, ECD=10.58-10.97 ppg, P/U=161k, S/0=109k, ROT=128k, ADT=4.67,Total bit/Jar hrs=23.89. SPR's @ 6142'MD, 3560'TVD, 9.6 ppg, 16:36 hrs #1-20 spm= 180 psi, 30 spm=220 psi #2-20 spm= 170 psi, 30 spm=200 psi 18:00 00:00 6.00 6,332 6,922 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 6332'MD to 6922'MD, 3801' TVD. 700 gpm-2830 psi, 20%flow out, 170 rpm, Tq on/off=13k/8.5k. WOB=10k, ECD=10.9-10.6 ppg, P/U=179k, S/0=104k, ROT=133k, ADT=3.98,Total bit/Jar hrs=27.87. Bit balling @ 6865'MD&6919' MD. Pumped 50 bbl Nut Plug/SAPP/Skreenkleen sweeps. 05/17/2015 Continue drilling 9-7/8"Intermediate section to 8318' MD. Install MPD bearing and continue drilling to 8886' MD. Begin shutting in MPD chokes on connections at 8790', no pressure observed. 00:00 07:00 7.00 6,922 7,615 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 6332'MD to 7615' MD,4015' TVD. 700 gpm-2853 psi, 19%flow out, 170 rpm, Tq on/off=16.5k/9k. WOB=10k, ECD=11.09 ppg, P/U=187k, S/O=91k, ROT=137k, ADT=4.03,Total bit/Jar hrs=31.90. Pumped 56 bbl Nut Plug sweep 10 ppb @ 6950'MD to clean BHA. SPR's @ 6993' MD, 3823'TVD, 9.55 ppg, 01:45 hrs #1-20 spm=120 psi, 30 spm=170 psi #2-20 spm=110 psi,30 spm=160 psi 07:00 07:45 0.75 7,467 7,467 INTRM1 DRILL CIRC T Pick up from 7615' MD to 7558'MD, CBU @ 700 gpm 2806 psi, 19%flow out, 150 rpm, 16k Tq. CBU due rapid climbing ECD from 11.25 to 11.53 ppg EMW. Circulate down to 11.1 ppg EMW. SPR's©7562'MD, 3992'TVD, 9.6 ppg, 06:30 hrs #1-20 spm=160 psi, 30 spm=200 psi #2-20 spm= 160 psi, 30 spm=190 psi Page 14 of 35 Time Logs ill 4110' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:45 12:00 4.25 7,467 7,887 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 7615'MD to 7887'MD,4091' TVD. 700 gpm-2900 psi,20%flow out, 160 rpm, Tq on/off=17.5k/12k. WOB=10k, ECD=11.18 ppg, P/U=195k, S/0=104k, ROT=137k, ADT=3.1, Total bit/Jar hrs=35.00. Start backreaming 30'per stand, circulating cuttings above ghost reamer prior to connection to assist in reducing ECD. 12:00 13:45 1.75 7,887 8,036 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 7887'MD to 8036' MD,4137' TVD. 700 gpm-3060 psi,20%flow out, 160 rpm, Tq on/off=16k/14k. WOB=6k, ECD=11.2 ppg, P/U=194k, S/0=104k, ROT=138k, ADT=1.1, Total bit/Jar hrs=36.1. 13:45 14:30 0.75 8,036 8,036 INTRM1 DRILL CIRC P Dump and dilute LSND 580 bbl while R&R from 8036' MD to 7946'MD @ 700 gpm, 2450 psi,20%flow out, 160 rpm, 13k Tq. P/U=178k, S/O=113k, ROT=139k. 14:30 17:15 2.75 8,036 8,318 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 8036'MD to 8318'MD,4226' TVD. 700 gpm-2490 psi, 20%flow out, 160 rpm, Tq on/off=15k/11k. WOB=9k, ECD=10.81 ppg, P/U=177k, S/O=112k, ROT=139k, ADT=2.2, Total bit/Jar hrs=38.3. Continue backreaming 20-30'per stand, circulating cuttings above ghost reamer prior to connection to assist in reducing ECD. SPR's©8318'MD,4226'TVD, 9.6 ppg, 18:16 hrs #1-20 spm=200 psi, 30 spm=240 psi #2-20 spm=210 psi, 30 spm=240 psi 17:15 18:15 1.00 8,318 8,318 INTRM1 DRILL MPDA P Backream stand#80 @ 700 gpm, 2520 psi, 20%flow out, 160 rpm, 13k Tq. Remove trip nipple and install MPD bearing assembly.Warm up bearing @ 50 rpm and establish circulation. Ream down stand#80. 18:15 00:00 5.75 8,318 8,886 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 8318'MD to 8886'MD,4402' TVD. 700 gpm-2915 psi,20%flow out, 160 rpm, Tq on/off=14k/11k. WOB=6k, ECD=11.13 ppg, P/U=185k, S/O=112k, ROT=138k, ADT=3.85,Total bit/Jar hrs=42.15. Start shutting MPD chokes on connection @ 8790' MD, no pressure build observed. Page 15 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/18/2015 24 hr summary Continue drilling 9-7/8"intermediate section from 8886' MD to 11519'MD, shutting in MPD chokes on connections monitoring for pressure, none observed. 00:00 06:00 6.00 8,886 9,467 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 8886'MD to 9467'MD,4597' TVD. 700 gpm-3058 psi, 20%flow out, 160 rpm, Tq on/off=13-15k/11k. WOB=10k, ECD=11.12 ppg, P/U=194k, S/O=116k, ROT=145k, ADT=3.7, Total bit/Jar hrs=45.85. Continue backreaming 20'per stand, circulating cuttings above ghost reamer prior to connection to assist in reducing ECD. Closing MPD chokes on connections, max 6 psi shut in, 35 psi drilling rate open chokes. SPR's @ 9452'MD,4575'TVD, 9.7 ppg, 05:30 hrs. #1-20 spm=220 psi, 30 spm=260 psi #2-20 spm=200 psi, 30 spm=250 psi 06:00 12:00 6.00 9,467 10,115 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 9467'MD to 10115'MD,4778' TVD. 700 gpm-2917 psi,20%flow out, 150 rpm, Tq on/off=14k/10-12k. WOB=8k, ECD=11.15 ppg, P/U=197k, S/O=118k, ROT=149k, ADT=3.27,Total bit/Jar hrs=49.12. Continue backreaming 20'per stand, continue closing MPD chokes on connections, no change in pressures. SPR's @ 9926'MD, 4270'TVD, 9.7 ppg, 10:05 hrs. #1-20 spm=240 psi, 30 spm=280 psi #2-20 spm=220 psi, 30 spm=270 psi 12:00 18:00 6.00 10,115 10,874 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 10115'MD to 10874'MD, 5010' TVD. 700 gpm-3130 psi,20%flow out, 160 rpm, Tq on/off=19k/13k. WOB=13k, ECD=11.25 ppg, P/U=204k, S/O=125k, ROT=153k, ADT=3.62,Total bit/Jar hrs=52.74. Continue backreaming 20'per stand, continue closing MPD chokes on connections, no change in pressures. Page 16 of 35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T- Comment 18:00 00:00 6.00 10,874 11,519 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 10874' MD to 11519'MD, 5206' TVD. 700 gpm-2970 psi, 20%flow out,160 rpm,Tq on/off=20k/13.5k. WOB=12k, ECD=11.21 ppg, P/U=208k, S/O=129k, ROT=156k, ADT=3.07,Total bit/Jar hrs=55.81. Continue backreaming 20'per stand, continue closing MPD chokes on connections, no change in pressures. Notified @ 23:40 that Kuparuk River Bridge is closed due high water. SPR's @ 10,967'MD, 5038'TVD, 9.6 ppg, 19:45 hrs. #1-20 spm=240 psi, 30 spm=280 psi #2-20 spm=220 psi, 30 spm=270 psi 05/19/2015 Continue drilling 9-7/8"intermediate section to TD, circulate hole clean, OWFF and BROOH to 3969'@ 1500 fpm, 700 gpm, 120 rpm. 00:00 02:00 2.00 11,519 11,688 INTRM1 DRILL DDRL P Directional drill 9-7/8"intermediate from 11519' MD to 11688'MD, 5257' TVD. 700 gpm-3066 psi, 20%flow out, 160 rpm,Tq on/off=19k/11 k. WOB=10k, ECD=11.19 ppg, P/U=210k, S/O=125k, ROT=159k, ADT=.9, Total bit/Jar hrs=56.71. Continue backreaming 20'per stand, continue closing MPD chokes on connections, no change pressure. SPR's @ 11687'MD, 5257'MD, 9.7 ppg, 03:30 hrs. #1-20 spm=260 psi, 30 spm=320 psi #2-20 spm=-260 psi, 30 spm=310 psi 02:00 04:15 2.25 11,688 11,630 INTRM1 CASING CIRC P Obtain SPR's, survey on bottom, pump 56 bbl Hi Vis sweep while R&R from 11688'-11625' MD @ 750 gpm, 3400 psi,20%flow out, 120 rpm, 13k Tq,total strokes 12282 rack back stand#116. 04:15 04:45 0.50 11,630 11,630 INTRM1 CASING OWFF P Monitor well for flow 30 minutes- static 04:45 08:30 3.75 11,630 11,630 INTRM1 CASING RGRP T Pump 66 bbl low vis sweep, Mud Pump#1 fluid end gasket failure. Circulate at reduced rate 355 gpm while replacing API ring. Circulate 355 gpm, 953 psi, 8%flow out, 120 rpm, 15-16k. 08:30 09:45 1.25 11,630 11,630 INTRM1 CASING CIRC P Pump 62 bbl Hi Vis sweep while R&R from 11630'MD to 11532' MD @ 750 gpm, 20%flow out, 3251 psi, 120 rpm, 15k Tq. Page 17 of 35 Time Logs • • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 11,630 10,587 INTRM1 CASING BKRM P Back ream out of hole @ 1500 fph from 11630' MD to 10587' MD 700 gpm, 2918 psi, 120 rpm, 13-15k, 19%flow out. 12:00 00:00 12.00 10,587 3,969 INTRM1 CASING BKRM P Continue back reaming out of hole from 10587'MD to 3969'MD 700 gpm, 2150 psi, 20%flow out, 120 rpm, 5k Tq. Monitor displacement via pits 1-4,total lost 3 bbl over displacement while backreaming from TD. 05/20/2015 Continue BROOH to casing shoe, CBU. R/D MPD bearing and OWFF 30 min static. POOH and L/D BHA. R/D RCD off BOP stack due height restriction,dummy run hanger. R/U and begin running casing to 2187' MD. 00:00 04:00 4.00 3,969 2,734 INTRM1 CASING BKRM P Continue backreaming out of hole from 3969'MD to 2834'MD 700 gpm, 2195 psi, 18%flow out, 120 rpm,6k Tq. Monitor displacement via pits 1-4,total 5 bbl loss for trip from bottom. 04:00 06:15 2.25 2,734 2,734 INTRM1 CASING CIRC P Circulate casing clean while R&R from 2734'MD to 2640'MD 600 gpm, 1598 psi, 80 rpm, 6k Tq. Pumped Hi Vis sweep fully around plus 4 bottoms up, still heavy clay and cavings returns, starting to taper off. Pumped second Hi Vis sweep to clean up what was left, shakers good and clean after 8 bottoms up. 06:15 06:45 0.50 2,734 2,734 INTRM1 CASING OWFF P Monitor well for flow for 30 minutes, static. 06:45 07:15 0.50 2,734 2,734 INTRM1 CASING MPDA P Pull MPD bearing and remove from drill pipe, install trip nipple. 07:15 07:45 0.50 2,734 2,734 INTRMI CASING CIRC P Pump 30 bbl dry job chase with 11 bbl, blow down top drive. 07:45 09:00 1.25 2,734 740 INTRM1 CASING TRIP P Pull out of hole on elevators from 2734' MD to 740'MD, laying down ghost reamer. Monitor displacement with trip tank#1, good hole fill. 09:00 09:30 0.50 740 740 INTRM1 CASING OWFF P Monitor well for 10 minutes-static. Change out slip inserts. 09:30 12:00 2.50 740 0 INTRM1 CASING BHAH P POOH from 740'MD, laying down 5" HWDP, NMDC and BHA per SLB DD/MWD reps. 12:00 12:30 0.50 0 0 INTRM1 CASING RURD P Clean and clear rig floor. 12:30 13:30 1.00 0 0 INTRMI CASING BOPE P Drain and flush stack with stack washer @ 9 bpm. Lay down stack washer. Pull wear bushing and set test plug. Page 18 of 35 4110 Time Logs • Date From To Dur S.Depth E.Death Phase Code ' Subcode T Comment 13:30 15:30 2.00 0 0 INTRM1 CASING MPDA P Pull PS-21 slips, remove trip nipple. Nipple down RCD from BOP stack. Install pitcher nipple adapter, pitcher nipple and Joes box. (RCD had to be removed due to height restriction, would not be able to pick stack up high enough to set e-slips or terminate DDV control lines.) 15:30 17:30 2.00 0 0 INTRM1 CASING BOPE P Change upper pipe rams from 2-7/8"x5-1/2"VBR to 7-5/8"solid rams. R/U test equipment and test UPR's and annular preventer to 250/3500 psi 5 min each on chart with 7-5/8"test joint. 17:30 18:30 1.00 0 39 INTRM1 CASING RURD P Perform dummy run with Cameron 7-5/8"modified hanger, made marks for fully landed, 1'off, 2'off and 8'off to facilitate cementing with DDV lines terminated in modified hanger. 18:30 19:15 0.75 39 0 INTRM1 CASING RURD P R/U to run casing. R/U Doyon Volant CRT, bail extensions, elevators, pump in sub. Change PS-21 slip inserts.Verify pipe count in shed. 19:15 19:30 0.25 0 0 INTRM1 CASING SFTY P Held pre-job safety meeting on running 7-5/8"39"&29.7#Hydril 563 dopeless casing string with DDV. Rig crew, CPAI, Doyon casing, Tenaris. 19:30 20:30 1.00 0 437 INTRM1 CASING PUTB P M/U shoe track, pump through and check floats at joint#3-good. RIH with 10 joints 39#TN110 Hydril 563 to 437' MD. 20:30 00:00 3.50 437 2,187 INTRM1 CASING PUTB P Continue to run in hole with 39#-29.7#XO, 7-5/8"29.7#L-80 Hydril 563 dopeless casing as per detail from 437' MD to 2187'MD installing floating Volant Hydroform centralizers on each joint. Running speed 3000 fph. Proper displacement. 05/21/2015 Continue running casing to shoe, CBU. R/U Weatherford DDV spool and lines. Continue RIH with 7-5/8" string, CBU @—6000', 9500'. P/U DDV @ 9088' MD connect and function test. Continue RIH prep for cement job. 00:00 01:30 1.50 2,187 2,710 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 2187' MD to 2710' MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Install floating Volant hydroform centralizers every joint to joint#90. Filling casing on the fly and topping off every 10 jts. 01:30 02:30 1.00 2,710 2,710 INTRM1 CASING CIRC P Circulate bottoms up while R&R from 2710'MD to 2678' MD, stage pumps up to 6 bpm, 165 psi,7%flow out. P/U=103k, 5/0=97k. SIMOPS-Rig up DDV spooling unit and sheave, run airlines to control panel and spooler. Page 19 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 02:45 0.25 2,710 2,710 INTRM1 CASING CIRC P Drain stack to cellar,divert flow to cellar and establish circulation up to 3 bpm, taking returns to cellar, loading on vac trucks. Rate tested for cement job. 3 bpm 75 psi with annular closed. 02:45 07:30 4.75 2,710 5,070 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 2710'MD to 5070' MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Filling casing on the fly and topping off every 10 jts. 07:30 08:00 0.50 5,070 5,070 INTRM1 CASING CIRC P Break circulation,stage pumps up to 6 bpm, 345 psi, 6%flow out. Circulate bottoms up while R&R from 5070' MD to 5033' MD. 08:00 10:30 2.50 5,070 6,127 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 5070'MD to 6127'MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Filling casing on the fly and topping off every 10 jts. 10:30 11:30 1.00 6,127 6,127 INTRM1 CASING CIRC P Break circulation,stage pumps up to 8 bpm, 322 psi, 10%flow out. Circulate bottoms up while R&R from 6127' MD to 6092' MD. 11:30 17:15 5.75 6,127 9,072 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 6127'MD to 9072'MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Filling casing on the fly and topping off every 10 jts. 17:15 18:45 1.50 9,072 9,072 INTRM1 CASING CIRC P Break circulation,stage pumps up to 8 bpm,475 psi, 11%flow out. Circulate bottoms up while R&R from 9072'MD to 9032'MD. 9.7 ppg in 10.0 ppg out. SIMOPS-R/U power tongs&DDV control line equipment. 18:45 20:15 1.50 9,072 9,072 INTRM1 CASING PUTB P P/U Weatherford DDV and M/U same. Install hydraulic control lines and PT to 3000 psi. Function test DDV, 8 minutes to close, 7 minutes to open. 20:15 00:00 3.75 9,072 10,767 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 9072' MD to 10767' MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Filling casing on the fly and topping off every 10 jts. Install cannon clamps over each casing collar. 05/22/2015 Continue running casing to shoe depth. Terminate DDV lines in hanger. C&C, cement 7-5/8"string per program. Install and test packoff. Terminate DDV to wellhead and function. L/D 5"DP. Page 20 of 35 Time Logs III Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:30 2.50 10,767 11,640 INTRM1 CASING PUTB P Continue RIH with 7-5/8"29.7#L-80 Hydril 563 dopeless casing from 10767' MD to 11635' MD, monitor displacement via pits 2-3,torque all connections to 12.4k ft/lbs. Filling casing on the fly and topping off every 10 jts. Install cannon clamps over each casing collar. Pick up hanger and landing joint, RIH to 11640' MD 02:30 04:45 2.25 11,640 11,640 INTRM1 CEMEN-CIRCP Break circulation,stage pumps up to 8 bpm, ICP=660 psi, FCP=460, 9% flow out. Circulate bottoms up while R&R from 11640'MD to 11630'MD. 9.7 ppg in 9.8 ppg out. SIMOPS- Terminate DDV control line into hanger. 04:45 05:30 0.75 11,640 11,670 INTRM1 CEMEN-RURD P RIH to 11676' MD, 1'off landed. Blow down topdrive. R/U cement equipment. P/U and stage pumps up to 5 bpm through cement hose 430 psi, 5%flow out while reciprocating 11670'MD to 11655'MD 05:30 05:45 0.25 11,670 11,670 INTRM1 CEMEN-SFTY P PJSM for 7-5/8"cement job with DDI crew, SLB cementers, CPAI,ASRC, Peak, MI 05:45 09:30 3.75 11,670 11,677 INTRM1 CEMEN-CMNT P Cement 7-5/8"casing per program, pump 5 bbl water from truck.Test cement line to 4000 psi. Bleed off pressure and pump 51 bbl Mud Push II 11.5 ppg @ 5 bpm 405 psi 8%flow out. Shut down, drop bottom plug followed by 196 bbl 15.8 ppg Gas Block tail cement @ 5 bpm,436 psi, 5%flow out. Shut down drop top plug. Kick out plug with 10 bbl water displaced with 5099 strokes rig pumps 9.7 ppg mud. Started chasing @ 8 bpm, caught plug at 980 stks, slowed down to 2 bpm as plus went by the DDV. Displaced at 5 bpm.At 4700 stks reduced rate to 1 bpm, took returns to cellar lowering hanger to 1'off landed. Bump plugs @ 5099 820 psi, increase to 1320 psi held 5 minutes. Bleed pressure and check floats good. Flush stack and landing profile with water before landing hanger. Land casing on depth @ 11677' MD CIP 09:30. P/U=250k, S/O=124k. 09:30 12:00 2.50 11,677 0 INTRM1 CEMEN-RURD P Rig down and blow down cement equipment, clean 4" Demco valves, pull landing joint, remove slip inserts. Clean and clear rig floor. Clean out stack for packoff installation. SIMOPS-Bring in and work 4"drill pipe. Page 21 of 35 ' Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 14:30 2.50 0 0 INTRM1 CEMEN'WWSP P Continue cleaning flushing stack to install packoff. Cameron sheared rupture disc for DDV @ 200 psi. Install packoff and test to 5000 psi for 10 minutes witnessed by CPAI. Install blank flanges on OA/IA valves not being used. Pull packoff running tool, install 5"slip inserts. 14:30 17:00 2.50 0 0 INTRM1 CEMEN-SLPC P PJSM, Hang blocks,slip and cut 100'drilling line. Calibrate Amphion and Totco block height. 17:00 17:30 0.50 0 0 INTRM1 CEMEN-SVRG P Service and inspect blocks,topdrive and crown. 17:30 19:30 2.00 0 0 INTRM1 CEMEN-FRZP P Freeze protect well, pumped 107 bbl fresh water @ 80°F down OA @ 1 bpm initial, break over @ 980 psi stage up to 3 bpm, ICP=670 psi, FCP=840 psi. Swap to LEPD 84 bbl @ 1.5 bpm with injection pump ICP=750 psi, FCP=840 psi. Shut in OA pressure 840 psi @ 20:00. Blow down and R/D injection lines. SIMOPS-Set mousehole and begin laying down 5"drill pipe 1x1 via mousehole. 19:30 00:00 4.50 0 0 INTRM1 CEMEN'PULD P Continue laying down 5"drill pipe 1x1 via mousehole. 05/23/2015 Continue laying down 5"drill pipe. Break stack and swap out to shorter DSA. Re-install RCD head and MPD equipment. R/U and test BOP with 4"and 3'/2'test joints. 00:00 09:30 9.50 0 0 INTRM1 CEMEN PULD P Continue laying down 5"drill pipe 1x1 via mousehole. SIMOPS-remove discharge line mud pump#1 inspect for washout. 09:30 12:00 2.50 0 0 INTRM1 WHDBO MPDA P Nipple down BOP stack, change out spacer spools to lower stack. Rig up RCD head. SIMOPS-C/O upper rams to 2-7/8"x 5-1/2"VBR. _OA pressure @ 11:30 hrs=500 psi. 12:00 16:30 4.50 0 0 INTRM1 WHDBO MPDA P Torque 2'spacer spool to adapter flange and riser. N/U RCD head and equipment on top of BOP stack. Re-align stack and install trip nipple. 16:30 18:15 1.75 0 0 INTRM1 CEMEN RURD P Change out saver sub from 4'/z'IF to XT39. 18:15 20:00 1.75 0 0 INTRM1 WHDBO RURD P P/U 4"test joint and set test plug. R/U test equipment,flush and fill ,lines with water. Page 22 of 35 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 20:00 23:45 3.75 0 0 INTRMI WHDBO BOPE P Test BOPE to 250/3500 psi 5 min ea on chart w/4"&31A"test jts. Witness waived by AOGCC John Crisp. Manual and super chokes tested to 250/2000 psi.With 4"test jt tested annular, 2-7/8"x 5'/2"UPR, 2-7/8"x 5'/z'LPR,Test choke valves 1-15.Test manual operated and super auto choke, manual kill, choke and kill HCR valves,4"valve on Kill line,4"TIW valve,4"Dart valve, 31/2" TIW, 3'/2'Dart valve. Upper and lower IBOP. Continue with 3'/z'test jt 5/24. 23:45 00:00 0.25 0 0 INTRM1 WHDBO BOPE P Perform Koomey test,Accumulator system pressure=3000 psi, manifold pressure=1500 psi, Pressure after all function pumps off=1500 psi,200 psi attained=20 sec with 2 electric pumps, Full system pressure attained=111 sec with 2 electric and 2 air pumps. Closing times; Annular=23 sec, UPR=18 sec, Blind/shears=16 sec, LPR=16 sec, Choke HCR=2 sec, Kill HCR=2 sec. 6 bottle backup N2 average=1984 psi. SIMOPS-Install Katch Kan on stack,secure tree and adapter flange in cellar. 35/24/2015 Complete BOPE testing, pressure test MPD system. P/U BHA and single in to 10628', performing CBL log from 7600'MD 00:00 01:00 1.00 0 0 INTRM1 WHDBO BOPE P Continue testing BOPE, pull 4"test jt,test blind/shear rams to 250/3500 psi 5 min ea. Install 3'/2"test jt, test annular, 2-7/8"x 5-1/2"UPR and LP R's. 01:00 02:00 1.00 0 0 INTRMI WHDBO MPDA P R/D test jt, pull MPD trip nipple, install MPD test cap. Flush mud through choke skid and pressure test to 250/1400 psi 5 min each. Remove test plug, install trip nipple, blow down choke skid. 02:00 03:15 1.25 0 0 INTRMI WHDBO RURD P Drain stack, remove test plug, install wear bushing, run in 2 lock down screws. Lay down test joint. Blow down choke manifold, kill line and test pump. 03:15 04:30 1.25 0 0 INTRMI CEMEN-PULD P P/U 6 doubles 4"drill pipe, building 4 more stands, rack back in derrick. 04:30 08:00 3.50 0 506 INTRM1 CEMEN-BHAH P PJSM, P/U BHA#4 per SLB DD/MWD reps to 506' MD 08:00 08:30 0.50 506 506 INTRM1 CEMEN-SFTY P Performed kick while drilling drill, conducted with underbalanced drilling scenario. Held AAR. 08:30 09:30 1.00 506 506 INTRM1 CEMEN-SVRG P Service pipe shed,skate,top drive and blocks. Page 23 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 11:00 1.50 506 1,572 INTRM1 CEMEN-PULDP RIH picking up doubles from 506'MD to 1572'MD, monitor displacement via trip tank#2. 11:00 11:45 0.75 1,572 1,572 INTRMI CEMEN-DHEQ P Shallow pulse test MWD, stage pumps up to 220 gpm, 1233 psi, 6% flow out. 11:45 12:00 0.25 1,572 1,958 INTRMI CEMEN-PULD P Continue RIH picking up doubles from 1572'MD to 1958'MD, monitor displacement via trip tank#2. OA pressure @ 11:30 hrs=380 psi 12:00 18:00 6.00 1,958 2,658 INTRM1 CEMEN-PULD P Continue RIH picking up doubles from 1958'MD to 2658'MD, P/U singles from 2658'MD to 7433' MD monitor displacement via trip tank #2, filling pipe every 20 stands. 18:00 18:30 0.50 2,658 7,433 INTRMI CEMEN-CIRCP Establish circulation filling pipe and send downlink to sonicscope tool for loggong. Stage pump up to 225 gpm, 1680 psi, 6%flow out. Blow down top drive. 18:30 00:00 5.50 7,433 10,628 INTRM1 CEMEN PULD P Continue RIH with singles from 7433' MD, begin CBL logging from 7600' MD to 10628' MD @ 900 fph CBL logging. Monitor displacement via trip tank, filling every 2000'. SIMOPS- load 3'/z'tubing in pipe shed, mobilize 3"gun lines in pits. Building 10.2 ppg LSND and reconditioning existing 9.7 to 10.2 ppg. OA pressure @ 23:30 hrs=340 psi 05/25/2015 Continue singling in performing CBL to TOC. C&C and test casing 3000 psi,drill out and perform FIT to 16.0 ppg EMW. Install MPD, fingerprint system and drill 6'/z'section per program. 00:00 02:30 2.50 10,628 11,568 INTRM1 CEMEN PULD P Continue RIH picking up singles from pipe shed from 10628'MD to 11568' MD @ 900 fph CBL logging. Monitor displacement via trip tank 1, filling pipe every 20 stands. P/U=182k, S/O=70k. 02:30 03:30 1.00 11,568 11,586 INTRM1 CEMEN COCF P Obtain SPR's and parameters, P/U=180k, S/O=70k, ROT=119k, 12k Tq. Stage pumps up to 180 gpm, 1530 psi, 6%flow out, 25 rpm, 12-14k Tq.Wash down from 11568' MD tag up on cement 11568' MD. Clean out to 11586'MD tag up on top plug. SPR's @ 11444'MD, 5194'TVD, 9.7 ppg, 02:30 hrs #1-20 spm=660 psi, 30 spm=910 psi #2-20 spm=600 psi,30 spm=920 psi Page 24 of 35 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:30 1.00 11,586 11,586 INTRM1 CEMEN-CIRCP CBU while R&R from 11584' MD to 11504' MD @ 215 gpm, 2400 psi, 6%flow out,25 rpm, 9k Tq. 04:30 06:00 1.50 11,586 11,586 INTRM1 CEMEN-PRTS P Rack back stand#116, rig up for casing test. Perform casing test to 3000 psi for 30 minutes charted, held 99.2%. Rig down and blow down test equipment. 06:00 08:00 2.00 11,586 11,688 INTRM1 CEMEN-DRLG P Drill cement plugs and float collar from 11586'MD to 11590' MD @ 200 gpm, 2075 psi, 100 rpm, 14k Tq, 5k WOB. Continue drilling cement down to 11675' MD,tag shoe @ depth 11675' MD. Drill shoe out to 11677' MD and rat hole to 11688'MD. 08:00 08:45 0.75 11,688 11,708 INTRM1 CEMEN DDRL P Drill 6'W production hole from 11688' MD to 11708'MD, 5263'TVD @ 200 gpm, 2200 psi, 8%flow out, 100 rpm, 14k Tq, 10k WOB. P/U=208k, S/0=60k, ROT=122k,ADT=.49, Total bit hrs=.49, Total Jar hrs=94.8. 08:45 10:45 2.00 11,708 11,708 INTRM1 CEMEN'CIRC P Rack back stand#119, circulate and condition while R&R from 11695'MD to 11600' MD, 200 gpm,2169 psi, 100 rpm, 34%flow out(cement contamination), 15-16k Tq, 10:45 12:00 1.25 11,708 11,708 INTRM1 CEMEN LOT P Lay down top single of stand#118, rig up for FIT. Establish circ down drill string and kill line. Perform FIT to 16.0 ppg EMW. 1724 psi. Rig down and blow down lines. P/U single. Clean pits 2-3 to displace to 10.2 ppg LSND. OA pressure @ 11:30 hrs=440 psi 12:00 14:15 2.25 11,708 11,708 PROD1 DRILL DISP P Displace well from 9.7 ppg LSND to 10.2 ppg re-conditioned LSND while R&R from 11610'MD to 11700'MD. Stage pumps up to 210 gpm, 2040 psi,6%flow out, 50 rpm, 12k Tq, FCP=2000 psi,4924 total strokes pumped. 14:15 15:00 0.75 11,708 11,708 PROD1 DRILL MPDA P Rack back stand#118 to 11609' MD. Blow down top drive, pull trip nipple, P/U and install RCD bearing assembly. 15:00 17:15 2.25 11,708 11,708 PROD1 DRILL MPDA P Establish circulation,wash down from 11609'MD to 11682' MD. Perform MPD fingerprinting at and MPD choke parameter adjustments as per MPD rep. Obtain SPR's. SPR's @ 11708'MD, 5263'TVD 10.2 ppg, 17:05 hrs #1-20 spm=540 psi, 30 spm=810 psi #2-20 spm=530 psi, 30 spm=800 psi Page 25 of 35 Time Logs • Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 17:15 00:00 6.75 11,708 12,068 PROD1 DRILL DDRL P Drill 6'/2'production hole from 11708' MD to 12068' MD, 5370'TVD @ 255 gpm, 2850 psi, 23%flow out, 150 rpm, 11k Tq, 15k WOB, ECD=11.7 ppg, P/U=160k, S/0=92k, ROT=114k,ADT=5.48, Total bit hrs=5.97,Total jar hrs=100.28. OA pressure @ 23:30 hrs=500 psi 35/26/2015 Drill to section TD of 12950'. Circulate and finger print with MPD and monitor. Weight up from 10.2 to 10.5 ppg. Monitor; Static. 00:00 06:00 6.00 12,068 12,393 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 12,068'MD to 12,393' MD, TVD 5,471'. 255 GPM,2,832 PSI,25% F/O, 150 RPM, 10K TQ,4K WOB, OFF BTM 2,800 PSI, PUW 172K, SOW 90K, ROT 122K.ART/ADT 3.91 HRS, BIT 9.88 HRS,JARS 104.19 HRS. 06:00 12:00 6.00 12,393 12,879 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 12,393'MD to 12,879' MD,TVD 5,677'. 255 GPM,2,950 PSI,24% F/O, 150 RPM, 10K TQ, 15K WOB, OFF BTM 2,816 PSI, PUW 163K, SOW 92K, ROT 125K,ART/ADT 4.35 HRS, BIT 14.23 HRS,JARS 108.36 HRS. OA PSI @ 11:30 HRS 580 PSI. Crew change. 12:00 13:15 1.25 12,879 12,950 PROD1 DRILL DDRL P Drill 6 1/2"production hole from 12,879' MD to 12,950'TD, TVD • 5,715'. 255 GPM,2,965 PSI, 26% F/O, 175 RPM, 10K TQ, 17K WOB, ECD 11.81, OFF BTM 2,940 PSI, PUW 162K, SOW 96K, ROT 120K, 10K TQ,ART/ADT.85 HRS, BIT 15.08 HRS, JARS 109.39 HRS. 13:15 17:00 3.75 12,950 12,745 PROD1 CASING CIRC P Obtain survey and circulate 3 BU racking back 1 stand every BU.255 GPM, ICP 2,950 PSI, 26%F/O, 110 RPM, 7K TQ. From 12,950'to 12,935'(3000 strokes), 12,935'to 12,840' (4,694'strokes), 12,840'to 12,745'(3,847 strokes),total BBLs 1162 pumped, FCP 2,800 PSI. 17:00 17:45 0.75 12,745 12,745 PROD1 CASING OWFF P Monitor well for 15 minutes with choke closed. IP 5 PSI, stabilizing at 8 PSI. Open RCD port and monitor for 25 minutes with minimal flow back. Page 26 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 20:30 2.75 12,745 12,950 PROD1 CASING CIRC P Weight up system from 10.2 to 10.5 ppg. Rotate and reciprocate at 255 gpm with 2775 psi, 25% FO, 80 RPM with 7K torque. Total of 798 BBL pumped. Obtain SPR's. Peak gas with 10.2 ppg in the hole at BU was 2620 units. 20:30 21:00 0.50 12,950 12,950 PROD1 CASING OWFF P Mud in and out 10.5 PPG. Monitor well for 10 minutes with choke closed with no pressure build. Open RCD port and monitor for 25 minutes with minimal flow back. 21:00 22:15 1.25 12,950 12,950 PROD1 CASING CIRC P Circulate BU to condition mud with above parameters with total gas peak at 976 units with 10.5 ppg in the hole. SIMOPs; Top off cement in surface annulus with 1.36 BBLs to bring to surface. 22:15 23:30 1.25 12,950 12,950 PROD1 CASING OWFF P Monitor well with closed chokes with no pressure build after 10 minutes. Monitor to atmosphere with 15 gal/hr and slowing to static. 23:30 00:00 0.50 12,950 12,950 PROD1 CASING MPDA P LD single not in string, blow down top drive and establish pressrue parameters to stripping schedule per MPD while circulating across the top. Crew change. No losses for tour/day. OAP=440 psi. 05/27/2015 Pull to shoe and monitor Static. Strip out of hole with MPD to 2588'exercise DDV. POOH and LD BHA. RU for running liner, PJSM, Run liner to 1175'. 00:00 01:30 1.50 12,950 11,603 PROD1 CASING TRIP P Strip out of the hole with MPD back pressure schedule from 12950'to 11603'. 01:30 02:00 0.50 11,603 11,603 PROD1 CASING OWFF P Observe well for flow with documented decreasing flow as seen on last monitor. 02:00 06:00 4.00 11,603 7,338 PROD1 CASING TRIP P Strip out of the hole per MPD back pressure schedule from 11603'to 7,338'. Drop 2.40" Rabbit, strip out of the hole holding pressure on the annulus. Hold pressure per MPD trip schedule, 250 psi/2,000', 30 psi while in slips. Monitor displacement at pits 2 and 3. 06:00 11:15 5.25 7,338 601 PROD1 CASING TRIP P Strip out of the hole per MPD pressure schedule from 7,338'to 601'. 180 psi/2000', 30 psi while on the slips. Function DDV at 2,306'. 11:15 12:00 0.75 601 601 PROD1 CASING OWFF P Observe well for flow with a measured flow rate at the RCD 2" choke line. Steady 1/16"to 1/8" stream. Closed DDV and saw no change in the flow rate. Function DDV close then open and leave open. OAP=350 psi. Crew change. Page 27 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:30 1.50 601 601 PROD1 CASING OWFF T Continue to monitor well; continue to flow due to u-tube from drill pipe. Decision made to continue to pull and lay down BHA. 13:30 14:15 0.75 601 506 PROD1 CASING MPDA P Stand back last stand of drill pipe with RCD bearing hanging per MPD rep. Install trip nipple. 14:15 14:45 0.50 506 506 PROD1 CASING SVRG P Service and inspect PS-21 slips and change out slip inserts. 14:45 17:45 3.00 506 0 PROD1 CASING BHAH P Pull and LD BHA; remove and secure radioactive sources, breakdown and LD BHA components. Blow down MPD skid. 17:45 18:15 0.50 0 0 PROD1 CASING BHAH P Clean and clear floor. 18:15 19:00 0.75 0 0 COMPZ CASING RURD P RU casing running equipment, stage equipment to rig floor, verify running order and centralizer placement and style placement 19:00 19:30 0.50 0 0 COMPZ CASING RURD P PU single and assemble cement head,torqeu all connections to 22K. LD assembly to shed. 19:30 19:45 0.25 0 0 COMPZ CASING SFTY P PJSM for running liner with crew, Baker and Weatherford reps. 19:45 21:30 1.75 0 95 COMPZ CASING PUTB P PU and MU shoe track with Baker-Lok,fill and check floats; Good. 21:30 00:00 2.50 95 1,175 COMPZ CASING PUTB P PU liner from 95'to 1175'with make-up on connections=2900 ft-lbs. Fill on-the-fly and top off every 10 joints. OAP=240 psi, crew change. 13 BBLs loss for day. 05/28/2015 Run liner per detail, run liner in on drill pipe to TD. Tag and sapce out. Cement in place with TOL at 11504.56'. 00:00 00:45 0.75 1,175 1,389 COMPZ CASING PUTB P PU liner from 1175'to 1389'with make-up on connections=2900 ft-lbs. Fill on-the-fly and top off every 10 joints. 00:45 01:00 0.25 1,389 1,389 COMPZ CASING RURD P Change out slips and equipment for hanger make-up. 01:00 01:30 0.50 1,389 1,456 COMPZ CASING OTHR P PU and MU hanger per Baker rep. 01:30 02:30 1.00 1,456 1,456 COMPZ CASING OTHR T Measure out and re-configure running tools fit for purpose. Re-configure, MU and RIH. 02:30 03:00 0.50 1,456 1,456 COMPZ CASING CIRC P PU 1st stand, MU to top drive and establish circulation through liner hanger. Pump 17 BBL and 3 BPM with 215 psi,20% FO. PU=52K, S0=55K. 03:00 11:00 8.00 1,456 11,607 COMPZ CASING RUNL P RIH with 3 1/2"9.2#L-80 Hyd 563 liner on 4"drill pipe from 1,456'to 11,607'. Fill every 10 stands. Page 28 of 35 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 11:30 0.50 11,607 11,607 COMPZ CASING CIRC P Break circulation, reciprocating from 11,603'to 11,517'. Staging pumps up to 4.5 bpm, 1,170 psi, 19%F/O. Circulate liner and DP volume. PUW 146K, SOW 86K. Obtain SPR's. 11:30 12:00 0.50 11,607 11,879 COMPZ CASING RUNL P RIH into open hole with 3 1/2"9.2# L-80 Hyd 563 liner on 4"drill pipe from 11,607'to 11879'. 12:00 13:15 1.25 11,879 12,843 COMPZ CASING RUNL P RIH, (open hole),with 3 1/2"9.2# L-80 Hyd 563 liner on 4"drill pipe from 11,879'to 12,843'. 13:15 13:45 0.50 12,843 12,938 COMPZ CASING RUNL P Wash down from 12,843'to 12,938', 22 gpm,490 psi, 9%F/O. Stage pump to 65 gpm, 600 psi, 18% F/O. Reciprocate from 12,843'to 12,938', PUW 180K, SOW 86K. 13:45 14:30 0.75 12,938 12,938 COMPZ CEMEN-RURD P R/U cement head and hoses for cement job. 14:30 14:45 0.25 12,938 12,950 COMPZ CEMEN-CIRC P Break circulation,42 gpm, 400 psi, 10% F/O. Slack off and tag bottom 12,951.59 Liner strap depth. Set down 10K and pick up to break over at 12,950.25'. 14:45 17:45 3.00 12,950 12,949 COMPZ CEMEN-CIRC P CBU while recip with 168 GPM with ICP= 1175 psi, FCP=1120 psi, 21% FO. Pumped 715 BBLs total. SIMOPs; PJSM with SLB, Crew and CPAI rep for cement job. 17:45 19:45 2.00 12,949 12,949 COMPZ CEMEN CMNT P Swap to SLB cement unit; Pump 5 BBLs water and PT surface lines; Good to 4000 psi. Reciprocate throughout cement job. Pump 31 BBIs Mudpush II at 3 BPM with 800 psi. Pump 61.1 BBLs 15.8 ppg cement slurry at 3 BPM with 750 psi, increase rate to 3.5 BPM with 600 psi. FCP=475 psi. Shut down and bleed off, close lower TIW and flush lines with 5 BBL water. Open lower TIW and drop dart, kick out with 10 BBLs water. Isolate SLB and swap to rig pumps. Chase cement with 10.5 drilling mud at 4 BPM ICP=930 psi, FCP= 1030 psi. Reduce rate to 3.5 BPM with FCP= 1200 psi. At 980 strokes away reduce rate to 2 BPM with 1200 psi. Set liner on depth at 12949'and bump plug with 1215 strokes and increase and hold 2300 psi, increase to 2500 while holding, increase to 4000 psi and hold pressure for 15 minutes. Bleed off and check floats; Good. Page 29of35 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T ' Comment 19:45 20:15 0.50 12,949 12,949 COMPZ CEMEN-PACK P Set 50 down weight to insure hanger set; Good. Release hanger and rotate down on dogs to shear. Set 30K down weight and pump 500 psi on packer, pull out of packer and note pressure decrease. 20:15 21:15 1.00 12,949 11,460 COMPZ CEMEN-CIRCP Circulate surface to surface staging pumps to 415 GPM with 3650 psi, 32%FO. Total 473 BBL pumped. Out of packer and seal bore assembly depth set to 11460'with liner set on depth. 21:15 21:45 0.50 11,460 11,460 COMPZ CEMEN-RURD P Blow down and LD cement head. 21:45 22:45 1.00 11,460 11,460 COMPZ CEMEN-PRTS P RU to test ZXP packer, Test to 3000 psi for 10 minutes to chart; Good. RD test equipment. 22:45 00:00 1.25 11,460 11,460 COMPZ WELLPF DISP P RU to reverse circulate for displacement to seawater. pump at 8 BPM with 2090 psi, 36%FO. Crew change. OAP=460 psi. 0 losses for tour and day. 05/29/2015 Complete displacement to 9.6 ppg seawater. Monitor, Circulate and POOH sideways. 00:00 00:30 0.50 11,512 11,512 ICOMPZ',WELLPF DISP P Reverse circ for displacement at 8 BPM with 1680 psi, 30%FO, Swap out to 8.5 ppg seawater. 00:30 01:00 0.50 11,512 11,512 COMPZ WELLPF OWFF P Observe well for flow; Static. SIMOPs; RD and blow down circ equipment, Clean 4"cementing Demcos and blow down cement lines. 01:00 01:30 0.50 11,512 11,327 COMPZ WELLPF PULD P Pull out sideways with 4" DP from 11460'to 11272'. Seawater starting to U-tube up drill pipe. 01:30 02:30 1.00 11,327 11,327 COMPZ WELLPF CIRC T Circulate to balance seawater suspect out of balance. Cement coming back over shakers. 02:30 03:15 0.75 11,327 11,327 COMPZ WELLPF OWFF T Observe seawater u-tubing up DP, suspect cement weighting up backside causing out of balance condition. 03:15 06:00 2.75 11,327 11,327 COMPZ WELLPF CIRC T Circulate to stop U-tubing,trace of cement coming over shakers. 8 BPM with 1295 psi, 25% FO, increasing to 15 BPM with 3580 psi, 33%FO,While reciprocating pipe. 06:00 06:30 0.50 11,327 11,486 COMPZ WELLPF TRIP T RIH from 11,327'to 11,486'to circulate cement suspected at bottom. 06:30 09:00 2.50 11,486 11,486 COMPZ WELLPF CIRC T Circulate BU while reciprocating from 11,483'to 11,393'. Cement returns moderate to heavy at shaker at BU and for 500 Strokes after,then tapering off. Pump 66 BBL high Vis sweep with no increase in returns with sweep out of hole. Page 30 of 35 4110 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 09:00 09:15 0.25 11,486 11,486 COMPZ WELLPF OWFF T Observe well for flow for 10 minutes; Static. 09:15 12:00 2.75 11,486 6,703 COMPZ WELLPF TRIP T Change of Scope to well plan to perform clean-out run with a working string to swap drilling mud in the liner to clean seawater and clean out cement above liner in casing. Decision made to POOH and stand back DP in derrick per town. POOH from 11486'to 6703'on elevators. Proper fill observed. Crew change at 10:00. OAP=400 psi. 12:00 13:30 1.50 6,703 3,103 COMPZ WELLPF TRIP T Continue to POOH with 4" DP from 6703'to 3103'. Proper fill observed. 13:30 15:00 1.50 3,103 3,103 COMPZ WELLPF SLPC P Slip and cut drill line 94'. Slip on same, perform calibrations on the Amphion, Blocks, and Totco equipment. 15:00 15:30 0.50 3,103 3,103 COMPZ WELLPFSVRG P Service rig;topdrive and blocks. Inspect same. 15:30 18:15 2.75 3,103 50 COMPZ WELLPF TRIP T POOH from 3103'to running tool. Proper fill observed. 18:15 19:15 1.00 50 0 COMPZ WELLPF BHAH P Break down running tools; upper spacer rods of the running tool bent and cork-screwed. 100%recovered to surface. 19:15 20:15 1.00 0 0 COMPZ WELLPF BHAH P Clean and clear rig floor of BHA components and equipment. 20:15 21:00 0.75 0 0 COMPZ WELLPF WWWH P MU stack washer and wash out stack and clean BOPE. Function all BOPE and flush again. 21:00 22:00 1.00 0 0 COMPZ WELLPF RURD P PU joint with cement head, break out pups,XOs and single. LD all components. Crew change. 22:00 22:30 0.50 0 0 COMPZ WELLPF RURD P RU to blow down Kill line, blow down line and RD equipment. 22:30 23:00 0.50 0 950 COMPZ WELLPF TRIP T PU and MU mule shoe, trip in the hole out of the derrick to 950'. While waiting for Baker clean out assembly to arrive. 23:00 00:00 1.00 950 0 COMPZ WELLPF PULD P POOH and LD singles to the pipe shed to surface. Proper fill observed on trip. While waiting for Baker clean out assembly to arrive. No losses for day. OAP=300 psi. 05/30/2015 RIH with Clean-out assembly and perform clean-out of casing and seal bore assembly. Pump high Vis sweep and continue to circ clean. 00:00 01:30 1.50 0 0 COMPZ WELLPF RURD T Remove 4" DP out of pipe shed and stage in 2 1/16"working string. 01:30 04:00 2.50 0 0 COMPZ WELLPF RURD T Stage working string XOs and equipment to the rig floor. Process 2 1/16"working string. 04:00 04:15 0.25 0 0 COMPZ WELLPF SFTY T PJSM for PU, Mu of working string for clean out run. Page 31 of 35 Time Logs • Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 04:15 07:15 3.00 0 1,321 COMPZ WELLPF PULD T M/U clean out BHA and RIH to 1,321'. 07:15 07:30 0.25 1,321 1,321 COMPZ WELLPF OWFF T Observed well for flow. 07:30 08:30 1.00 1,321 1,321 COMPZ WELLPF RURD T Change out elevators to 4"and intall PS-21 4" DP inserts. 08:30 11:30 3.00 1,321 3,953 COMPZ WELLPF TRIP T RIH with clean out string from 1,321' to 3,953'. PUW 75K, SOW 75K. 11:30 12:00 0.50 3,953 3,953 COMPZ WELLPF CIRC T Establish circulation and stage pumps to 6 BPM with 2350 psi, 21% FO. Circualte 93 BBL. Crew change. OAP=300 psi. No losses. 12:00 12:45 0.75 3,953 3,953 COMPZ WELLPF CIRC T Continue to circulate at 6 BPM with 2350 psi, 21% FO. PU= 150K, SO= 80K. 12:45 16:45 4.00 3,953 11,260 COMPZ WELLPF TRIP T Trip in hole from 3953'to 11260'with DP on elevators. Observe proper fill via TT. PU= 150K, SO=80K. 16:45 20:15 3.50 11,260 12,878 COMPZ WELLPF WASH T Wash down from 11260'to 12878'at 2 BPM with 425 psi to 11830', increase rate and wash at 3 BPM with 1000 psi to 12874'. PU single and wash to 12878'and observe pressure spike when tagging. Repeat tag to verify; Good. PU= 168K, SO=77K. 20:15 00:00 3.75 12,878 12,878 COMPZ WELLPF CIRC T Circulate 2X BU while reciprocating and staging pumps from 3 BPM to 5 BPM with 2430 psi, Pump 60 BBL high vis sweep to surface with minimal to no increase in returns. SIMOPs; Flush and blow down MPD skid and lies, remove Katch Kan from stack. Continue to break down equipment from annual inspection. Crew change, OAP=340 psi, No losses for day. 35/31/2015 Complete circulation, Pump high Vis sweep, circulate out, pump spacer and displace to clean seawater. POOH sideways with 4"DP to BHA and LD working string and Clean-out assembly. PU and run 3 1/2"9.3# L-80 EUE 8rd tubing per running order detail to 274'. 00:00 03:00 3.00 12,878 12,878 COMPZ WELLPF CIRC T Continue to Circulate while reciprocating while pumping 5 BPM with 2476 psi, 19%FO. PU= 187K, SO=73K. Circulate total of 2014 BBL. 03:00 05:15 2.25 12,878 12,878 COMPZ WELLPF CIRC T Pump 68 BBL high Vis sweep for spacer to swap to clean seawater. 05:15 05:30 0.25 12,878 12,878 COMPZ WELLPF OWFF T Observe well for flow. (No flow) 05:30 12:00 6.50 12,878 7,370 COMPZ WELLPF PULD P POOH sideways with 4"DP from 12,878'to 7,370'. Crew change. OAP=300 psi, No losses. 12:00 17:15 5.25 7,370 1,391 COMPZ WELLPF PULD P Continue to POOH sideways with 4" DP from 12,878'to 7,370'. 17:15 20:00 2.75 1,391 0 COMPZ WELLPF PULD T RU for 2 1/16"working string, pull and LD from 1391'to surface Page 32 of 35 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 21:00 1.00 0 0 COMPZ WELLPF RURD T Clean and clear rig floor of equipment _and working string components. 21:00 21:30 0.50 0 0 COMPZ WELLPF RURD P Pull hydraulic lines and control panel for DDV tool from rigfloor and BOP deck. 21:30 23:00 1.50 0 0 COMPZ RPCOM RURD P RU equipment to run 3 1/2"tubing and handling equipment. Pull wear bushing, LD test joint, verify jewelry and tubing for running detail. 23:00 23:15 0.25 0 0 COMPZ RPCOM SFTY P PJSM for running Upper completion _with crew, Baker and casing reps. 23:15 00:00 0.75 0 274 COMPZ RPCOM PUTB P Run 3 1/2"9.3#L-80 EUE 8rd tubing per detail to 274'. 06/01/2015 Continue to run 3 1/2"9.3#L-80 EUE 8rd tubing to Liner top. Tag, Space-out, RU and pump Corrosion Inhibitor. Land and RILDS. Test tubing and IA; Good tests. Install"H"profile BPV. 00:00 06:00 6.00 274 4,876 COMPZ RPCOM PUTB P Run 3 1/2"9.3#L-80 EUE 8rd tubing per detail from 274'to 4876'. PU= 68K, SO=64K. Monitor fill via trip tank with proper displacement. 06:00 11:30 5.50 4,876 9,883 COMPZ RPCOM PUTB P Run 3 1/2"9.3#L-80 EUE 8rd tubing per detail from 4876'to 9883'. PU= 92K, SO=62K. Monitor fill via trip tank with proper displacement. 11:30 12:00 0.50 9,883 COMPZ RPCOM PUTB T Change out joint#312 with#397 (extra joint not in tally)due to damaged pin. Change out collar on joint#311 with MU torque of 2250 ft-lbs. Crew change. OAP=260 psi. No losses for tour. 12:00 12:30 0.50 9,883 9,883 COMPZ RPCOM PUTB T Continue to Change out joint#312 with#397(extra joint not in tally)due to damaged pin. Change out collar on joint#311 with MU torque of 2250 ft-lbs. 12:30 14:45 2.25 9,883 11,531 COMPZ RPCOM PUTB P Run 3 1/2"9.3#L-80 EUE 8rd tubing per detail from 9883'to 11469'. Monitor fill via trip tank with proper displacement. Pick up joints#362 and#263 to tag for space out. 14:45 15:45 1.00 11,531 11,469 COMPZ RPCOM HOSO P RU headpin, chicksan , plug valve, and cement hose to joint#264, MU and establish circulation with 0.5 BPM with 45 psi, 5%FO. PU= 108K, S0=68K. Wash down to seals and see pressure increase at 11531'entering seal bore assembly. Shut down , bleed off pressure and slack to No-Go at 11556'with 10K over. LD joints#362 to#365. 15:45 18:00 2.25 11,469 11,520 COMPZ RPCOM HOSO P Confirm straps and calculate space-out length. PU and MU 2.26', 2.26', 4.24', and 8.19'pups. MU hanger and 4 1/2"full joint under hanger with 4 1/2"pup. Slack off and tag hanger at 11549'. PU and RU to circulate Cl. Page 33 of 35 Time Logs S Date From To Dur ` S. Depth E. Depth Phase Code ,. Subcode T ' Comment 18:00 20:00 2.00 11,520 11,520 COMPZ RPCOM CRIH P 1With Annular closed reverse circulate in Corrosion Inhibitor, Concor 303A, 407 BBL. Stage pumps to 5 BPM with 760 psi, 22% FO. Total 407 BBLs pumped, 4042 strokes. Bleed off pressure and open annular. Pump 20 BBL water to flush surface lines and stack. 20:00 21:00 1.00 11,520 11,549 COMPZ RPCOM THGR P While pumping down tubing slack off and mark pressure on seal bore entry, bleed off P. Land tubing 20:15, Cameron rep RILDS. SIMOPS; RU surface lines for testing. 21:00 22:45 1.75 11,549 11,549 COMPZ RPCOM PRTS P Test tubing to 3000 psi for 30 minutes to chart; Good. Test IA to 2500 psi for 30 minutes to chart; Good. Bleed to 0 psi. Pressure up on IA to 2600 psi to shear SOV. Check flow both directions; Good. Down Tubing with 2 BPM at 525 psi, Down IA with 2 BPM at 490 psi. Blow down surface equipment. 22:45 23:30 0.75 11,549 0 COMPZ RPCOM RURD P Pull and LD landing joint. Change out elevators and slip inserts, RD _test equipment. 23:30 00:00 0.50 0 0 COMPZ WHDBO MPSP P Install BPV"H"profile per Cameron rep. SIMOPs; PU single and PU stack whacker. 06/02/2015 Continue to test"H"profile BPV; Good. Wash BOP stack, ND BOPE; open all rams, clean and inspect. ND BOPE. NU tree, test to 5000 psi; Good. RU to freeze protect. 00:00 01:30 1.50 0 0 COMPZ WHDBO MPSP P RU and test BPV to 1500 for 15 minutes to chart; Good. 01:30 03:00 1.50 0 0 COMPZ WHDBO WWWH P MU and wash stack with washing tool. 03:00 13:30 10.50 0 0 COMPZ WHDBO NUND P ND and clean BOP's and pits. Open ram doors and clean ram cavities, PS-21 slips and Joe's box. 13:30 16:00 2.50 0 0 COMPZ WHDBO NUND P Finish nipple down and move BOP's to the pedestal position. 16:00 19:30 3.50 0 0 COMPZ WHDBO NUND P Nipple up and test blind adaptor; Good. 19:30 21:30 2.00 0 0 COMPZ WHDBO NUND P Nipple up tree, remove swab valve from tree and turn 180 degrees, aligning with the master valve. (Shane Ferrera,2N DSO,verified tree alignment at 19:15 hrs.) 21:30 22:45 1.25 0 0 COMPZ WHDBO PRTS P Fill and test tree 250/5000 psi for 5 minutes each to chart; Good. 22:45 00:00 1.25 0 0 COMPZ WHDBO FRZP P RU circulating equipment and Little Red Service to Freeze Protect, PJSM, pump 5 BBL diesel down IA taking returns to open top TT. PT surface lines to 2000 psi; Good. Crew change. OAP=260 psi prior to FP. No losses. Page 34 of 35 Time Logs; • Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 36/03/2015 24 hr Summary FP with Isotherm. RDMO. Rig Release 06:00 6/3/2015 00:00 00:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM for freeze protect of well with rig crew, mud engineer, LRS crew and truck driver. Dsicussed FP pump schedule and assignments, hazards and spill prevention. 00:15 01:45 1.50 0 0 COMPZ WHDBO FRZP P Pump 60° Isotherm down IA taking returns to TT, pump 88.5 BBLs at 3 BPM with ICP= 1000 psi, FCP= 1400 psi and chase down IA with 15 BBL diesel. Swap to 18 BBL diesel, at 2.75 BPM with 1000 psi down tubing taking returns to TT until Isotherm seen at the TT. Isotherm seen at 18 BBL of diesel away, pumping down the tubing, stop. Blow down all lines. SIMOPs; Prep to scope derrick, prep parts houses for move and truck shop to move to 1Y pad. Final well pressures; Tubing=0 psi, IA=0 psi, 0A=280 psi. 01:45 03:00 1.25 0 0 COMPZ WHDBO MPSP P Install BPV"H"profile per Cameron rep. Secure wellhead, Remove 1502 flanges and install gauges. 03:00 06:00 3.00 0 0 DEMOB MOVE RURD P Continue to prep to scope derrick and prep for move. Scope derrick Rig released for move f/2N-312 to 1Y pad for"Summer Maintenance" @ 0600 hrs 6/3/2015. The move is 22.2 miles to 1Y pad. Page 35 of 35 • • FINAL REVISED 12:53 pm,Jul 21, 2015 NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-312 Definitive Survey Report 15 July, 2015 NAD 27 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska, United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 0.00 usft Northing: 5,911,977.02 usft Latitude: 70° 10'13.664 N +E/-W 0.00 usft Easting: 460,961.62 usft Longitude: 150° 18'51.070 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-312 Magnetics Model Name Sample Date Declination a = a -A AvAAAAAA IMO',/gINXIMPONISMIMIllaidralW 11".14011 BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.79 0.00 0.00 39.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:3 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8:3' 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1:5 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:1 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 0.00 0.00 5,911,977.02 460,961.62 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 0.12 -0.15 5,911,977.14 460,961.47 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 0.72 -0.80 5,911,977.75 460,960.82 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 1.00 -1.06 5,911,978.02 460,960.56 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 -0.65 -0.10 5,911,976.37 460,961.51 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 -5.01 2.60 5,911,972.00 460,964.19 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 -10.69 6.75 5,911,966.30 460,968.31 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 -17.53 12.68 5,911,959.42 460,974.20 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 -26.43 20.95 5,911,950.48 460,982.43 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 -37.46 31.70 5,911,939.40 460,993.12 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 -50.15 44.41 5,911,926.65 461,005.77 2.25 -11.02 GYD-GC-SS(1) 7/15/2015 11:01:28AM Page 2 COMPASS 5000.1 Build 74 • Schlumberger III Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey :''s 7A...:= .47.v.t.,._a,r,sW , 4....--,01 ----, • '4 M ' jr4* 1.' ''' w '''' , .., . ;100,54,811''.):54 1 . Map Map Vertical � k.. A. :.n° MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 978.85 13.11 133.85 972.74 815.25 -59.24 53.68 5,911,917.51 461,014.99 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 -75.40 71.28 5,911,901.26 461,032.50 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 -93.70 92.15 5,911,882.86 461,053.28 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 -110.98 116.54 5,911,865.45 461,077.58 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 1,356.78 19.98 113.66 1,333.15 1,175.66 -125.15 144.62 5,911,851.14 461,105.58 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 -136.42 174.84 5,911,839.71 461,135.74 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 -144.32 207.78 5,911,831.64 461,168.63 3.63 18.60 MWD+IFR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 -147.69 244.17 5,911,828.09 461,205.00 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 -148.08 285.57 5,911,827.48 461,246.39 2.68 64.63 MWD+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 -146.18 329.00 5,911,829.16 461,289.83 4.52 93.45 MWD+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 -138.94 377.77 5,911,836.15 461,338.63 4.48 129.76 MWD+IFR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 -126.53 428.68 5,911,848.30 461,389.60 3.36 171.45 MWD+IFR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 -111.63 481.98 5,911,862.92 461,442.97 1.59 216.57 MWD+IFR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 -96.56 536.31 5,911,877.70 461,497.38 3.08 262.47 MWD+IFR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 -78.90 596.09 5,911,895.05 461,557.24 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 -57.55 659.86 5,911,916.07 461,621.11 4.39 370.53 MWD+IFR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 -31.84 727.06 5,911,941.44 461,688.43 4.15 432.81 MWD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 -3.11 796.52 5,911,969.80 461,758.04 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 21.42 854.18 5,911,994.03 461,815.81 3.75 554.20 MWD+IFR-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 46.58 909.36 5,912,018.91 461,871.12 3.14 608.48 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,758.81 59.33 63.63 2,428.38 2,270.89 55.91 928.50 5,912,028.14 461,890.31 3.14 627.78 MWD+IFR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 94.01 1,000.29 5,912,065.86 461,962.28 2.93 702.56 MWD+IFR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 137.44 1,071.07 5,912,108.92 462,033.28 3.88 780.86 MWD+IFR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 184.93 1,139.95 5,912,156.05 462,102.40 3.52 861.11 MWD+IFR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 235.85 1,207.85 5,912,206.61 462,170.55 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 290.43 1,274.53 5,912,260.84 462,237.50 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 349.42 1,339.01 5,912,319.49 462,302.28 3.71 1,114.21 MWD+IFR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 411.57 1,399.00 5,912,381.33 462,362.59 3.34 1,200.27 MWD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 477.49 1,457.12 5,912,446.94 462,421.04 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 545.92 1,512.50 5,912,515.08 462,476.76 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 617.91 1,567.23 5,912,586.78 462,531.86 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 690.08 1,619.48 5,912,658.67 462,584.48 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 766.24 1,670.24 5,912,734.56 462,635.63 2.32 1,646.60 MWD+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 842.12 1,719.97 5,912,810.17 462,685.74 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 915.54 1,770.70 5,912,883.32 462,736.84 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 989.36 1,822.61 5,912,956.87 462,789.13 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 1,063.01 1,875.23 5,913,030.23 462,842.12 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 1,136.98 1,928.56 5,913,103.93 462,895.83 0.78 2,097.28 MWD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 1,210.77 1,979.89 5,913,177.44 462,947.54 1.17 2,186.93 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 11:01:28AM Page 3 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey -4444t4tre-4-rgo Map Map Vertical MD Inc Azi TVD TVDSS +NI-S •I +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,555.72 72.90 33.56 3,073.19 2,915.70 1,284.84 2,029.68 5,913,251.25 462,997.70 0.71 2,275.83 MWD+IFR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 1,361.41 2,080.15 5,913,327.55 463,048.56 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 1,437.72 2,129.56 5,913,403.59 463,098.36 0.77 2,457.49 MWD+IFR-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 1,513.20 2,177.78 5,913,478.82 463,146.96 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 1,589.12 2,225.65 5,913,554.49 463,195.22 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 1,665.47 2,273.52 5,913,630.58 463,243.47 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 1,740.29 2,322.20 5,913,705.14 463,292.53 1.66 2,813.86 MWD+IFR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 1,815.06 2,372.59 5,913,779.64 463,343.31 0.23 2,903.68 MWD+IFR-AK-CAZSC(3) 5,314.27 71.88 34.89 3,306.85 3,149.36 1,889.38 2,423.65 5,913,853.68 463,394.74 0.80 2,993.57 MWD+IFR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 1,963.49 2,474.11 5,913,927.53 463,445.58 1.29 3,082.92 MWD+IFR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 2,038.97 2,523.11 5,914,002.75 463,494.97 1.25 3,172.42 MWD+I FR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 2,114.45 2,571.52 5,914,077.97 463,543.76 0.68 3,261.55 MWD+1FR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 2,190.20 2,621.54 5,914,153.45 463,594.17 0.92 3,351.90 MW D+I FR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 2,264.62 2,672.44 5,914,227.60 463,645.45 0.95 3,441.76 MW D+I FR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 2,338.85 2,723.75 5,914,301.56 463,697.13 0.38 3,531.74 MW D+I FR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 2,413.05 2,774.83 5,914,375.48 463,748.58 0.17 3,621.54 MW D+I FR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 2,487.11 2,825.61 5,914,449.27 463,799.75 0.38 3,711.06 MW D+I FR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 2,560.97 2,876.08 5,914,522.87 463,850.58 0.22 3,800.22 MW D+I FR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 2,635.95 2,926.91 5,914,597.58 463,901.80 0.59 3,890.48 MWD+IFR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 2,711.25 2,976.69 5,914,672.61 463,951.96 0.75 3,980.33 MW D+I FR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 2,786.48 3,025.74 5,914,747.58 464,001.39 0.03 4,069.66 MWD+IFR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 2,861.37 3,074.46 5,914,822.21 464,050.50 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 2,937.26 3,123.57 5,914,897.84 464,099.99 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 3,013.60 3,172.61 5,914,973.92 464,149.42 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 3,089.22 3,220.82 5,915,049.28 464,198.02 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 3,165.17 3,268.83 5,915,124.98 464,246.41 0.35 4,516.94 MWD+IFR-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 3,241.70 3,317.54 5,915,201.25 464,295.51 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 3,316.22 3,366.89 5,915,275.50 464,345.24 1.52 4,696.04 MWD+IFR-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 3,390.64 3,418.72 5,915,349.65 464,397.45 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 3,463.43 3,471.84 5,915,422.16 464,450.94 1.28 4,876.49 MWD+IFR-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 3,535.74 3,525.91 5,915,494.18 464,505.38 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 3,608.77 3,579.80 5,915,566.93 464,559.63 0.83 5,057.38 MWD+IFR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 3,681.62 3,632.08 5,915,639.50 464,612.28 0.74 5,146.90 MWD+IFR-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 3,755.78 3,684.23 5,915,713.37 464,664.81 0.40 5,237.35 MWD+IFR-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 3,829.75 3,735.42 5,915,787.08 464,716.37 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 3,904.22 3,786.13 5,915,861.27 464,767.46 0.37 5,416.84 MWD+IFR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 3,979.21 3,836.33 5,915,935.99 464,818.05 0.54 5,506.70 MWD+IFR-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 4,054.38 3,885.30 5,916,010.91 464,867.40 1.14 5,595.95 MWD+IFR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 4,130.20 3,933.12 5,916,086.47 464,915.60 0.79 5,684.96 MWD+IFR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 4,207.07 3,980.43 5,916,163.09 464,963.30 0.48 5,774.47 MWD+IFR-AK-CAZ-SC(3) 7/15/2015 11:01:28AM Page 4 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 .. . Survey Vel.„4 Alt Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 8,343.16 71.71 31.21 4,234.52 4,077.03 4,284.49 4,027.48 5,916,240.25 465,010.75 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 4,360.68 4,073.98 5,916,316.20 465,057.64 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 4,436.97 4,121.53 5,916,392.23 465,105.57 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 4,512.70 4,170.17 5,916,467.71 465,154.60 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 4,587.64 4,220.16 5,916,542.38 465,204.98 1.17 6,221.10 MWD+IFR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 4,661.58 4,270.95 5,916,616.05 465,256.14 0.40 6,310.53 MWD+IFR-AK-CAZ-SC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 4,735.26 4,322.57 5,916,689.46 465,308.13 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 4,808.80 4,374.38 5,916,762.72 465,360.32 0.36 6,490.02 MWD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 4,882.29 4,425.55 5,916,835.94 465,411.86 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 4,957.10 4,476.81 5,916,910.48 465,463.50 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 5,031.89 4,527.09 5,916,985.00 465,514.16 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 5,107.21 4,575.36 5,917,060.06 465,562.82 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 9,477.42 72.26 30.26 4,583.36 4,425.87 5,184.90 4,621.94 5,917,137.50 465,609.79 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 5,262.61 4,666.99 5,917,214.97 465,655.23 0.33 7,026.85 MWD+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 5,341.59 4,712.10 5,917,293.71 465,700.74 0.42 7,116.61 MWD+IFR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 5,419.95 4,757.32 5,917,371.82 465,746.37 0.95 7,205.97 MWD+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 5,496.18 4,803.63 5,917,447.81 465,793.06 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 5,572.65 4,853.67 5,917,524.01 465,843.49 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 5,646.19 4,903.41 5,917,597.29 465,893.61 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 5,721.59 4,954.96 5,917,672.41 465,945.54 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 5,794.30 5,007.70 5,917,744.85 465,998.65 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 5,866.33 5,062.35 5,917,816.58 466,053.66 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 5,937.30 5,117.19 5,917,887.27 466,108.87 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 6,008.89 5,173.20 5,917,958.56 466,165.23 0.15 7,925.39 MWD+IFR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 6,079.74 5,227.30 5,918,029.12 466,219.70 1.39 8,014.50 MWD+IFR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 6,153.53 5,279.56 5,918,102.63 466,272.33 2.78 8,104.72 MWD+IFR-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 6,203.38 5,311.07 5,918,152.32 466,304.10 4.98 8,163.30 MWD+IFR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 6,228.35 5,325.85 5,918,177.20 466,319.00 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 6,307.78 5,372.66 5,918,256.39 466,366.21 0.19 8,283.19 MWD+IFR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 6,385.17 5,418.08 5,918,333.53 466,412.03 0.15 8,371.92 MWD+IFR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 6,462.61 5,465.36 5,918,410.72 466,459.71 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 6,538.05 5,514.23 5,918,485.90 466,508.96 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 6,613.12 5,564.01 5,918,560.70 466,559.12 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 6,687.56 5,613.97 5,918,634.88 466,609.46 0.47 8,730.20 MWD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 6,762.68 5,664.91 5,918,709.72 466,660.78 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 6,837.98 5,715.59 5,918,784.75 466,711.84 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 6,883.04 5,745.21 5,918,829.66 466,741.69 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,677.00 73.37 33.29 5,253.64 5.096.15 6,930 66 5,776.27 5,918,877.11 466,773.00 1.86 9,021.26 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 11,714.45 74.03 33.50 5,264.15 5,106.66 6,960.67 5,796.06 5,918,907.01 466,792.93 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 7,036.14 5,846.17 5,918,982.22 466,843.43 1.86 9,147.22 MWD+IFR-AK-CAZ-SC(4) 7/15/2015 11:01:28AM Page 5 COMPASS 5000.1 Build 74 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) "North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 ' Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 11,905.96 72.27 31.26 5,321.07 5,163.58 7,113.97 5,895.69 5,919,059.78 466,893.34 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 7,191.48 5,943.81 5,919,137.04 466,941.86 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 7,267.66 5,992.12 5,919,212.96 466,990.55 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 7,302.73 6,014.35 5,919,247.92 467,012.96 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 7,378.24 6,062.96 5,919,323.16 467,061.96 0.81 9,549.52 MWD+IFR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 7,454.63 6,112.47 5,919,399.29 467,111.86 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 7,531.33 6,158.95 5,919,475.74 467,158.73 4.59 9,728.89 MWD+IFR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 7,605.55 6,205.15 5,919,549.72 467,205.31 4.75 9,815.65 MWD+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 7,677.67 6,253.74 5,919,621.58 467,254.26 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 7,748.57 6,301.56 5,919,692.23 467,302.45 1.65 9,987.48 MWD+IFR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 7,817.27 6,349.43 5,919,760.67 467,350.67 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 7,883.90 6,397.70 5,919,827.04 467,399.28 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57.76 35.26 5,696.83 5,539.34 7,895.13 6,405.81 5,919,838.23 467,407.44 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 7,919.16 6,422.80 5,919,862.17 467,424.55 0.00 10,196.35 PROJECTED to TD 3 1/2"x 6-1/2" 7/15/2015 11:01:28AM Page 6 COMPASS 5000.1 Build 74 • NADConversion Kuparuk River Unit Kuparuk 2N Pad 2N-312 Definitive Surve port 01 June, 2015 • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 164,036.12 usft Northing: 5,911,977.02 usfl Latitude: 70°10'13.664 N +EI-W 1,126,701.37 usft Easting: 460,961.62 usfl Longitude: 150°18'51.070 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 117.70usft Wellbore 2N-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (0) 39.79 164,036.1: -1,126,701 39.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:3 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8.3' 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1.5' 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:1' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 164,036.12-1,126,701.37 5,911,977.02 460,961.62 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 164,036.24-1,126,701.52 5,911,977.12 460,961.45 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 164,036.84-1,126,702.17 5,911,977.62 460,960.72 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 164,037.12-1,126,702.43 5,911,977.86 460,960.42 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 164,035.48-1,126,701.47 5,911,976.37 460,961.61 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 164,031.11-1,126,698.77 5,911,972.43 460,964.91 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 164,025.43-1,126,694.62 5,911,967.40 460,969.85 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 164,018.59-1,126,688.69 5,911,961.47 460,976.70 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 164,009.69-1,126,680.41 5,911,953.84 460,986.19 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 163,998.67-1,126,669.67 5,911,944.47 460,998.42 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 163,985.97-1,126,656.95 5,911,933.73 461,012.85 2.25 -11.02 GYD-GC-SS(1) 978.85 13.11 133.85 972.74 815.25 163,976.88-1,126,647.68 5,911,926.05 461,023.34 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 163,960.72-1,126,630.09 5,911,912.58 461,043.11 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 163,942.42-1,126,609.21 5,911,897.45 461,066.43 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 163,925.14-1,126,584.82 5,911,883.84 461,093.08 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 6/1/2015 3:12:37PM Page 2 COMPASS 5000.1 Build 65 • Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 1,356.78 19.98 113.66 1,333.15 1,175.66 163,910.97-1,126,556.74 5,911,873.84 461,122.95 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 163,899.70-1,126,526.52 5,911,867.03 461,154.51 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 163,891.80-1,126,493.59 5,911,863.95 461,188.29 3.63 18.60 MWD+I FR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 163,888.43-1,126,457.20 5,911,865.85 461,224.83 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 163,888.04-1,126,415.80 5,911,871.42 461,265.91 2.68 64.63 MWD+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 163,889.94-1,126,372.36 5,911,879.56 461,308.67 4.52 93.45 MWD+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 163,897.18-1,126,323.59 5,911,893.76 461,355.95 4.48 129.76 MWD+I FR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 163,909.59-1,126,272.69 5,911,913.39 461,404.61 3.36 171.45 MWD+I FR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 163,924.50-1,126,219.38 5,911,935.84 461,455.28 1.59 216.57 MWD+I FR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 163,939.56-1,126,165.05 5,911,958.59 461,506.94 3.08 262.47 MWD+I FR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 163,957.22-1,126,105.27 5,911,984.70 461,563.63 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 163,978.57-1,126,041.51 5,912,015.04 461,623.74 4.39 370.53 MWD+IFR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 164,004.28-1,125,974.31 5,912,050.20 461,686.62 4.15 432.81 MWD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 164,033.01-1,125,904.84 5,912,088.67 461,751.32 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 164,057.54-1,125,847.19 5,912,121.27 461,804.91 3.75 554.20 MWD+IFR-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 164,082.70-1,125,792.00 5,912,154.16 461,855.97 3.14 608.48 MWD+IFR-AK CAZ-SC(3) 10 3/4"x 13-1/2 2,758.81 59.33 63.63 2,428.38 2,270.89 164,092.03-1,125,772.86 5,912,166.16 461,873.59 3.14 627.78 MWD+IFR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 164,130.14-1,125,701.08 5,912,214.25 461,939.23 2.93 702.56 MWD+I FR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 164,173.56-1,125,630.29 5,912,267.48 462,003.11 3.88 780.86 MWD+IFR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 164,221.05-1,125,561.41 5,912,324.45 462,064.52 3.52 861.11 MWD+IFR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 164,271.97-1,125,493.52 5,912,384.69 462,124.46 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 164,326.55-1,125,426.84 5,912,448.37 462,182.67 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 164,385.54-1,125,362.36 5,912,516.11 462,238.06 3.71 1,114.21 MWD+I FR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 164,447.69-1,125,302.37 5,912,586.34 462,288.56 3.34 1,200.27 MWD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 164,513.61-1,125,244.24 5,912,660.02 462,336.65 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 164,582.04-1,125,188.87 5,912,735.81 462,381.66 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 164,654.03-1,125,134.14 5,912,815.02 462,425.52 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 164,726.20-1,125,081.89 5,912,894.06 462,466.90 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 164,802.36-1,125,031.12 5,912,976.83 462,506.23 2.32 1,646.60 MWD+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 164,878.24-1,124,981.39 5,913,059.18 462,544.58 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 164,951.66-1,124,930.67 5,913,139.24 462,584.27 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 165,025.48-1,124,878.76 5,913,219.86 462,625.07 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 165,099.13-1,124,826.14 5,913,300.41 462,666.60 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 165,173.10-1,124,772.80 5,913,381.40 462,708.79 0.78 2,097.28 MWD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 165,246.89-1,124,721.47 5,913,461.91 462,749.03 1.17 2,186.93 MWD+IFR-AK-CAZ-SC(3) 4,555.72 72.90 33.56 3,073.19 2,915.70 165,320.96-1,124,671.69 5,913,542.47 462,787.69 0.71 2,275.83 MWD+IFR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 165,397.53-1,124,621.21 5,913,625.61 462,826.67 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 165,473.84-1,124,571.81 5,913,708.34 462,864.64 0.77 2,457.49 MWD+IFR-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 165,549.33-1,124,523.59 5,913,790.08 462,901.54 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 165,625.25-1,124,475.71 5,913,872.20 462,938.04 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 165,701.60-1,124,427.85 5,913,954.75 462,974.48 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 165,776.41-1,124,379.17 5,914,035.89 463,011.93 1.66 2,813.86 MWD+IFR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 165,851.18-1,124,328.78 5,914,117.23 463,051.10 0.23 2,903.68 MWD+IFR-AK-CAZ-SC(3) 6/1/2015 3:12:37PM Page 3 COMPASS 5000.1 Build 65 Schlumberger • Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 I Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,314.27 71.88 34.89 3,306.85 3,149.36 165,925.50-1,124,277.72 5,914,198.23 463,090.98 0.80 2,993.57 MWD+IFR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 165,999.61-1,124,227.26 5,914,278.93 463,130.31 1.29 3,082.92 MWD+I FR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 166,075.09-1,124,178.25 5,914,360.78 463,167.99 1.25 3,172.42 MWD+IFR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 166,150.57-1,124,129.84 5,914,442.55 463,205.09 0.68 3,261.55 MWD+IFR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 166,226.32-1,124,079.82 5,914,524.81 463,243.74 0.92 3,351.90 MWD+IFR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 166,300.74-1,124,028.92 5,914,605.88 463,283.46 0.95 3,441.76 MWD+IFR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 166,374.97-1,123,977.62 5,914,686.82 463,323.60 0.38 3,531.74 MWD+IFR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 166,449.17-1,123,926.54 5,914,767.69 463,363.53 0.17 3,621.54 MWD+IFR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 166,523.23-1,123,875.75 5,914,848.39 463,403.18 0.38 3,711.06 MWD+IFR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 166,597.09-1,123,825.29 5,914,928.85 463,442.54 0.22 3,800.22 MWD+IFR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 166,672.07-1,123,774.46 5,915,010.47 463,482.11 0.59 3,890.48 MWD+IFR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 166,747.37-1,123,724.68 5,915,092.25 463,520.59 0.75 3,980.33 MWD+IFR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 166,822.60-1,123,675.63 5,915,173.85 463,558.36 0.03 4,069.66 MWD+IFR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 166,897.49-1,123,626.91 5,915,255.08 463,595.85 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 166,973.38-1,123,577.79 5,915,337.35 463,633.58 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 167,049.72-1,123,528.75 5,915,420.06 463,671.18 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 167,125.34-1,123,480.54 5,915,501.93 463,708.05 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 167,201.29-1,123,432.53 5,915,584.10 463,744.68 0.35 4,516.94 MWD+IFR-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 167,277.82-1,123,383.83 5,915,666.95 463,781.92 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 167,352.34-1,123,334.48 5,915,747.89 463,820.09 1.52 4,696.04 MWD+IF R-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 167,426.77-1,123,282.64 5,915,829.11 463,860.73 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 167,499.55-1,123,229.53 5,915,908.88 463,902.88 1.28 4,876.49 MWD+IFR-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 167,571.86-1,123,175.45 5,915,988.31 463,946.04 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 167,644.89-1,123,121.57 5,916,068.44 463,988.91 0.83 5,057.38 MWD+IFR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 167,717.74-1,123,069.29 5,916,148.16 464,030.22 0.74 5,146.90 MWD+I FR-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 167,791.90-1,123,017.13 5,916,229.15 464,071.22 0.40 5,237.35 MWD+IFR-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 167,865.87-1,122,965.95 5,916,309.82 464,111.28 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 167,940.34-1,122,915.24 5,916,390.91 464,150.81 0.37 5,416.84 MWD+IFR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 168,015.33-1,122,865.04 5,916,472.44 464,189.75 0.54 5,506.70 MWD+IFR-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 168,090.50-1,122,816.06 5,916,553.98 464,227.44 1.14 5,595.95 MWD+IFR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 168,166.32-1,122,768.25 5,916,635.99 464,263.90 0.79 5,684.96 MWD+IFR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 168,243.19-1,122,720.94 5,916,718.97 464,299.71 0.48 5,774.47 MWD+IFR-AK-CAZ-SC(3) 8,343.16 71.71 31.21 4,234.52 4,077.03 168,320.61-1,122,673.89 5,916,802.46 464,335.18 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 168,396.81-1,122,627.38 5,916,884.66 464,370.28 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 168,473.09-1,122,579.84 5,916,967.10 464,406.40 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 168,548.83-1,122,531.20 5,917,049.15 464,443.69 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 168,623.76-1,122,481.20 5,917,130.60 464,482.44 1.17 6,221.10 MWD+IFR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 168,697.70-1,122,430.41 5,917,211.18 464,522.11 0.40 6,310.53 MWD+IFR-AK-CAZ-SC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 168,771.39-1,122,378.80 5,917,291.63 464,562.64 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 168,844.92-1,122,326.98 5,917,371.95 464,603.39 0.36 6,490.02 MWD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 168,918.41-1,122,275.82 5,917,452.14 464,643.50 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 168,993.22-1,122,224.56 5,917,533.65 464,683.52 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 169,068.01-1,122,174.27 5,917,615.00 464,722.57 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 169,143.33-1,122,126.00 5,917,696.59 464,759.55 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 6/1/2015 3:12:37PM Page 4 COMPASS 5000.1 Build 65 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (0) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,477.42 72.26 30.26 4,583.36 4,425.87 169,221.02-1,122,079.42 5,917,780.27 464,794.52 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 169,298.73-1,122,034.38 5,917,863.76 464,827.96 0.33 7,026.85 MWD+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 169,377.71-1,121,989.27 5,917,948.52 464,861.28 0.42 7,116.61 MWD+I FR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 169,456.07-1,121,944.04 5,918,032.67 464,894.81 0.95 7,205.97 MWD+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 169,532.30-1,121,897.74 5,918,114.88 464,929.71 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 169,608.77-1,121,847.69 5,918,197.86 464,968.28 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 169,682.31-1,121,797.95 5,918,277.89 465,006.97 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 169,757.71-1,121,746.40 5,918,360.02 465,047.19 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 169,830.43-1,121,693.67 5,918,439.67 465,088.97 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 169,902.45-1,121,639.02 5,918,518.91 465,132.75 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 169,973.42-1,121,584.17 5,918,597.14 465,176.87 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 170,045.02-1,121,528.17 5,918,676.14 465,222.05 0.15 7,925.39 MWD+I FR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 170,115.86-1,121,474.06 5,918,754.14 465,265.46 1.39 8,014.50 MWD+IFR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 170,189.65-1,121,421.81 5,918,834.77 465,306.61 2.78 8,104.72 MWD+I F R-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 170,239,51-1,121,390.29 5,918,888.71 465,330.65 4.98 8,163.30 MWD+IFR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 170,264.47-1,121,375.52 5,918,915.58 465,341.69 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 170,343.90-1,121,328.71 5,919,001.03 465,376.63 0.19 8,283.19 MWD+IFR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 170,421.29-1,121,283.28 5,919,084.25 465,410.50 0.15 8,371.92 MWD+IFR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 170,498.74-1,121,236.00 5,919,167.80 465,446.20 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 170,574.17-1,121,187.13 5,919,249.59 465,483.75 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 170,649.24-1,121,137.35 5,919,331.14 465,522.26 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 170,723.68-1,121,087.39 5,919,412.10 465,561.04 0.47 8,730.20 MWD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 170,798.80-1,121,036.46 5,919,493.86 465,600.69 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 170,874.10-1,120,985.77 5,919,575.78 465,640.07 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 170,919.17-1,120,956.15 5,919,624.70 465,662.93 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,670.00 73.24 33.25 5,251.63 5,094.14 170,961.17-1,120,928.77 5,919,670.26 465,684.01 1.86 9,014.59 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-718" 11,714.45 74.03 33.50 5,264.15 5,106.66 170,996.79-1,120,905.31 5,919,708.93 465,702.13 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 171,072.26-1,120,855.19 5,919,790.93 465,740.91 1.86 9,147.22 MWD+I FR-AK-CAZ-SC(4) 11,905.96 72.27 31.26 5,321.07 5,163.58 171,150.09-1,120,805.68 5,919,875.18 465,778.77 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 171,227.60-1,120,757.55 5,919,958.92 465,815.29 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 171,303.78-1,120,709.25 5,920,041.36 465,852.18 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 171,338.85-1,120,687.02 5,920,079.32 465,869.15 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 171,414.36-1,120,638.40 5,920,161.14 465,906.45 0.81 9,549.52 MWD+IFR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 171,490.75-1,120,588.89 5,920,243.96 465,944.51 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 171,567.45-1,120,542.42 5,920,326.65 465,979.51 4.59 9,728.89 MWD+I FR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 171,641.67-1,120,496.21 5,920,406.85 466,014.60 4.75 9,815.65 MWD+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 171,713.80-1,120,447.63 5,920,485.31 466,052.35 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 171,784.70-1,120,399.80 5,920,562.45 466,089.53 1.65 9,987.48 MWD+IFR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 171,853.39-1,120,351.93 5,920,637.42 466,127.07 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 171,920.02-1,120,303.66 5,920,710.39 466,165.30 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57.76 35.26 5,696.83 5,539.34 171,931.25-1,120,295.56 5,920,722.68 466,171.71 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 171,955.29-1,120,278.57 5,920,748.95 466,185.09 0.00 10,196.35 PROJECTED to TD 3 1/2"x 6-112" 6/1/2015 3:12:37PM Page 5 COMPASS 5000.1 Build 65 • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. Yes No I have checked to the best of my ability that the following data is correct: 0 Surface Coordinates 0 Declination & Convergence Cl GRS Survey Corrections El Survey Tool Codes Clgitallysipeci by Vincent Osara cr.V"ncent Osam. Vincent OSa ra e=5cl'IL"erger`CrULNumbege-' S LB DE: ernall--vasar3gilb.com.cri.15 Cele 2015.0601 1511/33-OM Mpiahm,d*kmlunmA Client Representative: Scott Brunswick Date: O1-Jun-2015 • Cement Detail Report 2N-312 gym, CcwK3coPh 1trps . String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/5/2015 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 5/12/2015 05:45 5/12/2015 09:18 2N-312 Comment PJSM for cement job with SLB cementers,Truck drivers, rig crew and CPAI rep. Sim ops: Con't to circ @ 8 bpm&recip 20'f/2734'to 2714'.Con't to circ while Dowell prepares to take on water for cement job. Circ total of 824 bbls @ 8 bpm. Dowell pump 5 bbls water,then test to 3500 psi-good. Batch up MudPushll @ 10.5 ppg w/2-1/2 gallons of red dye. Pump 94.1 bbls of 10.5 ppg MudPush II w/2-1/2 gallons of red dye,avg 5.5 bbl/min. Recip casing 20'. PU wt 160k, SO wt 116k. Load bottom plug, install with the Volant casing tool. Dowell mix ALC cement(Yield 1.93 cufUsx, mix H2O 6.496 gal/sx,Thickening time 4.35 hrs) to 11 ppg,then pump @ avg of 6.6 bpm w/240-260 psi. Pumped a total of 304 bbls(884 sx)when MudPush w/red dye was seen at the shakers. Finished pumping down tanks for a total of 325.5 bbls(947 sx)of ACL cement. Recip casing 20'7PU Wt 1'68k, SO wt 113k. Batch up LiteCrete tail cement to 12 ppg(Yield 1.62 cufUsx, mix water 5.463 gal/sx,Thickening time 4.55 hrs). Dowell pump LiteCrete tail cement @ average of 5 bpm w/206-300 psi. Pumped a total of 63.1 bbls 1 (219 sx). Recip casing 20'. Broke over @ 190k,then PU wt 160k,SO wt 105-95k. Load top plug, install with the Volant casing tool. Dowell pump 10 bbls of water to clear lines©6 bpm w/218 psi. Attempt to recip pipe and did not break free @ 288k PU wt. Landed casing on hanger.opened(2)4"valves on conductor to take returns to the cellar. Rig displaced cement w/9.8 ppg Drilplex mud. Initially displacing @ 8 bpm w/500 psi taking returns to the cellar, had to slow down to keep up sucking returns. Slowed to 6 bpm w/250 psi after pumping 60 bbls.Was able to increase rate to 7 bpm after pumping 100 bbls of mud and continued at that rate until slowing down to 3 bpm w/340 psi after pumping 240 bbls and bumped the plug with 245.1 bbl pumped(95%pump efficiency,2420 strokes):94.7 bbls good cement to surface.Floats did not hold.Held 600 psi f/6.5 hrs,checked floats-held. _..._.._.._.. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Surface Casing Cement 40.0 2,743.0 Yes 94.7 Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 3 7 340.0 923.0 Yes 20.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) 2,644.0 Drill Bit 2,743.0 9 7/8 Comment PJSM for cement job with SLB cementers,Truck drivers, rig crew and CPAI rep. Sim ops: Con't to circ @ 8 bpm&recip 20'f/2734'to 2714'.Con't to circ while Dowell prepares to take on water for cement job. Circ total of 824 bbls @ 8 bpm. Dowell pump 5 bbls water,then test to 3500 psi-good. Batch up MudPushll @ 10.5 ppg w/2-1/2 gallons of red dye. Pump 94.1 bbls of 10.5 ppg MudPush II w/2-1/2 gallons of red dye,avg 5.5 bbl/min. Recip casing 20'. PU wt 160k, SO wt 116k. Load bottom plug, install with the Volant casing tool. Dowell mix ALC cement(Yield 1.93 cufUsx, mix H2O 6.496 gal/sx, Thickening time 4.35 hrs) to 11 ppg,then pump @ avg of 6.6 bpm w/240-260 psi. Pumped a total of 304 bbls(884 sx)when MudPush w/red dye was seen at the shakers. Finished pumping down tanks for a total of 325.5 bbls(947 sx)of ACL cement. Recip casing 20'. PU wt 168k, SO wt 113k. Batch up LiteCrete tail cement to 12 ppg(Yield 1.62 cufUsx, mix water 5.463 gal/sx,Thickening time 4.55 hrs). Dowell pump LiteCrete tail cement @ average of 5 bpm w/206-300 psi. Pumped a total of 63.1 bbls (219 sx). Recip casing 20'. Broke over© 190k,then PU wt 160k,SO wt 105-95k. Load top plug, install with the Volant casing tool. Dowell pump 10 bbls of water to clear lines @ 6 bpm w/218 psi. Attempt to recip pipe and did not break free @ 288k PU wt. Landed casing on hanger.opened(2)4"valves on conductor to take returns to the cellar. Rig displaced cement w/9.8 ppg Drilplex mud. Initially displacing @ 8 bpm w/500 psi taking returns to the cellar, had to slow down to keep up sucking returns. Slowed to 6 bpm w/250 psi after pumping 60 bbls.Was able to increase rate to 7 bpm after pumping 100 bbls of mud and continued at that rate until slowing down to 3 bpm w/340 psi after pumping 240 bbls and bumped the plug with 245.1 bbl pumped(95%pump efficiency, 2420 strokes).94.7 bbls good cement to surface. Floats did not hold.Held 600 psi f/6.5 hrs,checked floats-held. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 94.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 10.50 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Lead Cement 42.4 2,187.0 947 ALC 325.5 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.93 6.50 11.00 4.35 Additives Additive Type Concentration Conc Unit label D0145 Dispersant 0.05 gal/sx Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Tail Cement 2,187.0 2,733.8 219 LiteCrete 63.1 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 1.62 5.46 12.00 4.55 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 %BWOB Page 1/2 Report Printed: 6/24/2015 Cement Detail Report 2N-312 'hilusk. String: Surface Casing Cement Job: DRILLING ORIGINAL, 5/5/2015 18:00 Additives Additive Type Concentration Conc Unit label D185 Dispersant 0.06 gal/sx Additive Type Concentration Conc Unit label D177 Retarder 0.025 gal/sx Page 2/2 Report Printed: 6/24/2015 IIICement Detail Report 2N-312 cci�thitlaps String: Intermediate Casing Cement Job: DRILLING ORIGINAL, 5/5/2015 18:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Intermediate Casing Cement 5/22/2015 05:30 5/22/2015 09:30 2N-312 Comment Cement 7-5/8"casing per program, pump 5 bbl water from truck.Test cement line to 4000 psi. Bleed off pressure and pump 51 bbl Mud Push II 11.5 ppg @ 5 bpm 405 psi 8%flow out. Shut down,drop bottom plug followed by 196 bbl 15.8 ppg Gas Block tail cement @ 5 bpm,436 psi,5%flow out. Shut down drop top plug. Kick out plug with 10 bbl water displaced with 5099 strokes rig pumps 9.7 ppg mud. Started chasing @ 8 bpm,caught plug at 980 stks,slowed down to 2 bpm as plus went by the DDV. Displaced at 5 bpm.At 4700 stks reduced rate to 1 bpm,took returns to cellar lowering hanger to 1'off landed. Bump plugs @ 5099 820 psi, increase to 1320 psi held 5 minutes. Bleed pressure and check floats good. Flush stack and landing profile with water before landing hanger. Land casing on depth @ 11677'MD CIP 09:30.P/U=250k,S/0=124k. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Intermediate Casing Cement to>500'above C 8,100.0 11,688.0 Yes Yes Yes Cement -37(8100'MD) Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) 'Rotated? Pipe RPM(rpm) 5 6 5 820.0 1,320.0 Yes 15.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pumped 51 bbl 11.5 ppg MudPush II, 196 bbl 15.8 ppf GasBlok tail cement,displace with 10 bbl water and 513 bbl 9.7 ppg LSND. Bump plugs and floats held. Full returns throughout job Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Cement 8,100.0 11,688.0 941 G 196.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 2.96 15.80 100.0 5.50 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.15 %BWOC Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 6/24/2015 • Cement Detail Report 2N-312 ConocoPhillstps String: Production Liner 3 1/2"#9.2 L-80 Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Production Liner 3 1/2"#9.2 L-80 5/28/2015 18:00 5/28/2015 18:46 2N-312 Comment Cement 3 1/2"liner per program; Pump 5 BBLs water and PT surface lines; Good to 4000 psi. Reciprocate throughout cement job. Pump 31 BBIs Mudpush II at 3 BPM with 800 psi. Pump 61.1 BBLs 15.8 ppg cement slurry at 3 BPM with 750 psi, increase rate to 3.5 BPM with 600 psi. FCP=475 psi. Shut down and bleed off,close lower TIW and flush lines with 5 BBL water. Open lower TIW and drop dart,kick out with 10 BBLs water. Isolate SLB and swap to rig pumps. Chase cement with 10.5 drilling mud at 4 BPM ICP=930 psi, FCP= 1030 psi. Reduce rate to 3.5 BPM with FCP= 1200 psi. At 980 strokes away reduce rate to 2 BPM with 1200 psi. Set liner on depth at 12949'and bump plug with 1215 strokes and increase and hold 2300 psi, increase to 2500 while holding, increase to 4000 psi and hold pressure for 15 minutes. Bleed off and check floats;Good. Set 50 down weight to insure hanger set;Good. Release hanger and rotate down on dogs to shear. Set 30K down weight and pump 500 psi on packer,pull out of packer and note pressure decrease. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? Production Liner 3 1/2" Cement liner for injection 11,533.0 12,950.0 No No No #9.2 L-80 well Q Pump Init(bbl/m...Q Pump Final(bbl/... Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 7 2 3 1,800.0 2,300.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Pump 5 bbls H2O spacer,31 bbls 11.5 ppg MudPush II,61 bbls 15.8 ppg cement, 10 bbls H2O to launch dart. Pump 124 bbls 10.5 mud with rig, Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Production Cement 11,533.0 12,950.0 291 G Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa.$) Thickening Time(hr) CmprStr 1(psi) 5.50 Additives Additive Type Concentration Conc Unit label Antifoam D047 0.2 gal/sx Additive Type Concentration Conc Unit label Dispersant D065 0.4 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control D167 0.15 %BWOC Additive Type Concentration Conc Unit label Retarder D177 0.01 gal/sx Additive Type Concentration Conc Unit label Gas Block D600G 2.0 gal/sx Page 1/1 Report Printed: 6/24/2015 0 • 11 5028 25931 RFCELVFD SehlUMbergerjuN � 1 2���? Transmittal#: 11JUN15-SP02 PetroTechnicaI ServicesDATA LOGGED Gy��'`�� `; Product DeliveryC /2gi2015 M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2N-312T.O.C. Date Dispatched: 11-Jun-15 Job#: 14AKA0123 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 1 Contents on CD N/A PTS Answer Product SonicScope:Top of Cement x x LAS Digital Data N/A Contents on CD N/A x Directional Data N/A Contents on CD N/A As-Built Survey N/A Contents on CD N/A CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(a�conocophillips.com AlaskaPTSPrintCenter(a�slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 AT0 1707 G �l� /1 �V6 Received By: o q�,hr 0 • L15UL8 25932 :LIVE S cblumberger"N 1 1 Transmittal#: 11JUN15-SP01 Drilling & Measurements AOGCCn�+ DATA LOGGED MWD/LWD Log Product Delivery ro rzswo1s M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: AOGCC: Makana Bender Well No: 2N-312 Date Dispatched: 11-Jun-15 Job#: 14AKA0123 Dispatched By: Stephanie Pacillo Well/ Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 4 Contents on CD N/A VISION*Service 2" MD x x VISION*Service 2"TVD x x VISION*Service 5"MD x x VISION*Service 5"TVD x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x CD 1 Contents on CD N/A Data: DLIS/ASCII x Graphics:pdf/tiff x Surveys:pdf/txt x Please sign and email a copy to: Please sign and email a copy to: Catherine.Roso(cconocophillips.com AlaskaPTSPrintCenter(slb.com Catherine Roso Attn:Stephanie Pacillo 907-265-6189 ATO 1707mvaia4z4A....4.-/) 6.444.i' Received By: • • 21 5028 25 93 2 FINAL REczNED NADConversion JUN 11 2a3 Kuparuk River Unit Kuparuk 2N Pad AOGOC 2N-312 Definitive Survey Report NAD 27 01 June, 2015 • 0 Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 164,036.12 usft Northing: 5,911,977.02 usfl Latitude: 70°10'13.664 N +E/-W -1,126,701.37 usft Easting: 460,961.62 usfl Longitude: 150°18'51.070 W Position Uncertainty 0.00 usft Wellhead Elevation: usfl Ground Level: 117.70 usft !Wellbore 2N-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (°) 39.79 164,036.1: -1,126,701 39.00 Survey Program Date From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:3 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8:3! 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1:5' 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:1' Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (0/100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 164,036.12-1,126,701.37 5,911,977.02 460,961.62 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 164,036.24-1,126,701.52 5,911,977.12 460,961.45 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 164,036.84-1,126,702.17 5,911,977.62 460,960.72 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 164,037.12-1,126,702.43 5,911,977.86 460,960.42 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 164,035.48-1,126,701.47 5,911,976.37 460,961.61 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 164,031.11-1,126,698.77 5,911,972.43 460,964.91 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 164,025.43-1,126,694.62 5,911,967.40 460,969.85 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 164,018.59-1,126,688.69 5,911,961.47 460,976.70 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 164,009.69 -1,126,680.41 5,911,953.84 460,986.19 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 163,998.67-1,126,669.67 5,911,944.47 460,998.42 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 163,985.97-1,126,656.95 5,911,933.73 461,012.85 2.25 -11.02 GYD-GC-SS(1) 978.85 13.11 133.85 972.74 815.25 163,976.88-1,126,647.68 5,911,926.05 461,023.34 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 163,960.72-1,126,630.09 5,911,912.58 461,043.11 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 163,942.42-1,126,609.21 5,911,897.45 461,066.43 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 163,925.14-1,126,584.82 5,911,883.84 461,093.08 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 6/1/2015 3:12:37PM Page 2 COMPASS 5000.1 Build 65 • . _ Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 1,356.78 19.98 113.66 1,333.15 1,175.66 163,910.97-1,126,556.74 5,911,873.84 461,122.95 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 163,899.70-1,126,526.52 5,911,867.03 461,154.51 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 163,891.80-1,126,493.59 5,911,863.95 461,188.29 3.63 18.60 MWD+IFR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 163,888.43-1,126,457.20 5,911,865.85 461,224.83 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 163,888.04-1,126,415.80 5,911,871.42 461,265.91 2.68 64.63 MWD+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 163,889.94-1,126,372.36 5,911,879.56 461,308.67 4.52 93.45 MWD+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 163,897.18-1,126,323.59 5,911,893.76 461,355.95 4.48 129.76 MWD+IFR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 163,909.59-1,126,272.69 5,911,913.39 461,404.61 3.36 171.45 MWD+I FR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 163,924.50-1,126,219.38 5,911,935.84 461,455.28 1.59 216.57 MWD+I FR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 163,939.56-1,126,165.05 5,911,958.59 461,506.94 3.08 262.47 MWD+IFR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 163,957.22-1,126,105.27 5,911,984.70 461,563.63 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 163,978.57-1,126,041.51 5,912,015.04 461,623.74 4.39 370.53 MWD+I FR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 164,004.28-1,125,974.31 5,912,050.20 461,686.62 4.15 432.81 MWD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 164,033.01-1,125,904.84 5,912,088.67 461,751.32 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 164,057.54-1,125,847.19 5,912,121.27 461,804.91 3.75 554.20 MWD+I F R-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 164,082.70-1,125,792.00 5,912,154.16 461,855.97 3.14 608.48 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2.. 2,758.81 59.33 63.63 2,428.38 2,270.89 164,092.03-1,125,772.86 5,912,166.16 rt461,873.59 3.14 627.78 MW D+I FR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 164,130.14-1,125,701.08 5,912,214.25 461,939.23 2.93 702.56 MW D+I FR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 164,173.56-1,125,630.29 5,912,267.48 462,003.11 3.88 780.86 MWD+I FR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 164,221.05-1,125,561.41 5,912,324.45 462,064.52 3.52 861.11 MWD+I FR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 164,271.97-1,125,493.52 5,912,384.69 462,124.46 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 164,326.55-1,125,426.84 5,912,448.37 462,182.67 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 164,385.54-1,125,362.36 5,912,516.11 462,238.06 3.71 1,114.21 MWD+I FR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 164,447.69-1,125,302.37 5,912,586.34 462,288.56 3.34 1,200.27 MWD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 164,513.61-1,125,244.24 5,912,660.02 462,336.65 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 164,582.04-1,125,188.87 5,912,735.81 462,381.66 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 164,654.03-1,125,134.14 5,912,815.02 462,425.52 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 164,726.20-1,125,081.89 5,912,894.06 462,466.90 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 164,802.36-1,125,031.12 5,912,976.83 462,506.23 2.32 1,646.60 MWD+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 164,878.24-1,124,981.39 5,913,059.18 462,544.58 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 164,951.66-1,124,930.67 5,913,139.24 462,584.27 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 165,025.48-1,124,878.76 5,913,219.86 462,625.07 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 165,099.13-1,124,826.14 5,913,300.41 462,666.60 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 165,173.10-1,124,772.80 5,913,381.40 462,708.79 0.78 2,097.28 MWD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 165,246.89-1,124,721.47 5,913,461.91 462,749.03 1.17 2,186.93 MWD+IFR-AK-CAZ-SC(3) 4,555.72 72.90 33.56 3,073.19 2,915.70 165,320.96-1,124,671.69 5,913,542.47 462,787.69 0.71 2,275.83 MWD+I FR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 165,397.53-1,124,621.21 5,913,625.61 462,826.67 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 165,473.84-1,124,571.81 5,913,708.34 462,864.64 0.77 2,457.49 MWD+I F R-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 165,549.33-1,124,523.59 5,913,790.08 462,901.54 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 165,625.25-1,124,475.71 5,913,872.20 462,938.04 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 165,701.60-1,124,427.85 5,913,954.75 462,974.48 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 165,776.41-1,124,379.17 5,914,035.89 463,011.93 1.66 2,813.86 MWD+IFR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 165,851.18-1,124,328.78 5,914,117.23 463,051.10 0.23 2,903.68 MWD+IFR-AK-CAZ-SC(3) 6/1/2015 3:12:37PM Page 3 COMPASS 5000.1 Build 65 • • Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 5,314.27 71.88 34.89 3,306.85 3,149.36 165,925.50-1,124,277.72 5,914,198.23 463,090.98 0.80 2,993.57 MWD+IFR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 165,999.61-1,124,227.26 5,914,278.93 463,130.31 1.29 3,082.92 MWD+IFR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 166,075.09-1,124,178.25 5,914,360.78 463,167.99 1.25 3,172.42 MWD+IFR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 166,150.57-1,124,129.84 5,914,442.55 463,205.09 0.68 3,261.55 MWD+IFR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 166,226.32-1,124,079.82 5,914,524.81 463,243.74 0.92 3,351.90 MWD+IFR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 166,300.74-1,124,028.92 5,914,605.88 463,283.46 0.95 3,441.76 MWD+IFR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 166,374.97-1,123,977.62 5,914,686.82 463,323.60 0.38 3,531.74 MWD+IFR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 166,449.17-1,123,926.54 5,914,767.69 463,363.53 0.17 3,621.54 MWD+IFR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 166,523.23-1,123,875.75 5,914,848.39 463,403.18 0.38 3,711.06 MWD+IFR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 166,597.09-1,123,825.29 5,914,928.85 463,442.54 0.22 3,800.22 MWD+IFR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 166,672.07-1,123,774.46 5,915,010.47 463,482.11 0.59 3,890.48 MWD+I FR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 166,747.37-1,123,724.68 5,915,092.25 463,520.59 0.75 3,980.33 MWD+IFR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 166,822.60-1,123,675.63 5,915,173.85 463,558.36 0.03 4,069.66 MWD+IFR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 166,897.49-1,123,626.91 5,915,255.08 463,595.85 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 166,973.38-1,123,577.79 5,915,337.35 463,633.58 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 167,049.72-1,123,528.75 5,915,420.06 463,671.18 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 167,125.34-1,123,480.54 5,915,501.93 463,708.05 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 167,201.29-1,123,432.53 5,915,584.10 463,744.68 0.35 4,516.94 MWD+I F R-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 167,277.82-1,123,383.83 5,915,666.95 463,781.92 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 167,352.34-1,123,334.48 5,915,747.89 463,820.09 1.52 4,696.04 MWD+IF R-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 167,426.77-1,123,282.64 5,915,829.11 463,860.73 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 167,499.55-1,123,229.53 5,915,908.88 463,902.88 1.28 4,876.49 MWD+IF R-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 167,571.86-1,123,175.45 5,915,988.31 463,946.04 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 167,644.89-1,123,121.57 5,916,068.44 463,988.91 0.83 5,057.38 MW D+I FR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 167,717.74-1,123,069.29 5,916,148.16 464,030.22 0.74 5,146.90 MWD+IF R-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 167,791.90-1,123,017.13 5,916,229.15 464,071.22 0.40 5,237.35 MWD+IF R-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 167,865.87-1,122,965.95 5,916,309.82 464,111.28 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 167,940.34-1,122,915.24 5,916,390.91 464,150.81 0.37 5,416.84 MWD+IFR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 168,015.33-1,122,865.04 5,916,472.44 464,189.75 0.54 5,506.70 MWD+IF R-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 168,090.50-1,122,816.06 5,916,553.98 464,227.44 1.14 5,595.95 MWD+IFR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 168,166.32-1,122,768.25 5,916,635.99 464,263.90 0.79 5,684.96 MWD+IFR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 168,243.19-1,122,720.94 5,916,718.97 464,299.71 0.48 5,774.47 MWD+IF R-AK-CAZ-SC(3) 8,343.16 71.71 31.21 4,234.52 4,077.03 168,320.61-1,122,673.89 5,916,802.46 464,335.18 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 168,396.81-1,122,627.38 5,916,884.66 464,370.28 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 168,473.09-1,122,579.84 5,916,967.10 464,406.40 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 168,548.83-1,122,531.20 5,917,049.15 464,443.69 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 168,623.76-1,122,481.20 5,917,130.60 464,482.44 1.17 6,221.10 MWD+I FR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 168,697.70-1,122,430.41 5,917,211.18 464,522.11 0.40 6,310.53 MWD+IFR-AK-CAZSC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 168,771.39-1,122,378.80 5,917,291.63 464,562.64 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 168,844.92-1,122,326.98 5,917,371.95 464,603.39 0.36 6,490.02 MWD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 168,918.41-1,122,275.82 5,917,452.14 464,643.50 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 168,993.22-1,122,224.56 5,917,533.65 464,683.52 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 169,068.01-1,122,174.27 5,917,615.00 464,722.57 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 169,143.33-1,122,126.00 5,917,696.59 464,759.55 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 6/1/2015 3:12:37PM Page 4 COMPASS 5000.1 Build 65 • • . Schlumberger Definitive Survey Report Company: NADConversion Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 9,477.42 72.26 30.26 4,583.36 4,425.87 169,221.02-1,122,079.42 5,917,780.27 464,794.52 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 169,298.73-1,122,034.38 5,917,863.76 464,827.96 0.33 7,026.85 MWD+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 169,377.71-1,121,989.27 5,917,948.52 464,861.28 0.42 7,116.61 MWD+I FR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 169,456.07-1,121,944.04 5,918,032.67 464,894.81 0.95 7,205.97 MWD+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 169,532.30-1,121,897.74 5,918,114.88 464,929.71 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 169,608.77-1,121,847.69 5,918,197.86 464,968.28 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 169,682.31-1,121,797.95 5,918,277.89 465,006.97 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 169,757.71-1,121,746.40 5,918,360.02 465,047.19 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 169,830.43-1,121,693.67 5,918,439.67 465,088.97 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 169,902.45-1,121,639.02 5,918,518.91 465,132.75 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 169,973.42-1,121,584.17 5,918,597.14 465,176.87 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 170,045.02-1,121,528.17 5,918,676.14 465,222.05 0.15 7,925.39 MWD+IFR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 170,115.86-1,121,474.06 5,918,754.14 465,265.46 1.39 8,014.50 MW D+I FR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 170,189.65-1,121,421.81 5,918,834.77 465,306.61 2.78 8,104.72 MWD+IFR-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 170,239.51-1,121,390.29 5,918,888.71 465,330.65 4.98 8,163.30 MW D+I FR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 170,264.47-1,121,375.52 5,918,915.58 465,341.69 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 170,343.90-1,121,328.71 5,919,001.03 465,376.63 0.19 8,283.19 MW D+I FR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 170,421.29-1,121,283.28 5,919,084.25 465,410.50 0.15 8,371.92 MWD+I FR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 170,498.74-1,121,236.00 5,919,167.80 465,446.20 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 170,574.17-1,121,187.13 5,919,249.59 465,483.75 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 170,649.24-1,121,137.35 5,919,331.14 465,522.26 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 170,723.68-1,121,087.39 5,919,412.10 465,561.04 0.47 8,730.20 MWD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 170,798.80-1,121,036.46 5,919,493.86 465,600.69 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 170,874.10-1,120,985.77 5,919,575.78 465,640.07 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 170,919.17-1,120,956.15 5,919,624.70 465,662.93 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,670.00 73.24 33.25 5,251.63 5,094.14 170,961.17-1,120,928.77 5,919,670.26 465,684.01 1.86 9,014.59 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 11,714.45 74.03 33.50 5,264.15 5,106.66 170,996.79 -1,120,905.31 5,919,708.93 465,702.13 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 171,072.26-1,120,855.19 5,919,790.93 465,740.91 1.86 9,147.22 MWD+IFR-AK-CAZ-SC(4) 11,905.96 72.27 31.26 5,321.07 5,163.58 171,150.09-1,120,805.68 5,919,875.18 465,778.77 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 171,227.60-1,120,757.55 5,919,958.92 465,815.29 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 171,303.78-1,120,709.25 5,920,041.36 465,852.18 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 171,338.85-1,120,687.02 5,920,079.32 465,869.15 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 171,414.36-1,120,638.40 5,920,161.14 465,906.45 0.81 9,549.52 MWD+I FR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 171,490.75-1,120,588.89 5,920,243.96 465,944.51 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 171,567.45-1,120,542.42 5,920,326.65 465,979.51 4.59 9,728.89 MWD+I FR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 171,641.67-1,120,496.21 5,920,406.85 466,014.60 4.75 9,815.65 MWD+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 171,713.80-1,120,447.63 5,920,485.31 466,052.35 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 171,784.70-1,120,399.80 5,920,562.45 466,089.53 1.65 9,987.48 MWD+I FR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 171,853.39-1,120,351.93 5,920,637.42 466,127.07 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 171,920.02-1,120,303.66 5,920,710.39 466,165.30 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57,76 35.26 5,696.83 5,539.34 171,931.25-1,120,295.56 5,920,722.68 466,171.71 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 171,955.29-1,120,278.57 5,920,748.95 466,185.09 0.00 10,196.35 PROJECTED to TD 3 1/2"x 6-1/2" 6/1/2015 3:12:37PM Page 5 COMPASS 5000.1 Build 65 • • • Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. (] Yes Q No have checked to the best of my ability that the following data is correct: C Surface Coordinates [j Declination & Convergence [J GRS Survey Corrections Survey Tool Codes Dlgnain signed by Vincent osan DN cn ncent Osara, Vincent Osara o=StltWmberger, 5C111umber9C, SLB DE_ e.p1bDatts 5--703-0800 3 'e Msmn Bow-.l Client Representative: Scott Brunswick "�� Date: 01-Jun-2015 215028 25932 RECEIVED JUN 11 ,t [ FINAL ' ADCC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2N Pad 2N-312 Definitive Survey Report NAD 83 01 June, 2015 • • `, Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Well 2N-312(ShangriLa) Well Position +N/-S 0.00 usft Northing: 5,911,725.97 usft Latitude: 70°10'12.522 N +E/-W 0.00 usft Easting: 1,600,995.72 usft Longitude: 150°19'2.187 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 117.70 usft Wellbore 2N-312 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) l°) (nT) BGGM2014 5/18/2015 18.57 80.75 57,533 Design 2N-312 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 39.79 Vertical Section: Depth From(TVD) +NI-S +E/-W Direction (usft) (usft) (usft) (0) 39.79 0.00 0.00 39.00 Survey Program Date 6/1/2015 From To (usft) (usft) Survey(Wellbore) Tool Name Description Survey Date 81.00 919.30 2N-312 Srvy#1 GYD-GC-SS(2N-312) GYD-GC-SS Gyrodata gyro single shots 5/13/2015 8:37: 978.85 2,662.70 2N-312 Srvy#2 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/13/2015 8:39: 2,758.81 11,617.50 2N-312 Srvy#3 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/18/2015 1:57: 11,714.45 12,915.20 2N-312 Srvy#4 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5/28/2015 4:17:. Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (0) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°1100') (ft) Survey Tool Name 39.79 0.00 0.00 39.79 -117.70 0.00 0.00 5,911,725.97 1,600,995.72 0.00 0.00 UNDEFINED 81.00 0.54 307.67 81.00 -76.49 0.12 -0.15 5,911,726.09 1,600,995.56 1.31 0.00 GYD-GC-SS(1) 169.58 0.61 317.43 169.57 12.08 0.72 -0.80 5,911,726.69 1,600,994.92 0.14 0.05 GYD-GC-SS(1) 260.20 0.13 139.81 260.19 102.70 1.00 -1.06 5,911,726.97 1,600,994.66 0.82 0.11 GYD-GC-SS(1) 353.10 2.22 150.30 353.07 195.58 -0.65 -0.10 5,911,725.32 1,600,995.61 2.25 -0.57 GYD-GC-SS(1) 449.73 3.87 147.10 449.56 292.07 -5.01 2.60 5,911,720.94 1,600,998.28 1.72 -2.26 GYD-GC-SS(1) 542.42 4.85 141.21 541.98 384.49 -10.69 6.75 5,911,715.24 1,601,002.41 1.16 -4.06 GYD-GC-SS(1) 636.40 6.21 137.45 635.52 478.03 -17.53 12.68 5,911,708.37 1,601,008.30 1.50 -5.65 GYD-GC-SS(1) 730.29 8.67 136.82 728.61 571.12 -26.43 20.95 5,911,699.43 1,601,016.53 2.62 -7.36 GYD-GC-SS(1) 825.35 9.97 134.78 822.42 664.93 -37.46 31.70 5,911,688.35 1,601,027.21 1.41 -9.16 GYD-GC-SS(1) 919.30 12.08 135.09 914.63 757.14 -50.15 44.41 5,911,675.59 1,601,039.86 2.25 -11.02 GYD-GC-SS(1) 6/1/2015 2:38:29PM Page 2 COMPASS 5000.1 Build 65 • 0 Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +EI-W Northing Easting DLS Section (usft) (0) (0) (usft) (usft) (usft) (usft) (ft) (ft) (0/1001 (ft) Survey Tool Name 978.85 13.11 133.85 972.74 815.25 -59.24 53.68 5,911,666.45 1,601,049.08 1.79 -12.26 MWD+IFR-AK-CAZ-SC(2) 1,073.02 16.29 131.51 1,063.82 906.33 -75.40 71.28 5,911,650.21 1,601,066.59 3.43 -13.74 MWD+IFR-AK-CAZ-SC(2) 1,167.84 17.76 131.00 1,154.48 996.99 -93.70 92.15 5,911,631.80 1,601,087.37 1.56 -14.82 MWD+IFR-AK-CAZ-SC(2) 1,262.69 19.14 120.03 1,244.48 1,086.99 -110.98 116.54 5,911,614.39 1,601,111.67 3.93 -12.90 MWD+IFR-AK-CAZ-SC(2) 1,356.78 19.98 113.66 1,333.15 1,175.66 -125.15 144.62 5,911,600.08 1,601,139.67 2.43 -6.25 MWD+IFR-AK-CAZ-SC(2) 1,451.24 20.01 107.25 1,421.93 1,264.44 -136.42 174.84 5,911,588.65 1,601,169.83 2.32 4.01 MWD+IFR-AK-CAZ-SC(2) 1,545.37 22.25 100.09 1,509.74 1,352.25 -144.32 207.78 5,911,580.58 1,601,202.72 3.63 18.60 MWD+IFR-AK-CAZ-SC(2) 1,639.10 23.79 90.78 1,596.03 1,438.54 -147.69 244.17 5,911,577.02 1,601,239.09 4.21 38.88 MWD+IFR-AK-CAZ-SC(2) 1,736.73 26.40 90.33 1,684.44 1,526.95 -148.08 285.57 5,911,576.41 1,601,280.48 2.68 64.63 MW1D+IFR-AK-CAZ-SC(2) 1,829.24 29.73 84.95 1,766.07 1,608.58 -146.18 329.00 5,911,578.09 1,601,323.92 4.52 93.45 MW3+IFR-AK-CAZ-SC(2) 1,924.95 32.38 78.41 1,848.08 1,690.59 -138.94 377.77 5,911,585.08 1,601,372.72 4.48 129.76 MWD+IFR-AK-CAZ-SC(2) 2,019.93 34.63 74.31 1,927.28 1,769.79 -126.53 428.68 5,911,597.22 1,601,423.69 3.36 171.45 MWD+IFR-AK-CAZ-SC(2) 2,115.50 36.15 74.45 2,005.19 1,847.70 -111.63 481.98 5,911,611.84 1,601,477.06 1.59 216.57 MWD+IFR-AK-CAZ-SC(2) 2,207.97 39.00 74.55 2,078.47 1,920.98 -96.56 536.31 5,911,626.62 1,601,531.47 3.08 262.47 MWD+IFR-AK-CAZ-SC(2) 2,302.71 43.32 72.62 2,149.79 1,992.30 -78.90 596.09 5,911,643.97 1,601,591.33 4.75 313.82 MWD+IFR-AK-CAZ-SC(2) 2,397.42 47.18 70.43 2,216.46 2,058.97 -57.55 659.86 5,911,664.98 1,601,655.20 4.39 370.53 MWD+IFR-AK-CAZ-SC(2) 2,492.95 50.60 67.76 2,279.26 2,121.77 -31.84 727.06 5,911,690.35 1,601,722.53 4.15 432.81 MVVD+IFR-AK-CAZ-SC(2) 2,587.39 54.93 67.32 2,336.40 2,178.91 -3.11 796.52 5,911,718.71 1,601,792.13 4.60 498.85 MWD+IFR-AK-CAZ-SC(2) 2,662.70 57.69 66.60 2,378.17 2,220.68 21.42 854.18 5,911,742.93 1,601,849.91 3.75 554.20 MWD+IFR-AK-CAZ-SC(2) 2,734.00 58.90 64.39 2,415.64 2,258.15 46.58 909.36 5,911,767.81 1,601,905.22 3.14 608.48 MWD+IFR-AK-CAZ-SC(3) 10 3/4"x 13-1/2 2,758.81 59.33 63.63 2,428.38 2,270.89 55.91 928.50 5,911,777.04 1,601,924.41 3.14 627.78 MWD+IFR-AK-CAZ-SC(3) 2,853.12 59.73 60.46 2,476.21 2,318.72 94.01 1,000.29 5,911,814.76 1,601,996.38 2.93 702.56 MWD+IFR-AK-CAZ-SC(3) 2,948.64 61.11 56.51 2,523.37 2,365.88 137.44 1,071.07 5,911,857.81 1,602,067.38 3.88 780.86 MWD+IFR-AK-CAZ-SC(3) 3,043.01 63.82 54.35 2,567.00 2,409.51 184.93 1,139.95 5,911,904.94 1,602,136.51 3.52 861.11 MWD+IFR-AK-CAZ-SC(3) 3,137.21 64.77 51.92 2,607.86 2,450.37 235.85 1,207.85 5,911,955.50 1,602,204.66 2.53 943.41 MWD+IFR-AK-CAZ-SC(3) 3,232.26 65.32 49.48 2,647.97 2,490.48 290.43 1,274.53 5,912,009.72 1,602,271.61 2.40 1,027.79 MWD+IFR-AK-CAZ-SC(3) 3,328.25 65.88 45.62 2,687.64 2,530.15 349.42 1,339.01 5,912,068.37 1,602,336.39 3.71 1,114.21 MWD+IFR-AK-CAZ-SC(3) 3,422.54 66.90 42.37 2,725.41 2,567.92 411.57 1,399.00 5,912,130.20 1,602,396.70 3.34 1,200.27 MVVD+IFR-AK-CAZ-SC(3) 3,517.42 68.85 40.45 2,761.14 2,603.65 477.49 1,457.12 5,912,195.81 1,602,455.16 2.78 1,288.07 MWD+IFR-AK-CAZ-SC(3) 3,611.14 71.07 37.53 2,793.26 2,635.77 545.92 1,512.50 5,912,263.95 1,602,510.89 3.77 1,376.10 MWD+IFR-AK-CAZ-SC(3) 3,706.23 72.93 36.96 2,822.65 2,665.16 617.91 1,567.23 5,912,335.64 1,602,565.98 2.04 1,466.49 MWD+IFR-AK-CAZ-SC(3) 3,799.47 72.82 34.85 2,850.10 2,692.61 690.08 1,619.48 5,912,407.53 1,602,618.61 2.17 1,555.46 MWD+IFR-AK-CAZ-SC(3) 3,895.29 72.78 32.52 2,878.44 2,720.95 766.24 1,670.24 5,912,483.42 1,602,669.76 2.32 1,646.60 MW3+IFR-AK-CAZ-SC(3) 3,990.25 72.87 33.96 2,906.48 2,748.99 842.12 1,719.97 5,912,559.03 1,602,719.88 1.45 1,736.86 MWD+IFR-AK-CAZ-SC(3) 4,083.66 72.77 35.32 2,934.08 2,776.59 915.54 1,770.70 5,912,632.18 1,602,770.98 1.40 1,825.84 MWD+IFR-AK-CAZ-SC(3) 4,178.12 72.88 34.91 2,961.97 2,804.48 989.36 1,822.61 5,912,705,72 1,602,823.27 0.43 1,915.88 MWD+IFR-AK-CAZ-SC(3) 4,272.84 72.84 36.18 2,989.89 2,832.40 1,063.01 1,875.23 5,912,779.09 1,602,876.27 1.28 2,006.23 MWD+IFR-AK-CAZ-SC(3) 4,368.28 72.87 35.40 3,018.02 2,860.53 1,136.98 1,928.56 5,912,852.78 1,602,929.98 0.78 2,097.28 MVVD+IFR-AK-CAZ-SC(3) 4,462.34 72.88 34.25 3,045.72 2,888.23 1,210.77 1,979.89 5,912,926.29 1,602,981.69 1.17 2,186.93 MVVD+IFR-AK-CAZ-SC(3) 6/1/2015 2:38:29PM Page 3 COMPASS 5000.1 Build 65 • • *. Schlumberger ConocoPhilhps Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 4,555.72 72.90 33.56 3,073.19 2,915.70 1,284.84 2,029.68 5,913,000.09 1,603,031.86 0.71 2,275.83 MWD+IFR-AK-CAZ-SC(3) 4,651.71 72.74 33.23 3,101.55 2,944.06 1,361.41 2,080.15 5,913,076.39 1,603,082.73 0.37 2,367.10 MWD+IFR-AK-CAZ-SC(3) 4,747.02 72.30 32.61 3,130.17 2,972.68 1,437.72 2,129.56 5,913,152.43 1,603,132.52 0.77 2,457.49 MWD+IFR-AK-CAZ-SC(3) 4,841.17 71.82 32.53 3,159.17 3,001.68 1,513.20 2,177.78 5,913,227.66 1,603,181.13 0.52 2,546.50 MWD+IFR-AK-CAZ-SC(3) 4,935.64 71.82 31.94 3,188.65 3,031.16 1,589.12 2,225.65 5,913,303.32 1,603,229.40 0.59 2,635.63 MWD+IFR-AK-CAZ-SC(3) 5,030.51 71.74 32.23 3,218.31 3,060.82 1,665.47 2,273.52 5,913,379.41 1,603,277.65 0.30 2,725.09 MWD+IFR-AK-CAZ-SC(3) 5,124.49 71.79 33.87 3,247.72 3,090.23 1,740.29 2,322.20 5,913,453.97 1,603,326.72 1.66 2,813.86 MWD+IFR-AK-CAZ-SC(3) 5,219.39 71.86 34.09 3,277.32 3,119.83 1,815.06 2,372.59 5,913,528.46 1,603,377.49 0.23 2,903.68 MWD+IFR-AK-CAZ-SC(3) 5,314.27 71.88 34.89 3,306.85 3,149.36 1,889.38 2,423.65 5,913,602.51 1,603,428.93 0.80 2,993.57 MWD+IFR-AK-CAZ-SC(3) 5,408.61 71.88 33.61 3,336.19 3,178.70 1,963.49 2,474.11 5,913,676.35 1,603,479.78 1.29 3,082.92 MWD+IFR-AK-CAZ-SC(3) 5,503.32 71.82 32.37 3,365.69 3,208.20 2,038.97 2,523.11 5,913,751.57 1,603,529.16 1.25 3,172.42 MWD+IFR-AK-CAZ-SC(3) 5,597.63 72.09 32.98 3,394.91 3,237.42 2,114.45 2,571.52 5,913,826.79 1,603,577.96 0.68 3,261.55 MWD+IFR-AK-CAZ-SC(3) 5,693.00 72.19 33.90 3,424.16 3,266.67 2,190.20 2,621.54 5,913,902.27 1,603,628.37 0.92 3,351.90 MWD+IFR-AK-CAZ-SC(3) 5,787.71 72.16 34.84 3,453.15 3,295.66 2,264.62 2,672.44 5,913,976.41 1,603,679.66 0.95 3,441.76 MWD+IFR-AK-CAZ-SC(3) 5,882.50 72.17 34.46 3,482.18 3,324.69 2,338.85 2,723.75 5,914,050.37 1,603,731.34 0.38 3,531.74 MWD+IFR-AK-CAZ-SC(3) 5,977.12 72.18 34.63 3,511.15 3,353.66 2,413.05 2,774.83 5,914,124.29 1,603,782.80 0.17 3,621.54 MWD+IFR-AK-CAZ-SC(3) 6,071.44 72.21 34.25 3,539.99 3,382.50 2,487.11 2,825.61 5,914,198.08 1,603,833.97 0.38 3,711.06 MWD+IFR-AK-CAZ-SC(3) 6,165.42 72.09 34.43 3,568.79 3,411.30 2,560.97 2,876.08 5,914,271.67 1,603,884.81 0.22 3,800.22 MVVD+IFR-AK-CAZ-SC(3) 6,260.60 72.16 33.84 3,598.01 3,440.52 2,635.95 2,926.91 5,914,346.38 1,603,936.03 0.59 3,890.48 MWD+IFR-AK-CAZ-SC(3) 6,355.45 72.07 33.10 3,627.14 3,469.65 2,711.25 2,976.69 5,914,421.41 1,603,986.19 0.75 3,980.33 MVVD+IFR-AK-CAZ-SC(3) 6,449.85 72.04 33.11 3,656.22 3,498.73 2,786.48 3,025.74 5,914,496.37 1,604,035.63 0.03 4,069.66 MWD+IFR-AK-CAZ-SC(3) 6,543.78 72.01 32.98 3,685.21 3,527.72 2,861.37 3,074.46 5,914,571.00 1,604,084.73 0.14 4,158.52 MWD+IFR-AK-CAZ-SC(3) 6,638.78 72.15 32.84 3,714.44 3,556.95 2,937.26 3,123.57 5,914,646.62 1.604,134.24 0.20 4,248.40 MWD+IFR-AK-CAZ-SC(3) 6,734.13 72.07 32.59 3,743.73 3,586.24 3,013.60 3,172.61 5,914,722.71 1,604,183.67 0.26 4,338.60 MWD+IFR-AK-CAZ-SC(3) 6,828.41 71.98 32.45 3,772.83 3,615.34 3,089.22 3,220.82 5,914,798.06 1,604,232.27 0.17 4,427.70 MWD+IFR-AK-CAZ-SC(3) 6,922.86 72.13 32.14 3,801.93 3,644.44 3,165.17 3,268.83 5,914,873.76 1,604,280.67 0.35 4,516.94 MWD+IFR-AK-CAZ-SC(3) 7,018.18 72.09 32.81 3,831.21 3,673.72 3,241.70 3,317.54 5,914,950.02 1,604,329.76 0.67 4,607.07 MWD+IFR-AK-CAZ-SC(3) 7,111.99 72.57 34.22 3,859.68 3,702.19 3,316.22 3,366.89 5,915,024.28 1,604,379.50 1.52 4,696.04 MWD+IFR-AK-CAZ-SC(3) 7,207.03 72.66 35.49 3,888.08 3,730.59 3,390.64 3,418.72 5,915,098.42 1,604,431.72 1.28 4,786.50 MWD+IFR-AK-CAZ-SC(3) 7,301.42 72.70 36.75 3,916.18 3,758.69 3,463.43 3,471.84 5,915,170.93 1,604,485.21 1.28 4,876.49 MWD+IFR-AK-CAZ-SC(3) 7,396.02 72.58 36.83 3,944.41 3,786.92 3,535.74 3,525.91 5,915,242.95 1,604,539.65 0.15 4,966.71 MWD+IFR-AK-CAZ-SC(3) 7,491.18 72.44 36.01 3,973.01 3,815.52 3,608.77 3,579.80 5,915,315.69 1.604,593.91 0.83 5,057.38 MWD+IFR-AK-CAZ-SC(3) 7,585.17 72.67 35.32 4,001.19 3,843.70 3,681.62 3,632.08 5,915,388.26 1,604,646.56 0.74 5,146.90 MWD+IFR-AK-CAZ-SC(3) 7,680.15 72.64 34.92 4,029.50 3,872.01 3,755.78 3,684.23 5,915,462.13 1,604,699.10 0.40 5,237.35 MVVD+IFR-AK-CAZ-SC(3) 7,774.51 72.21 34.44 4,058.00 3,900.51 3,829.75 3,735.42 5,915,535.83 1,604,750.66 0.67 5,327.05 MWD+IFR-AK-CAZ-SC(3) 7,869.12 72.25 34.07 4,086.87 3,929.38 3,904.22 3,786.13 5,915,610.03 1,604,801.76 0.37 5,416.84 MWD+IFR-AK-CAZ-SC(3) 7,963.87 72.25 33.53 4,115.76 3,958.27 3,979.21 3,836.33 5,915,684.75 1,604,852.34 0.54 5,506.70 MWD+IFR-AK-CAZ-SC(3) 8,058.25 71.60 32.63 4,145.04 3,987.55 4,054.38 3,885.30 5,915,759.66 1.604,901.70 1.14 5,595.95 MWD+IFR-AK-CAZ-SC(3) 8,152.69 71.69 31.85 4,174.78 4,017.29 4,130.20 3,933.12 5,915,835.22 1,604,949.91 0.79 5,684.96 MWD+IFR-AK-CAZ-SC(3) 8,247.75 71.74 31.37 4,204.60 4,047.11 4,207.07 3,980.43 5,915,911.83 1,604,997.61 0.48 5,774.47 MW13+IFR-AK-CAZ-SC(3) 6/1/2015 2:38:29PM Page 4 COMPASS 5000.1 Build 65 • 11110 Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (usft) (') (°) (usft) (usft) (usft) (usft) (ft) (ft) ("/700') (ft) Survey Tool Name 8,343.16 71.71 31.21 4,234.52 4,077.03 4,284.49 4,027.48 5,915,989.00 1,605,045.06 0.16 5,864.25 MWD+IFR-AK-CAZ-SC(3) 8,437.17 71.73 31.58 4,264.01 4,106.52 4,360.68 4,073.98 5,916,064.94 1,605,091.95 0.37 5,952.73 MWD+IFR-AK-CAZ-SC(3) 8,531.83 71.73 32.29 4,293.69 4,136.20 4,436.97 4,121.53 5,916,140.97 1,605,139.89 0.71 6,041.93 MWD+IFR-AK-CAZ-SC(3) 8,626.50 72.18 33.13 4,323.01 4,165.52 4,512.70 4,170.17 5,916,216.44 1,605,188.92 0.97 6,131.40 MWD+IFR-AK-CAZ-SC(3) 8,721.12 72.19 34.29 4,351.96 4,194.47 4,587.64 4,220.16 5,916,291.11 1,605,239.30 1.17 6,221.10 MWD+IFR-AK-CAZ-SC(3) 8,815.35 72.16 34.68 4,380.81 4,223.32 4,661.58 4,270.95 5,916,364.78 1,605,290.47 0.40 6,310.53 MWD+IFR-AK-CAZ-SC(3) 8,909.84 72.22 35.34 4,409.71 4,252.22 4,735.26 4,322.57 5,916,438.19 1,605,342.46 0.67 6,400.27 MWD+IFR-AK-CAZ-SC(3) 9,004.33 72.13 35.00 4,438.63 4,281.14 4,808.80 4,374.38 5,916,511.44 1,605,394.65 0.36 6,490.02 MVVD+IFR-AK-CAZ-SC(3) 9,098.39 72.24 34.69 4,467.41 4,309.92 4,882.29 4,425.55 5,916,584.66 1,605,446.20 0.33 6,579.34 MWD+IFR-AK-CAZ-SC(3) 9,193.64 72.16 34.15 4,496.53 4,339.04 4,957.10 4,476.81 5,916,659.20 1,605,497.84 0.55 6,669.74 MWD+IFR-AK-CAZ-SC(3) 9,288.30 72.21 33.68 4,525.49 4,368.00 5,031.89 4,527.09 5,916,733.71 1,605,548.51 0.48 6,759.50 MWD+IFR-AK-CAZ-SC(3) 9,382.28 72.13 31.63 4,554.27 4,396.78 5,107.21 4,575.36 5,916,808.77 1,605,597.17 2.08 6,848.42 MWD+IFR-AK-CAZ-SC(3) 9,477.42 72.26 30.26 4,583.36 4,425.87 5,184.90 4,621.94 5,916,886.21 1,605,644.15 1.38 6,938.10 MWD+IFR-AK-CAZ-SC(3) 9,571.75 72.18 29.94 4,612.16 4,454.67 5,262.61 4,666.99 5,916,963.68 1,605,689.59 0.33 7,026.85 MW1D+IFR-AK-CAZ-SC(3) 9,667.29 72.18 29.52 4,641.40 4,483.91 5,341.59 4,712.10 5,917,042.42 1,605,735.11 0.42 7,116.61 MWD+IFR-AK-CAZ-SC(3) 9,762.31 72.22 30.47 4,670.45 4,512.96 5,419.95 4,757.32 5,917,120.53 1,605,780.74 0.95 7,205.97 MW3+IFR-AK-CAZ-SC(3) 9,855.97 72.27 32.08 4,699.01 4,541.52 5,496.18 4,803.63 5,917,196.51 1,605,827.44 1.64 7,294.36 MWD+IFR-AK-CAZ-SC(3) 9,951.96 72.14 34.32 4,728.35 4,570.86 5,572.65 4,853.67 5,917,272.71 1,605,877.87 2.23 7,385.28 MWD+IFR-AK-CAZ-SC(3) 10,045.22 72.21 33.83 4,756.90 4,599.41 5,646.19 4,903.41 5,917,345.99 1,605,927.99 0.51 7,473.73 MWD+IFR-AK-CAZ-SC(3) 10,141.12 72.28 34.89 4,786.15 4,628.66 5,721.59 4,954.96 5,917,421.10 1,605,979.92 1.06 7,564.76 MWD+IFR-AK-CAZ-SC(3) 10,235.44 72.24 37.01 4,814.89 4,657.40 5,794.30 5,007.70 5,917,493.54 1,606,033.03 2.14 7,654.47 MWD+IFR-AK-CAZ-SC(3) 10,330.37 72.27 37.37 4,843.82 4,686.33 5,866.33 5,062.35 5,917,565.27 1,606,088.05 0.36 7,744.83 MWD+IFR-AK-CAZ-SC(3) 10,424.57 72.14 38.02 4,872.61 4,715.12 5,937.30 5,117.19 5,917,635.95 1,606,143.26 0.67 7,834.50 MWD+IFR-AK-CAZ-SC(3) 10,520.03 72.28 38.05 4,901.78 4,744.29 6,008.89 5,173.20 5,917,707.24 1,606,199.63 0.15 7,925.39 MWD+IFR-AK-CAZ-SC(3) 10,613.65 72.16 36.69 4,930.36 4,772.87 6,079.74 5,227.30 5,917,777.80 1,606,254.10 1.39 8,014.50 MWD+IFR-AK-CAZ-SC(3) 10,708.69 71.98 33.92 4,959.63 4,802.14 6,153.53 5,279.56 5,917,851.31 1,606,306.73 2.78 8,104.72 MWD+IFR-AK-CAZ-SC(3) 10,770.73 71.95 30.67 4,978.84 4,821.35 6,203.38 5,311.07 5,917,900.99 1,606,338.50 4.98 8,163.30 MWD+IFR-AK-CAZ-SC(3) 10,801.22 72.19 30.57 4,988.23 4,830.74 6,228.35 5,325.85 5,917,925.88 1,606,353.41 0.85 8,192.00 MWD+IFR-AK-CAZ-SC(3) 10,898.02 72.34 30.45 5,017.71 4,860.22 6,307.78 5,372.66 5,918,005.06 1,606,400.63 0.19 8,283.19 MWD+IFR-AK-CAZ-SC(3) 10,992.16 72.46 30.38 5,046.18 4,888.69 6,385.17 5,418.08 5,918,082.20 1,606,446.45 0.15 8,371.92 MWD+IFR-AK-CAZ-SC(3) 11,087.40 72.19 32.43 5,075.10 4,917.61 6,462.61 5,465.36 5,918,159.39 1,606,494.13 2.07 8,461.86 MWD+IFR-AK-CAZ-SC(3) 11,181.80 72.23 33.44 5,103.94 4,946.45 6,538.05 5,514.23 5,918,234.57 1,606,543.39 1.02 8,551.24 MWD+IFR-AK-CAZ-SC(3) 11,276.38 72.25 33.66 5,132.79 4,975.30 6,613.12 5,564.01 5,918,309.37 1,606,593.55 0.22 8,640.91 MWD+IFR-AK-CAZ-SC(3) 11,370.46 72.46 34.07 5,161.31 5,003.82 6,687.56 5,613.97 5,918,383.54 1,606,643.89 0.47 8,730.20 MVVD+IFR-AK-CAZ-SC(3) 11,465.67 72.35 34.21 5,190.09 5,032.60 6,762.68 5,664.91 5,918,458.38 1,606,695.21 0.18 8,820.63 MWD+IFR-AK-CAZ-SC(3) 11,560.91 72.40 33.68 5,218.93 5,061.44 6,837.98 5,715.59 5,918,533.41 1,606,746.28 0.53 8,911.05 MWD+IFR-AK-CAZ-SC(3) 11,617.50 72.31 32.95 5,236.08 5,078.59 6,883.04 5,745.21 5,918,578.32 1,606,776.13 1.24 8,964.71 MWD+IFR-AK-CAZ-SC(3) 11,670.00 73.24 33.25 5,251.63 5,094.14 6,925.05 5,772.59 5,918,620.18 1,606,803.73 1.86 9,014.59 MWD+IFR-AK-CAZ-SC(4) 7-5/8"x 9-7/8" 11,714.45 74.03 33.50 5,264.15 5,106.66 6,960.67 5,796.06 5,918,655.67 1,606,827.38 1.86 9,057.03 MWD+IFR-AK-CAZ-SC(4) 11,809.11 72.28 33.67 5,291.58 5,134.09 7,036.14 5,846.17 5,918,730.87 1,606,877.88 1.86 9,147.22 MWD+IFR-AK-CAZ-SC(4) 6/1/2015 2:38:29PM Page 5 COMPASS 5000.1 Build 65 • • v.. Schlumberger ConocoPhillips Definitive Survey Report Company: ConocoPhillips(Alaska)Inc.-Kup2 Local Co-ordinate Reference: Well 2N-312(ShangriLa) Project: Kuparuk River Unit TVD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Site: Kuparuk 2N Pad MD Reference: Rig:39.79+117.7 @ 157.49usft(Doyon 25) Well: 2N-312(ShangriLa) North Reference: True Wellbore: 2N-312 Survey Calculation Method: Minimum Curvature Design: 2N-312 Database: OAKEDMP2 Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +El-W Northing Easting DLS Section (usft) (°) (°) (usft) (usft) (usft) (usft) (ft) (ft) (°/100') (ft) Survey Tool Name 11,905.96 72.27 31.26 5,321.07 5,163.58 7,113.97 5,895.69 5,918,808.43 1,606,927.80 2.37 9,238.87 MWD+IFR-AK-CAZ-SC(4) 12,001.74 72.31 32.41 5,350.21 5,192.72 7,191.48 5,943.81 5,918,885.68 1,606,976.32 1.14 9,329.39 MWD+IFR-AK-CAZ-SC(4) 12,096.39 72.41 32.35 5,378.89 5,221.40 7,267.66 5,992.12 5,918,961.60 1,607,025.02 0.12 9,418.99 MWD+IFR-AK-CAZ-SC(4) 12,139.95 72.46 32.38 5,392.03 5,234.54 7,302.73 6,014.35 5,918,996.56 1,607,047.43 0.13 9,460.24 MWD+IFR-AK-CAZ-SC(4) 12,234.10 72.59 33.17 5,420.31 5,262.82 7,378.24 6,062.96 5,919,071.80 1,607,096.43 0.81 9,549.52 MWD+IFR-AK-CAZ-SC(4) 12,329.71 71.80 32.73 5,449.54 5,292.05 7,454.63 6,112.47 5,919,147.92 1,607,146.34 0.94 9,640.04 MWD+IFR-AK-CAZ-SC(4) 12,425.08 68.51 29.66 5,481.92 5,324.43 7,531.33 6,158.95 5,919,224.37 1,607,193.20 4.59 9,728.89 MWD+IFR-AK-CAZ-SC(4) 12,519.63 66.84 34.17 5,517.85 5,360.36 7,605.55 6,205.15 5,919,298.35 1,607,239.79 4.75 9,815.65 MW1D+IFR-AK-CAZ-SC(4) 12,614.82 65.17 33.76 5,556.56 5,399.07 7,677.67 6,253.74 5,919,370.21 1,607,288.74 1.80 9,902.28 MWD+IFR-AK-CAZ-SC(4) 12,709.64 63.67 34.25 5,597.50 5,440.01 7,748.57 6,301.56 5,919,440.85 1,607,336.93 1.65 9,987.48 MWD+IFR-AK-CAZ-SC(4) 12,803.89 61.69 35.50 5,640.75 5,483.26 7,817.27 6,349.43 5,919,509.29 1,607,385.16 2.41 10,070.99 MWD+IFR-AK-CAZ-SC(4) 12,898.88 58.37 36.36 5,688.20 5,530.71 7,883.90 6,397.70 5,919,575.66 1,607,433.77 3.58 10,153.15 MWD+IFR-AK-CAZ-SC(4) 12,915.20 57.76 35.26 5,696.83 5,539.34 7,895.13 6,405.81 5,919,586.85 1,607,441.93 6.83 10,166.97 MWD+IFR-AK-CAZ-SC(4) 12,950.00 57.76 35.26 5,715.40 5,557.91 7,919.16 6,422.80 5,919,610.79 1,607,459.05 0.00 10,196.35 PROJECTED to TD 3 1/2"x 6-1/2" Final Definitive Survey Verified and Signed-off All targets and/or well position objectives have been achieved. 0 Yes 0 No I have checked to the best of my ability that the following data is correct: G Surface Coordinates Lj Declination & Convergence [� GRS Survey Corrections 0 Survey Tool Codes Digitally signed try vkxent°tara DN:cri=tencent Mark Vincent Osara o=scelamberger,ou=scnlumberger, SLB DE: Daffi11701�.11s52163 moa Client Representative: Scott Brunswick Zs:k`: °.c..7 7Dir Date: 01-Jun-2015 6/1/2015 2:38:29PM Page 6 COMPASS 5000.1 Build 65 IP • o, ot, f rr , „-o-, \I%% -�� THE STATE Alaska ii anti as 4F � —`'A ®f � Conservation Commission - � LA KA 'rux _iv==\\,........ 333 West Seventh Avenue iiozmh;, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Tyson Wiese Sr. Wells Engineer _ D ConocoPhillips Alaska, Inc. I S P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-312 Sundry Number: 315-348 Dear Mr. Wiese: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 'e),— Daniel T. Seamount, Jr. Commissioner DATED this ay of June, 2015 Y Encl. STATE OF ALAS AIRKAOIL AND GAS CON ERVATIONCOM•ION RECEIVED " f; APPLICATION FOR SUNDRY APPROVALS JUN 0 5 2015 20 AAC 25.280 z---\i. ; 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing fl Operatibrts SShutdow n r Suspend r Perforate P" . Other Stimulate E Alter Casing fl Change Approved Program Rug for Redrill fl Perforate New Pool f Repair Well I Re-enter Susp Well fl Other: (-` 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development fl 215-028-0 3.Address: 6.API Number: Stratigraphic r Service P.O. Box 100360,Anchorage,Alaska 99510 50-103-20706-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? *h Will planned perforations require spacing exception? Yes r No i il' JCO430A KRU 2N-312 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380053,390982,375074 < Kuparuk River Field/Tarn Oil Pool . 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12950 5715 12917' 5697' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 118 16 158' 158' SURFACE 2693 10.75 2734' 2415' INTERMEDIATE 11639 7.625 11677' 5251' 3 1/2"LINER 1444 3.5 12949' 5715' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): none none 3.5 L-80 11511 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER 2RH LINER TOP PACKER , MD=11504 TVD=5203 LANDING NIPPLE-CAMCO DS NIPPLE ' MD=508 TVD=508 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch r Exploratory fl Stratigraphic Development r Service IV ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/11/2015 OIL r WINJ r WDSPL Suspended r 16.Verbal Approval: Date: GAS '°"" WAG I7 r GSTOR fl SPLUG Commission Representative: GINJ r Op Shutdown `"' Abandoned 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson.M.WieseAconocophillips.com Printed Name Tyson Wiese Title: Sr. Wells Engineer (( — �, G Signature Phone:263-4250 Date b 1- ^-'015 Commission Use Only Sundry Number:2 / Conditions of approval: Notify Commission so that a representative may witness 315— 7'-7 Plug Integrity r BOP Test fl Mechanical Integrity Test fl Location Clearance fl Other: Spacing Exception Required? Yes ❑ No I Subsequent Form Required: /O — 46' 4- APPROVED BY Approved by: Wf7 7 COMMISSIONER THE COMMISSION Date: i pproved application Is valid for 12 months trom the date of approval. Submit Form and Form 10-403 Revised 5/2015 ORIGINAL TI �I �'s Attachments in Duplicate 1- V 6,/41 i5 RBDMS3- JUN 1 0 2015 • S 2N-312 Bermuda Injection Well Perforating Permit to Drill #: 215-028 2N-312 was recently drilled and completed in June 2015 as a slant injector, to improve Bermuda oil recovery and pattern sweep efficiency. The well will be placed on MWAG injection following the planned perforations detailed below. The objective of this procedure is to perforate the 3 '/2" cemented liner from approx. 12,280-12,550'. Procedure: Slickline: (dummy drift) 1. Prior to Slickline, schedule the BPV to be pulled. 2. RIH with a sample bailer and drift the well to TD, or as deep as possible. 3. RIH with 30' x 2.72" OD dummy gun and drift below the planned perf depth. Drift with 20' assembly if 30' assembly will not drift to requested perf depths. 4. Ensure Tubing and IA are both fluid packed. Pump diesel if needed. 5. Set catcher, Pull SOV from Station #2 @ approx. 11,347' KB. Install DMY. 6. Perform MIT-IA to 2,500 psi. Record Results. RDMO. E-line: (Perforate, SBHP) 1. RIH with perf gun assembly and GR/CCL tools for depth correlation. 2. Perforate the Bermuda Sands underbalanced from 12,280' — 12,500', using 2 '/2" 6 spf 60 deg phase deep penetration guns. 3. Record 30 min SBHP mid-perf © approx. 12,415'. PUH 100' TVD and perform 15 min gradient check. 4. POOH. RDMO. •arn 2N-312 ShangriLa 0 )10V • ', Grass Roots Topset Slant Injector I ... As Run Wellbore Schematic ConocoPhillips eCAMERON 4-14"tree,top joint is 4-14"12.6#IBTM,for tree Brunswick/Tejo 6/2/15 . - .. . Conductor: . • 16"62.6#H-40 , . 3 1/4"Camco . . DS Nipple 2.875" Drillplex Spud I = 507'MD/ ii WTI—DDV Hydrualic Control Line . . iH Mud 9.6 PPG :, ... 13-1/2"Surface Hole 3/ Camco KBMG 31/2"X 1"@ 2918MD/2501'TVD w/dummy m WTI—Downhole Deployment Valve 0--2600'MD j6.6"drift) i 1 Surface Casing: Il 10-3/4"45.5#L-80 Hydril 563 4011KFMD/AMP'TVD @ 60° Campanian Top 3,057'MD(2,566'TVD 73/1A / 2 115) VD ) Tubing: 3-1/2"9.3#L-80 EUE8RD LSND 9.6 PPG \ TOC 15.8 ppg @+/-8,100'MD Keep up with Dilution C-37 Top 8,694'MD (4340'-ND) • 9-7/8" Intermediate Hole 3'A"Camco KBMG 31/2"X 1"@ eti 11347'MD/5151'TVD w/SOV annulus to tubing shear ill @3'A"Baker68,_ry "1B4ake r CMU51S1idingDSleeve 2.812"Camco DS Profile 3'A"Camco D Nipple 2.75" 11111.21i 7-5/8",ZXP Liner Top Packer 11504'MD/5199'TVD (72 deg)@ 11461'MD/5185' 111 ..— 7-5/8"x 3-'A"Baker Flex Lock Liner hanger w/RS Nipple, 11524'MD/ TVD 174"7''':jlim' 5205'TVD iliT:=Z-, 4"ID Seal Bore Extension Intermediate Casing Topset: .:: 7-5/8"29.7#L-80 HYD563 11,241' MD/5,118'TVD @ To.of Bermuda 12 251'MD 5 427'TVD 72° LSND ....''...' :ig.agiYMMWi*H] ifiii:i: 39#tail f/11241'MD to 11677'MD (better for 6.5"bit drill :: i]i:i:]iiiiii::iii:ii:iii]ii : ii 10.2+PPG iiiiMHHH :::: •:::' .................. . . :::-:-:-:•:-:-:-:-:::::,::::,:•: •:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•:•.; _.....w!....i..:71-::mp:::::::::::::::::::::iiiiiii:imiiiiiioiiiiiiiiHy . • Bermuda Pore Pressure iii;iH :1111111 ill..._'IMH 6-1/2"Production Hole 8.1 - 10.2 - 11.97 ppg ".•• " .i,i.:::i:::::::: " ""•-— "----------- ••••-•••-••••••••••••••••••••••••••••—•-• •• ..............................................................................:.....:........................... „ . .. .................................... ..... ................. i:i:::,„:,,„„ _...................................................................................................... (25 300 - 2,900 - 3,400 psig) - --•••••••••••• ...•••••.••••.•-•.--- ............... -..••••••.•••••........................ . ........... .................. ....................,.... ..„,......„.. - .--.....•...-;;;.-;;;;;.-......".'2,'.'.'.'.'.'.V.V.',',',', ..:.:........................... ---•••••••••••••••••..••••••••••••••• . ............. ... • • . ..................:,,,,......................,,,,,,...:„.................::„:„,:,,•:. - •...................................................... „„ - -- ----- -- . . ................. ., „ """" " ""-----.......'........."-........-:-.--'-'-'-'-----------'-'-'-'-'-'-'• '--"." • ...................................,..........,.................,.,........ . „ . ....................................... ..... . , • ------- .. . ............... . „ .-•-•---..•---. .. . ............... . ,. ........ ............................ . ., - ..--•-•---....................... .. . . . .............. .... ...........'"' .--."-..................................'............'"'..." .----------- Base Bermuda 12,553'MD 5,527'TVD Cemented Production Liner: 3 1/2"9.3#L-80 Hydril 563 12,950' MD/5,710'TVD @ 54° OF Tyt • c„iP'\\ 1%%i sA THE STATE Alaska Oil and Gas ofLV�,�.._.��� Conservation Commission 1011 � z--=- 333 West Seventh Avenue QTR,, GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F � ALASFax: 907.276.7542 www.aogcc.alaska.gov Graham Alvord Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-312 ConocoPhillips Alaska, Inc. Permit No: 215-028 revised Surface Location: 36.89' FNL, 631.89' FEL, SEC. 3, T9N, R7E, UM Bottomhole Location: 2608.48' FNL, 4712.63' FEL, SEC. 25, T1ON, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced service well. This permit supersedes and replaces the permit previously issued for this well dated March 23, 2015. Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the AOGCC reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the AOGCC specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or an AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P oerster ecray Chair DATED this of May, 2015. • RECEIVED STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIASON MAY 0 4 2015 PERMIT TO DRILL �OG�� 20 AAC 25.005 la.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service- Winj ❑ Single Zone Q • lc.Specify if well is proposed for: Drill Q Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redril❑ Reentry ❑ Exploratory ❑ Service- WAG ❑✓ • Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q Single Well ❑ 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 KRU 2N-312 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13063.32' • TVD: 5773.5 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Field Surface: 36.89'FNL,631.89'FEL,Sec3,T9N,R7E,UM ' ADL380053,390982,375074 ' Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 3,216.94'FNL,5,117.6'FEL,Sec 25,T1ON,R7E 4602 4/10/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2608.48'FNL,4712.63'FEL,Sec 25,T1ON,R7E,UM - •7680 2608.5'from ADL380051 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:159.5' feet • 15.Distance to Nearest Well Open Surface: x-460,961.24' y- 5,911,970.2' Zone-4 • GL Elevation above MSL:120.0' feet to Same Pool: 1030't02L-328wp8 16.Deviated wells: Kickoff depth: 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 72.2 degrees Downhole: 3400 - Surface: 2857. 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 16" 62.6 H-40 Welded 92' Surf Surf 120' 120' 13.5" 10.75" 45.5 L-80 HYD563 2765' Surf Surf 2791' 2440' 1276 sx to surface 9.875" 7.625" 29.7 L-80 HYD563 12090' Surf Surf 12120' 5387.5' 1049 sx to 500 ft above C37 6.5" 3.5" 9.3 L-80 HYD563 1083' -11920 -5326 13063' 5773.5' • 256 sx to liner top 3.5" 9.3 L-80 EUE-8RD 11960' Surf Surf -11920 -5326 N/A tubing 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program ❑✓ Time v.Depth Plot ❑ Shallow Hazard Analysis❑ Diverter Sketch❑✓ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements 21. Verbal Approval: Commission Representative: U ic..---1 eT c> 1 oe PP Ili/15.N %H e M611/ Date ,"- e/- / 3 22. I hereby certify that the foregoing is true and correct. Scott Brunswick 263-4249 Contact scot a.brunswick@cop.com Email Printed Name Graham.Alvord Title Drilling Manager Signature T' L� ��-%t Phone 265-6120 Date -- L/ � 3 Commission Use Only Permit to Drill r API Number: Permit Approval See cover letter for other Number:215-02_5( (ev ecL 50-'tO?j- to 1 O(e- O c -01 V Date: 3/2.3f 2.-c3/ requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: ❑ Other: i30P _re.5 f to 3 5001JS 1 Samples req'd: Yes❑ NoL Mud log req'd:Yes❑'NoE An lel!i.,l Gr r p re-V i'h fc y f2-5 f to Z5-00p5 1112S measures: Yes [v]"' No❑ Directional svy req'd:Yes Elatii No❑ Spacing exception req'd: Yes❑ Nov Inclination-only svy req'd:Yes❑ No V APPROVED BY /J Approved by: COMMISSIONER � THE COMMISSION Date:5--g[ VTL S��`/� � /'� .6-m is- Submit Form and Form 10-401(Revised 10/2012) T r r r Ii 4Ar the from the date of app oval(20 AAC 25.005(g)) Attachments in Duplicate ! • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Tarn Well 2N-312 (Shangrila) g Application for Permit to Drill Document Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(fi 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Requirements of 20 AAC 25.050(b) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 5 Casing and Cementing Program 6 Requirements of 20 AAC 25.005(c)(6) 6 6. Diverter System Information 6 Requirements of 20 AAC 25.005(c)(7) 6 7. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 6 8. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 7 9. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 10. Seabed Condition Analysis 8 Requirements of 20 AAC 25.005(c)(11) 8 11. Evidence of Bonding 8 Requirements of 20 AAC 25.005(c)(12) 8 2N'-312 APD Page 1 of 7 Printed:21-Apr-15 • • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 12. Proposed Drilling Program 8 Requirements of 20 AAC 25.005(c)(13) 8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005(c)(14) 9 14. Attachments 10 Attachment 1 Directional Plan 10 Attachment 2 Drilling Hazards Summary 10 Attachment 3 Well Schematic 10 Attachment 4 Cement Summary 10 2N'-312 APD Page 2 of 7 Printed:21-Apr-15 • S Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 1. Well Name Requirements of 20 AAC 25.005(fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2N-312. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; This well is planned as a slant injector to improve Bermuda oil recovery and pattern sweep efficiency in the 2014/2015 program at Tarn. The Doyon 25 rig will drill a 13-1/2"surface hole and case with 10-3/4"L-80 with premium connections. The 9-7/8"intermediate section will be drilled to+/- 150'MD above the Bermuda sand,and 7-5/8"top-set casing will be run. A 6-1/2"hole into the Bermuda will be drilled. A 3-1/2"production liner will be rung,cemented,&liner top packer set for the lower completion. Finally,a 3-1/2"gaslifted tubing assembly will be run for the upper completion. The liner will be perforated post rig. Location at Surface 36.89'FNL, 631.89'FEL, Sec 3, T9N,R7E,UM NAD 1927 RKB Elevation 159.5'AMSL Northings: 5,911,970.20 Eastings: 460,961.24 Pad Elevation 120.0'AMSL Location at Top of Productive Interval 3,216.94'FNL,5,117.60'FEL,Sec 25,T1ON,R7E,UM (Bermuda) Nad 1927 Measured Depth, RKB: 12,251' Northings: 5,919,320.42 Eastings:467,062.02 Total Vertical Depth,RKB: 5,427.5' Total Vertical Depth, SS: 5,268' Location at Total Depth 2,608.48'FNL, 4,712.62'FEL, Sec 25,T1ON,R7E,UM Nad 1927 Measured Depth, RKB: 13,063.32' Northings: 5,919,927.07 Eastings: 467,469.19 Total Vertical Depth, RKB: 5,773.5' Total Vertical Depth,SS: 5,614' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well: Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records.and show that each named operator has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. 2Ar-312 APD Page 3of7 Printed:21-Apr-15 • S i Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(BOPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: • NOTE:The Doyon 25 5000 psi BOP equipment is adequate.Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) (A) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: The maximum potential surface pressure(MPSP)while drilling 2N-312 is calculated using an estimated reservoir pressure of 3,400 psig(11.97 ppg),a gas gradient of 0.10 psi/ft,and the estimated depth of the Bermuda formation at 5,427'TVD. 1) ASP=[(FG x 0.052)—0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where; FPP=Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. MPSP/MASP calculation ASP=[(FG x 0.052)—0.1]D =[(14.5 x 0.052)—0.1]x 5,427'=3,550 psi OR ASP=FPP—(0.1 xD) =3,400—(0.1 x 5,427')=2,857 psi 7 (B)data on potential gas zones: The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensity for differential sticking; 2N1-312 APD Page 4 of 7 Printed.21-Apr-15 i • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(17; Drill out of surface and intermediate casing shoes and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2N'-312 APD Page 5 of 7 Printed:21-Apr-15 • • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; Casing_and Cementing Program Hole Top(RKB) Btm(RKB) Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 62.5 H-40 Welded 92' Surf 120'/120' Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,765' Surf 2,791'/2,440' 226 Sx 12.0 ppg DeepCRETE&1050 Sx ASL 11.0 ppg DeepCRETE Hydril Cement Top planned @ 8,100'MD/ 7-5/8 9-7/8 29.7 L-80 563 12,090' Surf 11,760"/4,971' 4,159'TVD. Cemented w/ 1049 sx GasBLOK Class"G"© 15.8 ppg Cement Top planned @ 8,100'MD/ TN- Hyd 7-5/8 9-7/8 39 11088 563i1 1,143' 11,760'/4,971 12,120'/5,387' 4,159'TVD. Cemented w/ 1049 sx GasBLOK Class"G"@ 15.8 ppg Cemented to 3 1/2"Liner Top @ 3 1/2" Liner 6-3/4 9.3 L-80 563i1 1083' 11,98075,346' 13,063'/5,773' 11,980'MD Cemented with 234 sx GasBLOK Class"G"© 15.8 ppg Casing/Liner Design: The 85%collapse and burst ratings are listed in the following table: Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 3.5" 9.3 L-80 3 HYD563 10530 psi 8950 psi 10160 psi 8636 psi 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 25. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 120'—2,791' Density(ppg) 8.8—9.8 ' Funnel Viscosity(seconds) 75—250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 2N'-312 APD Page 6 of 7 Printed.21-Apr-15 • s Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Chlorides(mg/l) <1000 Intermediate LSND 2,791'—12,120' Density(ppg) 9.6 • Yield Point(cP) 5-10 Fluid Loss(ml/30min) <6 pH 9.5-9.8 PV 18-21 Production LSND 12,120'—13,063' Density(ppg) 10.2 ' Yield Point(cP) 5-10 HTHP Fluid Loss(ml/30min) <6 pH 9.5-10.0 PV 18-21 Note:Additional weight in mud will be due to solids build up Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water / gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND water-based mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.2 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; N/A-Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 2N'-312 APD Page 7 of 7 Printed:21-Apr-15 • S Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(1 1) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b): N/A-Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005(c)(1 2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025(Bondins]have been met: Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 25 on 2N-312 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface casing point(2,791' MD/2,440'TVD)according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. a. LWD:Gama Ray/Resistivity / 4. Run and cement 10-3/4"45.5#L-80 HYD563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 5. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify AOGCC of BOP test. Record results. 6. Shut in BOP's and pressure test casing to 3500 psi per AOGCC regulations. Record results. 7. Pick up BHA and 9 7/8"bit, RIH 8. Drill out cement and 20'minimum to 50' maximum of new hole. Perform LOT. 9. Directionally drill 9-7/8"hole to+/-12,120' MD/5,387'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. a. LWD:Triple Combo with Gama Ray/Resistivity/Neutron-Density 10. POOH while laying down 5"drill pipe. Run 7-5/8"29.7#L-80 HYD563 w/360ft 39#TN-110SS tail casing to+/- 12,120' MD/5,387'TVD and cement in place bringing cement up to a minimum of 500'MD over the top of the C-37 formation. WTI Downhole deployment valve will be run in the 7-5/8"casing @—2600 ft MD. This valve will be used as a lubricator while constructing the production section of the well. 11. PU 4"drill pipe, BHA and 6 1/2"bit. 12. RIH to 7 5/8"float collar and clean out cement from float collar to shoe 13. Drill an additional 20-50 feet of new hole and perform LOT 14. Drill the 6 1/2"hole to 13,063'MD/5,773'TVD using managed pressure drilling to TD and circulate and condition mud a. LWD:Triple Combo with Gama Ray/Resistivity/Neutron-Density&Sonic for CBL of the 7-5/8"casing 2N'-312 APD Page 8 of 7 Printed:21-Apr-15 • S Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 15. POOH applying pressure with MPD with drill pipe 16. Once BHA is—90 feet above the WTI DDV,close the valve 17. Bleed off the pressure from MPD&perform 30 minute flow check to ensure DDV full closure 18. POOH&L/D BHA 19. RU to run 3%2"liner 20. PU 3%2"liner with a 3'A"X 7 5/8"liner hanger and RIH on 4"drill pipe 21. Once liner shoe is+/-3 stands above the DDV&running on DP,install the MPD RCD 22. Apply pressure gradually to what it was before closure of DDV 23. Open the DDV,&slowly apply MPD back pressure ensuring full opening, RIH slowly across the DDV 24. Run liner to 13,063'MD/5,773'TVD and prepare to cement in place 25. Cement liner in place while reciprocating and rotating,once wiper plug seats pressure up to 2500 psi to set liner hanger 26. Continue to pressure up to 3,000 psi to release running tool from hanger 27. PU and let packer setting dogs drop out,slack off and set down with setting dogs on liner top with 35 K to set ZXP 28. PU with 500 psi on drill pipe until pressure suddenly bleeds off,shut in bag and reverse out any excess cement 29. Swap out drilling fluid to sea water&perform negative pressure test to confirm barriers 30. POOH with running tool while laying down 4"drill pipe 31. Run 3-1/2"completion tubing with a seal assembly and stab into the liner hangers PBR at+/-11,920. a. Four Gas Lift Mandrels b. DS Nipple c. Sliding sleeve d. D Nipple e. Seal Assembly 32. LD DP and associated equipment. 33. ND BOP and rig up tree. Test tree and freeze protect annulus w/Istotherm. Rig down and move out rig. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. Contact Kuparuk Environmental Coordinator for questions regarding waste classification.(659-7212). 2N'-312 APD Page 9 of 7 Printed:21-Apr-15 • r Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2N'-312 APD Page 10of7 Printed:21-Apr-15 • • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Attachment 1 —Directional Plan 2N'-312 APD Page 11 of 7 Printed:21-Apr-15 • S Application for Permit to Drill,Well 2N1-312 Saved:21-Apr-15 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-312 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures,Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump ,/ rates, Mud rheology, LCM. Use GKA LC decision tree. 6-1/2" Hole / 3-1/2" Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure. Use of MPD & Downhole deployment valve. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 2N'-312 APD Page 12 of 7 Printed:21-Apr-15 • • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 2N-312 well plan. Anti-collision analysis indicates the following separation factors between the planned 2N-312 well plan and the following existing wellbores. 2N-310(Separation Factor= 1.547, 7.3' ellipse separation at a depth of 700' MD) 2N-311A(Separation Factor=2.273, 9.01' ellipse separation at a depth of 425' MD) 2N-304 (Separation Factor=2.061, 103.44' center to center at a depth of 4750' MD) Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. Mandatory flow checks will be performed upon penetration and when tripping out of suspected gas or overpressured zones such as the Campanian, Iceberg, and Bermuda intervals. Lower Shale Stability: Unstable shale and ash in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 2N'-312 APD Page 13 of 7 Printed:21-Apr-15 0 0 Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Attachment 3—Proposed Well Schematic Tarn 2N-312 ShangriLa J Grass Roots Topset Slant Irtie,0„, ConocoPhillips Proposed Wel!bore Schematic t,, it 4-1 'tree top Joint is 4-14•12.e4FieThl.tor tree . , erunswict 427;15 _,_ 7.1ft Not Yet Installed Conductor: t,,I 1-' 16'62.6#H-40 ,., 3 W Carnco 03 Ft pple ., 428'11D: itl: Spud 428TVD St,,, -WTI-DDV Hydrualic Control Line rillolex ill d - PPG '1..,. 13-1/;"Surface Hole 2.Y.•Carrico 314"X 1"a :1818'MD I 2500TVD wi dummy 112 -w-rr-Downhole IDeployment Valve @-2680'MD l6.6"drift) — Surface Casino: 10-314"45.5#L-80 1-tydril 563 2,791'MD I 2,440'TVD @ 60° [ ,;:ampaTnan Top 3,057'MD/2.53!:ni0 •• 3 li-Cameo 314'X I`e 1 : f.271'MD I 3500"TVD w:dummy , 1 . s . 1 3'.'Canto:,3'.'X 1'g .0,4 , 't TUbillg: E 722'MD/4350'TVD+xi dummy ',.,-.:: 1461 3-14"9.3#L-80 EU E8R D LSND tigi 9.6 PPG TOC 15.8 pr..g Q+:-.!,'" 0'VD Keep up with It Dilution li C-37 Top 8,084'MD ifi3or,11* , , _ 314'Camco 3W X1'dg ilit t 10520'MD I 4900'TVD siedunany 9-7/8"Intermediate Hole 3..4."Cameo 3W X 1' 1 tots 11793'MD!4528'ND w!SOV i t "annulus to tubing shear i i St 3 W Baker CMU Sliding Sleeve 2.812'Cameo DS Profile rxxxVID I TM 7-418.ZXP Liner Top Packer 11020'MD 3W Cameo DS Nipple 275" 7-518'x 3-'4"Baker Flex Lock Liner hanger vit RS Nipple, 0 xxxxliD t zoo(TVD -,:t-,........-;,..st am`MDI-xxxxlVD \ iSSOM'1'-' 4E)Seal Bore Extension 777 I. i L Intermediate Casing Tooset: 0..... 1 7-5/8"29.7#L-80 HYD563 lit •. ,.` ermuoa 12 251'MD 5 427.-rt.'D li /--12 120'MD/5,:38T TVD @ 72° .. • LSND .. .:::.: 39#tail f/11760 trTD(better for 6.5"bit drill out&liner :::- ::: :-----7, —1;-:-,--;-;:;..—:::. - .;;--:,-..,-.-'• :: ; - Bermuda Pore Pressure ::. :.:.:1__ , .:;::::6_112" 8.1 —10,2—11.97 ppg .. ,;k .. . .. .••-•:.t• ... ... ..... ... .t: ....... ...,.. ... .... .: P1 ,{2 300—2,900— 3,400 psig) ;;: -] i ,, ,, — , , :: „ ,-- . . . . 1 gas*Se-r...:a2,f 53'MD f,f:7'TVC i 1 ' Cemented Production Liner: i 3 112”9.3#L-80 Hydril 563 13,063'MD/5,773'ND @ 54° 2N'-312 APD Page 14 of 7 Printed:21-Apr-15 • • Application for Permit to Drill,Well 2N-312 Saved:21-Apr-15 Attachment 4—Cement Summary 10-3/4" Surface Casing run to 2791' MD/2440' TVD Cement from 2791' MD to 2200' (591' of fill)with 12.0 ppg DeepCRETE, and from 2200'to surface with ASL @ 11.0 ppg DeepCRETE.Assume 250% excess annular volume in permafrost and 50% excess below the permafrost(1134' MD). Lead slurry:(2200- 1134')X 0.3634 ft3/ft X 1.5 (50% excess) = 582 ft3 below permafrost 1134'X 0.3634 ft3/ft X 3.5 (250% excess) = 1443 ft3 above permafrost Total volume= 582 + 1443=2025 ft3=> 1050 Sx @ 1.93 ft3/sk Tail slurry: 591'X 0.3634 ft3/ft X 1.5(50%excess) = 323 ft3 annular volume 80'X 0.5397 ft3/ft=44 ft3 shoe joint volume Total volume= 323 +44 = 367 ft3=>226 Sx @ 1.63 ft3/sk System: 226 Sx 12.0 ppg DeepCRETE & 1050 Sx ASL 11.0 ppg DeepCRETE 7-5/8" Intermediate Casing run to 12114' MD/5387' TVD Cement from 12,114' MD to 8100' MD. A minimum of 500' above C-37 w/Class G @ 15.8 PPG. Assume 40% excess annular volume. Tail Slurry: (12,114'-8,100')X 0.2146 ft3/ft X 1.4 (40% excess) = 1206 ft3 annular vol. 80' x 0.2577 ft3/ft=21 ft3 shoe joint volume Total volume= 21 ft3+ 1206 ft3= 1227 ft3=> 1049 Sx @ 1.17 ft3/sk System: 1049 Sx 15.8 ppg Class G 3-1/2" Liner run to 13063' MD/5773'TVD Cement 3%" liner from shoe @ 13,063' MD to 11,920' MD (+/-200' inside the 7%" casing) with Class G + Additives @ 15.8 PPG. Assume 40% excess in the openhole annular volume, 0% excess inside casing. Cement for liner job is to be batch mixed. 31/2"Cmt: (13,063'-12,120')x 0.1635 ft3/ft x 1.40(40%excess)= 216 ft3 in open hole 200' of volume above liner for contamination, 200 ft x.2302 ft3/ft(0%excess)=46 ft3 Lap: 200' inside 7%" casing x 0.1635 ft3/ft x 1.00(0%excess) =33 ft3 80'shoe track x 0.0449 ft3/ft x 1.0(0% excess)=4 ft3 Total volume=216 ft3+46 ft3+33 ft3+4 ft3=>299 ft3=>256 Sx @ 1.17 ft3/sk System: 256 Sx Class G @ 15.8 PPG 2N'-312 APD Page 15 of 7 Printed:21-Apr-15 • • Loepp, Victoria T (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Friday, May 01, 2015 3:31 PM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]RE: KRU 2N-312 PTD 215-028 Follow Up Flag: Follow up Flag Status: Flagged Just saw this, hope Monday will be ok. I'll surely get the 10-401 I emailed over. The rig at best could be moving to the well Monday from 2L pad over to 2N. I don't expect we spud until mid to late next week. Sent with Good (www.good.com) From: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Sent: Friday, May 01, 2015 5:44:56 PM To: Brunswick, Scott A Subject: [EXTERNAL]RE: KRU 2N-312 PTD 215-028 Scott, Sorry for the delayed response but could you please send over a revised,signed PTD with the changes. Thanx, Victoria From: Brunswick,Scott A[mailto:Scott.A.Brunswick@conocophillips.com] Sent:Tuesday,April 21,2015 8:56 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2N-312 PTD 215-028 Updated procedure&forms, some items to note: 1. Casing&Cement program table has been updated. Will run a 39#heavy tail on the 7-5/8"casing as the drift of the DDV is—6.6",so will drill production with a 6.5" bit, &drift of that tail will match the 6.5" bit to avoid leaving a ring of shoe. 2. Section 12: Procedure has been updated to reflect use of DDV& MPD 3. Attachment 3 has been update to reflect DDV& Hole size 4. Attachment 4 has been updated to reflect 3-1/2" liner cement volumes for change in hole size &39#7-5/8 casing tail. I updated what I could on the 10-401 just in case, problem is,there is no more space to include the 39#casing tail in the 7-5/8" and I don't think the AOGCC wants me changing the form. 1 • If you need hard copies of these with signatures, I can send them over. From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday,April 21, 2015 8:13 AM To: Brunswick,Scott A Subject: [EXTERNAL]RE: KRU 2N-312 PTD 215-028 Scott, A bond log for the 3-1/2" cemented liner is not required at this time. Please review the 7-5/8" bond log with the AOGCC as soon as it is obtained. Use of the downhole deployment valve is approved. Please update your approved PTD with this change and I will make the change in our well file. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil &Gas Conservation Commission 333 W. 7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@alaska.gov<mailto:Victoria.Loepp@alaska.gov> CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it,and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at(907)793- 1247 or Victoria.Loepp@alaska.gov<mailto:Victoria.Loepp@alaska.gov> From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Monday,April 20, 2015 4:23 PM To: Loepp,Victoria T(DOA) Subject: KRU 2N-312 PTD 215-028 Victoria I wanted to double check on the cement bond log plans for the KRU 2N-312 well. It is an injector. The PTD had planned to run a LWD sonic CBL on the 7-5/8" intermediate casing. I had not included an bond log of the 3-1/2" cemented liner, as the more important cement job is the 7-5/8" as it extends above the top of the pool being @ least 500 feet above the top of the C-37 sand. 2 f • Is this a correct conclusion,or does • 3-1/2" liner also need to have a bond Iog run? I've attached an updated schematic for a refresher of what the well will look like upon completion. Another item we have added since the permit was submitted is the downhole deployment valve we will run in the 7- 5/8" casing. It will act as a lubricator for tripping the BHA& running the liner. What type of information may I provide for this change to the program/design? Thank you Scott 3 • • TRANSMITTAL LETTER CHECKLIST WELL NAME: kali. Q.11) -30, PTD: Development /Service Exploratory Stratigraphic Test Non-Conventional FIELD: AlApamttAi< ICI Vkir POOL: KcvI< x,,‘,/kr // .S n b r ) Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are also required for this well: Well Logging Requirements /Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 AAC 25.071, V composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 2/2015 +i i 00 ii , , ; e, €' E �, a , ; ; o ; , ; ; o c 0. 13 o 4 CC 1N 4 O , ; , . o' oN a a o 1- E O c) O. c' , y, o; a o' 3' o' ai o. 0 ca �; c a; o Q. d, '� 3'. , , ;. � ' a _ U. m T c 3. o, i �'� a3,v o a a�E.y , a coa iri p U ` U °0. 7 a °0' y. W o J Z a n t aa)i, 'm, rn or c�' �' pi . > Z �. �, U d N. ..... Mme, ll: 6...: cOAI o N. V' 3 , w. , r. cd 0, a 0 , �. co, -L-, U. . •p, N > b Q, , 0: p Ty O. yN. 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O, O t, al co, m, al, o, 0 - z, a -J D, 5, 5 5 U) - o, o a a' U, 5, Q, a, U co 0, U, U U, a, ' a, = o CO, CO, 0, 5,, N' � d 0 CO, u) 0 �4 I2 - - N M a l0 co n 00 O ,- N M '� b CO N N N N N N C0 dr 0 N N N N OM M M M M M OO') CO M M 0 U U> U Lo N �Cillj o O w O w O 0 o Ct^ N o O al 0 r 0 O O y F- L :. Lco La Ln 'E 0 0. cO w a5N u) N >, Ur E J, C ala a a .0 a > 0 Qa 0a W 0 p ✓D 215 —oz-E( • • Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Friday, May 01, 2015 9:45 AM To: 'Brunswick, Scott A' Subject: RE: KRU 2N-312 PTD 215-028 Follow Up Flag: Follow up Flag Status: Completed Scott, Sorry for the delayed response but could you please send over a revised, signed PTD with the changes. Thanx, Victoria From: Brunswick, Scott A [mailto:Scott.A.Brunswick@ conocophillips.com] Sent: Tuesday, April 21, 2015 8:56 AM To: Loepp, Victoria T(DOA) Subject: RE: KRU 2N-312 PTD 215-028 Updated procedure&forms, some items to note: 1. Casing&Cement program table has been updated. Will run a 39# heavy tail on the 7-5/8" casing as the drift of the DDV is–6.6", so will drill production with a 6.5" bit, & drift of that tail will match the 6.5" bit to avoid leaving a ring of shoe. 2. Section 12: Procedure has been updated to reflect use of DDV& MPD 3. Attachment 3 has been update to reflect DDV& Hole size 4. Attachment 4 has been updated to reflect 3-1/2" liner cement volumes for change in hole size & 39#7-5/8 casing tail. I updated what I could on the 10-401 just in case, problem is,there is no more space to include the 39#casing tail in the 7-5/8" and I don't think the AOGCC wants me changing the form. If you need hard copies of these with signatures, I can send them over. From: Loepp, Victoria T(DOA) [mailto:victoria.loepp(aalaska.gov] Sent:Tuesday, April 21, 2015 8:13 AM To: Brunswick, Scott A Subject: [EXTERNAL]RE: KRU 2N-312 PTD 215-028 Scott, A bond log for the 3-1/2" cemented liner is not required at this time. Please review the 7-5/8" bond log with the AOGCC as soon as it is obtained. Use of the downhole deployment valve is approved. Please update your approved PTD with this change and I will make the change in our well file. Thanx, 1 J ► • Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(cilalaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Laepp@alaska.gov From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.conn] Sent: Monday, April 20, 2015 4:23 PM To: Loepp, Victoria T(DOA) Subject: KRU 2N-312 PTD 215-028 Victoria I wanted to double check on the cement bond log plans for the KRU 2N-312 well. It is an injector. The PTD had planned to run a LWD sonic CBL on the 7-5/8" intermediate casing. I had not included an bond log of the 3-1/2"cemented liner,as the more important cement job is the 7-5/8" as it extends above the top of the pool being @ least 500 feet above the top of the C-37 sand. Is this a correct conclusion,or does the 3-1/2" liner also need to have a bond log run? I've attached an updated schematic for a refresher of what the well will look like upon completion. Another item we have added since the permit was submitted is the downhole deployment valve we will run in the 7- 5/8"casing. It will act as a lubricator for tripping the BHA& running the liner. What type of information may I provide for this change to the program/design? Thank you Scott 2 Pi0 z /5--020- 41 es—ozg- Loepp, Victoria T (DOA) From: Loepp,Victoria T (DOA) Sent: Tuesday,April 21, 2015 8:13 AM To: 'Brunswick, Scott A' Subject: RE: KRU 2N-312 PTD 215-028 Follow Up Flag: Follow up Flag Status: Completed Scott, A bond log for the 3-1/2"cemented liner is not required at this time. Please review the 7-5/8" bond log with the AOGCC as soon as it is obtained. Use of the downhole deployment valve is approved. Please update your approved PTD with this change and I will make the change in our well file. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(o,alaska.t ov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepp@alaska.gov From: Brunswick, Scott A [mailto:Scott.A.Brunswick(aconocophillips.com] Sent: Monday, April 20, 2015 4:23 PM To: Loepp, Victoria T(DOA) Subject: KRU 2N-312 PTD 215-028 Victoria I wanted to double check on the cement bond log plans for the KRU 2N-312 well. It is an injector. The PTD had planned to run a LWD sonic CBL on the 7-5/8" intermediate casing. I had not included an bond log of the 3-1/2" cemented liner, as the more important cement job is the 7-5/8" as it extends above the top of the pool being @ least 500 feet above the top of the C-37 sand. Is this a correct conclusion,or does the 3-1/2" liner also need to have a bond log run? 1 • I've attached an updated schematic for a refresher of what the well will look like upon completion. Another item we have added since the permit was submitted is the downhole deployment valve we will run in the 7- 5/8" casing. It will act as a lubricator for tripping the BHA& running the liner. What type of information may I provide for this change to the program/design? Thank you Scott 2 • a,Or T,, w s THE STATE Alaska Oil and Gas ���'���i OfA T c T A Conservation Commission itith RECEIVED STATE OF ALASKA ''r ALA OIL AND GAS CONSERVATION cowl" FEB 13 2015 PERMIT TO DRILL ,221 AAC 25.005 AOGGC- 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ' Service- Winj ❑ Single Zone ❑✓ . lc.Specify if well is proposed for: Drill 0 Lateral ❑ Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zone ❑ Coalbed Gas ❑ Gas Hydrates ❑ Redrill❑ Reentry ❑ Exploratory ❑ Service- WAG Q Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: Blanket Q . Single Well ❑ 11.YVicell Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 ` 2N-3312 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 13063.32' ' TVD: • 5773.5 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Kuparuk River Field. Surface: 36.89'FNL,631.89'FEL,Sec3,T9N,R7E,UM • ADL380053 .5909 v, 37-50-1 Tarn Oil Pool Top of Productive Horizon: 8.Land Use Permit: i 13.Approximate Spud Date: 3,216.94'FNL,5,117.6'FEL,Sec 25,T10N,R7E 4602 4/10/2015 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 2608.48'FNL,4712.63'FEL,Sec 25,T1 ON,R7E,UM • •7(2. 2560.2608.5'from ADL380051 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:159.5' feet ‘ 15.Distance to Nearest Well Open Surface: x-460,961.24' y- 5,911,970.2' Zone-4 . GL Elevation above MSL:120.0' feet , to Same Pool: 1030'to2L-328wp8 16.Deviated wells: Kickoff depth: . 300 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: . 72.2 degrees Downhole: 3400 , Surface: 2857 • 18.Casing Program: Specifications Top - Setting Depth - Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 24" 1,if 62.6 H-40 Welded 92' Surf Surf 120' 120' 13.5" 10.75" 45.5 L-80 HYD563 2765' Surf Surf 2791' 2440' 1276 sx to surface 9.875" 7.625" 29.7 L-80 HYD563 12090' Surf Surf 12120' 5387.5' 1049 sx to 500 ft above C37 6.75" 3.5" 9.3 L-80 HYD563 1083' -11980 -5346 13063' 5773.5' 234 sx to liner top 3.5" 9.3 L-80 EUE-8RD 11960' Surf Surf -11980 -5346 N/A tubing 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured): Effect.Depth MD(ft): Effect.Depth TVD(ft): Junk(measured): Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 20. Attachments: Property Plat ❑ BOP Sketch❑ Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis Diverter Sketch 0 Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.0500requirements0 21. Verbal Approval: Commission Representative: Date i 2 - /5 22. I hereby certify that the foregoing is true and correct. Scott Brunswick 263-4249 Contact scott.a.brunswick(a cop.com Email Printed Name Graham/ .Alvord Title Drilling Manager Signature /4 L._ak- Phone 265-6120 Date 2-k i 2- ( Zo'c- ' Commission Use Only Permit to Drill API Number: Permit Approval See cover letter for other Number: cz)5 - p�� 50-103"-0/O (o-GO _0 C. Date: 3l 3, 1 requirements. Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane gas hydrates,or gas contained in shales: EY Other: cop to s f fa 5D O p s )- Samples req'd: Yes❑ No[ Mud log req'd:Yes❑ No 4ez h v/et r- p re ire h fly 71r5 f to 2.5-0 Ifi pS/ H2S measures: Yes Ile No❑ Directional svy req'd:Yes121/No❑ Spacing exception req'd: Yes ❑ No[ . Inclination-only svy req'd:Yes❑ No +[g APPROVED BY _ _ Approved by: - / �9i2ZCMY"'�- COMMISSIONER THE COMMISSION Date:3.23-l5 /� AA ,, f� � .2j I o i i Submit Form and Form 10-401(Revised 10/2012) This permit is li R2(retis�t�drr eldate of approval(20 AAC 25.05(g)) Attachments in Duplicate li'TL. 3//,3 0/� ����JJJJ 1YYYVY/I////��l�iii� {6..� AG F/l✓ -' • •ation for Permit to Drill,Well 2N-312 Saved 12-Feb-15 Tarn Well 2N-312 (Shangrila) ,. Application for Permit to Drill Document ConocoPhillips Table of Contents 1. Well Name 3 Requirements of 20 AAC 25.005(f) 3 2. Location Summary 3 Requirements of 20 AAC 25.005(c)(2) 3 Requirements of 20 AAC 25.050(6) 3 3. Blowout Prevention Equipment Information 4 Requirements of 20 AAC 25.005(c)(3) 4 4. Drilling Hazards Information 4 Requirements of 20 AAC 25.005(c)(4) 4 ASP CALCULATIONS 4 5. Procedure for Conducting Formation Integrity Tests 5 Requirements of 20 AAC 25.005(c)(5) 5 Casing and Cementing Program 6 Requirements of 20 AAC 25.005(c)(6) 6 6. Diverter System Information 6 Requirements of 20 AAC 25.005(c)(7) 6 7. Drilling Fluid Program 6 Requirements of 20 AAC 25.005(c)(8) 6 8. Abnormally Pressured Formation Information 7 Requirements of 20 AAC 25.005(c)(9) 7 9. Seismic Analysis 7 Requirements of 20 AAC 25.005(c)(10) 7 10. Seabed Condition Analysis 7 Requirements of 20 AAC 25.005(c)(11) 7 11. Evidence of Bonding 8 Requirements of 20 AAC 25.005(c)(12) 8 PER E ED 2N'-312 APD Page 1 of 7 __ Printed:12-Feb-15 •ation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 12. Proposed Drilling Program 8 Requirements of 20 AAC 25.005(c)(13) 8 13. Discussion of Mud and Cuttings Disposal and Annular Disposal 9 Requirements of 20 AAC 25.005(c)(14) 9 14. Attachments 9 Attachment 1 Directional Plan 9 Attachment 2 Drilling Hazards Summary 9 Attachment 3 Well Schematic 9 Attachment 4 Cement Summary 9 RS Et) D 2N'-392 APD Page 2 of 7 Printed:12-Feb-15 ORIGINAL • •ation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 1. Well Name Requirements of 20 AAC 25.005(fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b).For a well with multiple well branches,each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this application is submitted will be designated as 2N-312. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identf'ing the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth; This well is planned as a slant injector to improve Bermuda oil recovery and pattern sweep efficiency in the 2014/2015 program at Tarn. The Doyon 25 rig will drill a 13-1/2"surface hole and case with 10-3/4"L-80 with premium connections. The 9-7/8"intermediate section will be drilled to+/- 150'MD above the Bermuda sand,and 7-5/8"top-set casing will be run. A 6-1/2"hole into the Bermuda will be drilled. A 3-1/2"production liner will be rung,cemented,&liner top packer set for the lower completion. Finally,a 3-1/2"gaslifted tubing assembly will be run for the upper completion. The liner will be perforated post rig. Location at Surface 36.89'FNL, 631.89'FEL, Sec 3, T9N,R7E,UM' NAD 1927 RKB Elevation 159.5'AMSL Northings: 5,911,970.20 Eastings: 460,961.24 Pad Elevation 120.0'AMSL Location at Top of Productive Interval 3,216.94'FNL,5,117.60'FEL,Sec 25,T10N,R7E,UM (Bermuda) Nad 1927 Measured Depth, RKB: 12,251' Northings: 5,919,320.42 Eastings:467,062.02 Total Vertical Depth, RKB: 5,427.5' Total Vertical Depth, SS: 5,268' Location at Total Depth 2,608.48'FNL, 4,712.62'FEL, Sec 25,T10N,R7E,UM Nad 1927 Measured Depth,RKB: 13,063.32' Northings: 5,919,927.07 Eastings: 467,469.19 Total Vertical Depth,RKB: 5,773.5' Total Vertical Depth, SS: 5,614' and (D)other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must 0)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named operator has been furnished a copy of the application by certified mail;or (8)state that the applicant is the only affected owner. The Applicant is the only affected owner. 2N'-312 APD Page 3 of 7 OR I G I NA L Printed: 12-Feb-15 • ation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (3)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25.036,or 20 AAC 25.037, as applicable; Please reference BOP schematics on file for Doyon 25. 4. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (4)information on drilling hazards,including (A)the maximum downhole pressure that may,be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient; The following presents data used for calculation of anticipated surface pressure(ASP)during drilling of this well: • NOTE:The Doyon 25 5000 psi BOP equipment is adequate.Test BOP to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE(ASP) (A) ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing seat with a gas gradient to the surface,or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: The maximum potential surface pressure(MPSP)while drilling 2N-312 is calculated using an estimated reservoir pressure of 3,400 psig(11.97 ppg),a gas gradient of 0.10 psi/ft,and the estimated depth of the Bermuda formation at 5,427'TVI3. 1) ASP=[(FG x 0.052)—0.1]D Where: ASP=Anticipated Surface pressure in psi FG=Fracture gradient at the casing seat in lb/gal 0.052=Conversion from lb./gal to psi/ft 0.1 =Gas gradient in psi/ft D=true Vertical depth of casing seat in ft RKB OR 2) ASP=FPP—(0.1 x D) Where; FPP=Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. MPSP/MASP calculation ASP=[(FG x 0.052)—0.1]D =[(14.5 x 0.052)—0.1]x 5,427'=3,550 psi OR ASP=FPP—(0.1 x D) =3,400—(0.1 x 5,427')=2,857 psi ✓ (B)data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C)data concerning potential causes of hole problems such as abnormally geo-pressured strata,lost circulation zones,and zones that have a propensityfor differential sticking; SUES _-; 2N'-312 APD Page 4 of 7 Printed: 12-Feb-15 • .•tion for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 Please see Attachment 2-Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,as required under 20 AAC 25.030(; Drill out of surface and intermediate casing shoes and perform LOT test or FIT in accordance with the Kuparuk LOT/FIT procedure that ConocoPhillips Alaska has on file with the Commission. 2N'-312 APD Page 5 of 7 J R I G I N A L Printed:12-Feb-15 • • Illation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (6)a complete proposed casing and cementing program as required by 20 AAC 25.030,and a description of any slotted liner,pre perforated liner,or screen to be installed; Casing and Cementing Program Hole Top(RKB) Btm(RKB) Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program Driven 16 24 62.6 H-40 Welded 92' Surf 120'/120' Hydril Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 563 2,765' Surf 2,791'/2,440' 226 Sx 12.0 ppg DeepCRETE&1050 Sx ASL 11.0 ppg DeepCRETE Hydril Cement Top planned @ 8,100'MD/ 7-5/8 9-7/8 29.7 L-80 563 12,090' Surf 12,120"/5,387' 4,159'TVD. Cemented w/ 1049 sx GasBLOK Class"G"@ 15.8 ppg 3 /z" H dril Cemented to 3'/2"Liner Top @ Liner 6-3/4 9.3 L-80 563 1083' 11,98075,346' 13,06375,773' 11,980'MD Cemented with 234 sx GasBLOK Class"G"@ 15.8 ppg Casing/Liner Design: The 85%collapse and burst ratings are listed in the following table: Wt Connection 85%of 85%of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 10-3/4" 45.5 L-80 3 Hyd563 2,480 psi 2,108 psi 5,210 psi 4,429 psi 7-5/8" 29.7 L-80 3 Hyd563 4,790 psi 4,072 psi 6,890 psi 5,857 psi 3.5" 9.3 L-80 3 HYD563 10530 psi 8950 psi 10160 psi 8636 psi 6. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (7)a diagram and description of the diverter system as required by 20 AAC 25.035,unless this requirement is waived by the commission under 20AAC 25.035(h)(2); Please reference diverter schematic on file for Doyon 25. 7. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (8)a drillingfluid program,including a diagram and description of the drilling fluid system,as required by 20 AAC 25.033; Drilling will be done using mud systems having the following properties: Surface WBM 120'-2,791' Density(ppg) 8.8—9.8 Funnel Viscosity(seconds) 75—250 Yield Point(cP) 60—80 pH 9.0—9.5 API Filtrate(cc) NC—8.0 Chlorides(mg/1) <1000 Intermediate LSND 2,791'—12,120' 21T-312 APD Page 6 of 7 3RIGINAL Printed:12-Feb-15 • illation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 Density(ppg) 9.6 Yield Point(cP) 5-10 Fluid Loss(ml/30min) <6 pH 9.5-9.8 PV 18-21 Production LSND 12,114'—13,063' Density(ppg) 10.2-12.0 Yield Point(cP) 5-10 HTHP Fluid Loss(ml/30min) <6 pH 9.5-10.0 PV 18-21 Note:Additional weight in mud will be due to solids build up Surface Hole Section: Fresh water spud mud system. Standard high viscosity fresh water/ gel spud mud will be used for the surface interval. Viscosity will be reduced prior to cementing. Maintain mud weight between 9.6 - 10.0 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: LSND water-based mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity through the sticky upper clays. There is potential for lost circulation, particularly after the Campanian and Iceberg zones are penetrated. Maintain mud weight at or above 9.6 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required)will all be important in maintaining wellbore stability. Production Hole Section: LSND water-based mud system. Ensure good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is potential for lost circulation in the target Bermuda reservoir. Maintain minimum mud weight of at least 10.2 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Doyon 25 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 8. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (9)for an exploratory or stratigraphic test well,a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.0330; N/A-Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005(00 0) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (10)for an exploratory or stratigraphic test well,a seismic refraction or reflection analysis as required by 20 AAC 25.061(a); N/A-Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (11)for a well drilled from an offshore platform,mobile bottom founded structure,jack-up rig,or floating drilling vessel,an analysis of seabed conditions as required by 20 AAC 25.061(b); 2N'-312 APD Page 7 of 7 Printed: 12-Feb-15 ORIGINAL 4111 Asation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 N/A-Application is not for an offshore well. 11. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (12)evidence showing that the requirements of 20 AAC 25.025{Bonding)have been met; Evidence of bonding for ConocoPhillips Alaska,Inc.is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: The proposed drilling program is listed below. Please refer to Attachment 3:Well Schematic. 1. MIRU Doyon 25 on 2N-312 Conductor. 2. NU and function test diverter system and prepare spud mud. 3. Spud and directionally drill 13-1/2"hole to the 10-3/4"surface casing point(2,791'MD/2,440' TVD) according to the directional plan. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. a. LWD:Gama Ray/Resistivity 'l 4. Run and cement 10-3/4"45.5#L-80 HYD563 casing to surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 5. Nipple down diverter and install wellhead and test to 5000 psi. Nipple up BOPE and test to 3,500 psi. Notify ✓ AOGCC of BOP test. Record results. 6. Shut in BOP's and pressure test casing to 3500 psi per AOGCC regulations. Record results. 7. Pick up BHA and 9 7/8"bit,RIH 8. Drill out cement and 20'minimum to 50'maximum of new hole.Perform LOT. 9. Directionally drill 9-7/8"hole to+/-12,120'MD/5,387'TVD. Run MWD/LWD logging tools in drill string as required for directional monitoring and formation data gathering. a. LWD: Triple Combo with Gama Ray/Resistivity/Neutron-Density 10. POOH while laying down 5"drill pipe. Run 7-5/8"29.7#L-80 HYD563 casing to+/-12,120'MD/5,387' TVD and cement in place bringing cement up to a minimum of 500'MD over the top of the C-37 formation. 11. PU 4"drill pipe,BHA and 6 3/4"bit 12. RIH to 7 5/8"float collar and clean out cement from float collar to shoe 13. Drill an additional 20-50 feet of new hole and perform LOT 14. Drill the 6 3/4"hole to 13,063'MD/5,773'TVD and circulate and condition mud a. LWD:Triple Combo with Gama Ray/Resistivity/Neutron-Density& Sonic for CBL 15. POOH with drill pipe and RU to run 3 %"liner 16. PU 3 '/"liner with a 3 '/2"X 7 5/8"liner hanger and RIH on 4"drill pipe 17. Run liner to 13,063'MD/5,773'TVD and prepare to cement in place 18. Cement liner in place while reciprocating and rotating,once wiper plug seats pressure up to 2500 psi to set liner hanger 19. Continue to pressure up to 3,000 psi to release running tool from hanger 2N'-312 APD Page 8 of 7 Printed:12-Feb-15 ORIGINAL • 4bation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 20. PU and let packer setting dogs drop out,slack off and set down with setting dogs on liner top with 35 K to set ZXP 21. PU with 500 psi on drill pipe until pressure suddenly bleeds off,shut in bag and reverse out any excess cement 22. POOH with running tool while laying down 4"drill pipe 23. Run 3-1/2"completion tubing with a seal assembly and stab into the liner hangers PBR at+/-11,980. a. Four Gas Lift Mandrels b. DS Nipple c. Sliding sleeve d. D Nipple e. Seal Assembly 24. LD DP and associated equipment. 25. ND BOP and rig up tree. Test tree and freeze protect annulus. Rig down and move out rig. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorLation under 20 AAC 25.080 for an annular disposal operation in the well.; • All solid waste will be transported to the grind and inject facility at DS-4 Prudhoe Bay for disposal. • Incidental fluids generated from drilling operations will be injected in a Kuparuk Class II disposal well (1R-18 or DS 1B disposal facilities)or Prudhoe DS-4 if a Kuparuk facility is unavailable. • All wastes and waste fluids hauled from the pad must be properly documented and manifested. Contact Kuparuk Environmental Coordinator for questions regarding waste classification.(659-7212). 14.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Summary 2N'-312 APD Page9of7 Printed:12-Feb-15 OIGINAL illation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 Attachment 1 —Directional Plan 2N'-312 APD Page 10 of 7 Printed:12-Feb-15 ORIGINAL I S 1051 FcbmxyOr?201.Z 2N-312wp04. 1 Permit Pack I Plan Summary - BASE_BERM_SEIS TOP_BERM_SE S U z,5- Cu8011P SST BASE BERMTOPIPURPLE-5 d ''. C-35 I I ..,... _-... -PFROST t\ I 1st Iceberg anomaly '`` . 1 BASE_.URPLE - I ` d Leber anomaly 'tom \ 4. ��oo ' o - ---- 1.. w1. ' �:s \ n T-7, T 4. P,�"'E`Rk 5000 ... 1 ww 1 C 4 I .\ 1 li �� 'tl w 1Y\t - � \ 0 , 1 I 13000 i 1 f 16000 I ` I 1 y' ' 0 •\��\. �6 Xaz 9000 lz000 31/2"1x6-1/2' 1500 C ^�\��; 10.3/4"x 13-1/2�' Measured Depth 7-5/8"x 9-7/8'I ; �A o, -�16"x 421 Geodetic Datum: North American Datum 1983 \\�� -� Depth Reference Plan 39.5+120 @ 159.SOusft(Doyon 25) � WO Rig: Doyon 25 0000 _ 2 110.3/4"x 13-1/2�' ...........s,....,.. ....- 0 0 ���0. o o -l 0000 0o h 6 o O O O 17-518"x 9-7/8'� I3 1/2"x 6-1/2' -'10600 i L. b __ ^p ^ I Oi o ` O '� . o 1 ®®� -2500 1 I\ 0 • --,-_ - ._ 40 ^^250 1 I I 1..__ I I I 1 I 1 I I 1 1 I 0 1500 3000 4500 6000 7500 9000 10500 250 -440 Horizontal Departure �"'''"'P - .4... +ce 440 -640 ° 330 i o t.`(,1 RM 640 - 830 it MAE • s1!\V�� , s 830 -1020 o �i l v fieIfi , * _'w s w' iv 1020 - 1220 60 1 1 300 1 (�A �� ‘^ E1 1220 - 1410 co a i�l� h�I?'M. s 1410 - 1600 CO ._ _.. __ 4 t e S: , 600-2080 r• T t II I i t.1.1."0.1.1N L !-e' _ / w.. 2080 2550 �e I i 00-e ai _ i �iwii 2550 -3030 U 30 �E�I:' I ( ii fiv1�. %,.":.c ��;il!80 3030 -3500 • ��_'. ...-__ .. 270 r/,r✓ I4 r wlo ''• 1 3500 3980 50 m i I I - 4450- 4930 U ' . - 0 4930 -5400 5400 - 6360 0 2000 4000 6000 8000 10000 240 .. 120 6360 -7320 SURVEY PROGRAM 7320 - 8270 Surface Location 8270 - 9230 Depth From Depth To Survey/Plan Tool --" 9230 - 10190 39.50 1000.00 2N-312wp04.1(Plan:2N-312) GYD-GC-SS 210 --- _ 159 1000.00 2000.00 2N-312wp04.1(Plan:2N-312) MWD Pad Elevation: 120.00 �2� 10190 11150 1000.00 2791.25 2N-312wp04.1(Plan:2N-312) MWD+IFR-AK-CAZ-SC 180 11150 --- 12110 2791.25 4291.25 2N-312wp04.1 Plan:2N-312 MWD CASING DETAILS 12110 - 13063 2791.25 12120.17 2N-312wp04.1 Plan:2N-312 MWD+IFR-AK-CAZ-SC 12120.17 13063.32 2N-312wp04.1(Plan:2N-312 MWD TVD MD Name M 120.00 120.00 16"X 42" Magnetic Model: BGGM2014 T 2440.20 2791.25 10-3/4"X 13-1/2" Magnetic Model Date: 12-Feb-15 - 5387.50 12120.17 7-5/8"X 9-7/8" Magnetic Declination: 18.71° 5773.50 13063.32 3 1/2"X 6-1/2" To convert a Magnetic Direction toe True Direction,Add 18.71°East SECTION DETAILS -1122.1 Sec MD Inc Azi TVD +N/S +E/-W Dleg TFace VSect Target Annotation 1 39.50 0.00 0.00 39.50 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 KOP:Start 1.5°/100'DLS,135°TF,for 300' 3 600.00 4.50 135.00 599.69 -8.33 8.33 1.50 135.00 -1.23 Start 2.5°/100'DLS,0°TF,for 481.26' 4 1081.26 16.53 135.00 1072.00 -70.32 70.32 2.50 0.00 -10.39 Hold for 104.31' PFROST 5 1185.57 16.53 135.00 1172.00 -91.31 91.31 0.00 0.00 -13.50 Start 3.5°/100'DLS,-80°TF,for 1605.68' 6 2791.25 60.51 64.92 2440.20 55.28 956.29 3.50 -80.00 644.77 Hold for 20' 7 2811.25 60.51 64.92 2450.05 62.66 972.06 0.00 0.00 660.43 Start 3.5°/100'DLS,-74.92°TF,for 883.36' 8 3695.35 72.20 33.49 2811.64 589.60 1567.38 3.50 -74.92 1444.59 Hold for 8654.75' 9 12354.96 72.20 33.49 5459.28 7465.39 6117.34 0.00 0.00 9651.47 10 12358.94 72.31 33.58 5460.50 7468.56 6119.44 3.50 35.90 9655.25 2N-312 wp04 EB 20Nov14 -Big* 11 13063.32 54.70 33.58 5773.50 7991.69 6466.75 2.50 180.00 10280.37 CAMP_SST -3889.5 C-50 -4149.5 C-40 __4' Iceberg anomal 2nd Iceberg anoma 4936.0 T-7 -5193.5 0-4.1 74 ►By signing this I acknowledge that I have been informed of all risks,checked that the data is correct,ensured ifs completeness,and all surrounding wells are assigned to the proper position and I approve the scan and collision avoidanceplanas set out in the audit pack.I approve it as the basis for the final well ^j .. � " �LL •� Prepared by: Checked by: Accepted by: Approved by: Vincent Osara Nate Beck Ifeanyi Ifesie ORIGINAL 0 s a I I I I I I I I I I I I I I IT I I 1 1 1 Nol lhingl(i u co I 'n)I 1 I I 11 1 1 1 1 1 1 1 I I 11 I I 11 I I I !^ U C p C U a O - N JM m (n Q. -Ci — O N • N p d tD U al - n3 p n — CM V _ C 1 '— liowS) (p' N `- N 'D r9 O L._ — 1 I N N CO TN a MI - CO .rte O N = �\� O N I I ) Q N d C`7 O CO r 1 1r J CO a (nom _ 1aN I 2 d 55) N • M ` r N L cir CO _ 5 o rN Q N - O co ~•• r @ 3' J M N m co O _ N J d N ( --I N - N O MI N J M N O N N Z Q E- d a s , CO N 3 3 — � N m m M r m r a a. 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C`, "1 " "1 " NNNNNN N N N N E E E E E E E, E EE 0) M M M M M M M M M M M M M M M O • o d IY .. o z z z ZZZZZ E ZZZ zN E 0> 0> 0> U0> 0> 22 z z Z C C CO V N N N N N N N N N N N N N N N O 0- 0_ 0- d O a NL d O Q Ve R w U U 0 • ox a ° fj U Cti .x cl 'Q G 4 PiO U O C O U 0 0 O CO 0 1- N N 0 0 < Y Y N U) < < m fl & 0 Il LL 0 + + 000222 0 T a N an 10 as 4 O a Q > N o T M i N o 0 as J (C 7.-- V' V V' V' V -4 a aaao_o31C- o' N N N N N N d W M M M M M 'P'HA ZZZZZZ U L_ N N N N N N N o N N ,7 2 .2 O O Lo u-) (N N N 3i N N M O O N N M C C I O O O M 'p U7 O Z o o C) Ern (N c0 o C m U �o O o n N o E N v N N V N4 r O N U w 9 C E C 15,...4) N C N C CL � a ( N 9 cn L cO00NN) I- C O Gl C C L W OO O N C O 'NO £ O O D O NN N pfL 3 y.. O N OOf f O U 2 .O �. r r N N { U N NO ML LI- RI tN OM e- O M F 3O cn N y O J.2a1a) 2 m m G = co . UO N O I •N C N «) LN U O- V o N 3 O O@ doN N N C C O O o co . 6OY pN II N 2.a Q o It N N O O -O G m LL U c0 V N ° O O O p C }^= QJ ° N C (6 3 Y 2. U p_ N N < W U ( 0 0 0 ORIGINAL • • Con©coPhillips 2N-31 2wp04. 1 Schlumherger Alaska ,. i Q 2 .,,.. , M4 //ifw n A 300 - I�� I iism,".f���®1� ��1� ! I��li11�l�l�" i���ll1�ll I i;I IIIF 1 1I , lir ply ..._... .. ._ - .._. .. ....... ... .....--- I 1111 O 1 i II dioillllll�I � �� � � :PIA - II IJ / Il/ 1 V4 E nri!, I III 611 IIIIII ,// 0 i „.enrill8 1'111'1 1 I III II IIID l I 1 � (n 11a P � l unl it ilI it II \ , _ 0 , 11 11 - I O7 m . 150 e/J 1 7 1.,1� nllla 41 SOI I111111I1 1') i IIIIIIIIII1:r wool II =14.4al�'IYJ(iiP I - - !(rdill011111 I I I .mr ,n"10'1ppp!I I 0 . I I I I I I 1 I I I I 1 I I I 1 I I I 1 0 2000 4000 6000 8000 10000 Disp "fwetriM°could be less than entire range: Measured Deptl'39.50 To 13063.32 ANTI-COLLISION SETTINGS Interpolation Method: MD,interval:25.00 Depth Range From: 39.50 To 13063.32 Results Limited By: Centre Distance:1502.38 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1000.00 2N-312wp04.1 (Plan:2N-312) GYD-GC-SS 1000.00 2000.00 2N-312wp04.1 (Plan:2N-312) MWD 1000.00 2791.25 2N-312wp04.1 (Plan:2N-312) MWD+IFR-AK-CAZ-SC 2791.25 4291.25 2N-312wp04.1 (Plan:2N-312) MWD 2791.25 12120.17 2N-312wp04.1 (Plan:2N-312) MWD+IFR-AK-CAZ-SC 12120.17 13063.32 2N-312wp04.1 (Plan:2N-312) MWD CASING DETAILS TVD MD Name Size 120.00 120.00 16"x 42" 16 2440.20 2791.25 10-3/4"x 13-1/2" 10-3/4 5387.50 12120.17 7-5/8"x 9-7/8" 7-5/8 5773.50 13063.32 3 1/2"x 6-1/2" 3-1/2 LEGEND -e- 2L-330,2L-330,2L-330 V8 -A- 2N-311,2N-311A,2N-311A W -i- 2N-322(Lexington),2N-322PB1,2N-322PB1 VO -e- Plan:2L-328(Sierra),2L-328,2L-328 wp08 VO -X- 2N-313,2N-313,2N-313 V2 -9-- 2N-322(Lexington),2N-322PB2,2N-322PB2 VO -X- 2N-302,2N-302,2N-302 V11 - -A- 2N-314,2N-314,2N-314 V3 -9- 2N-323,2N-323,2N-323 V2 - 2N-303,2N-303,2N-303 V4 --1- 2N-315,2N-315,2N-315 V2 -e- 2N-323,2N-323A,2N-323A V0 -B- 2N-303,Plan:2N-303A,2N-303A VO -0- 2N-316,2N-316,2N-316 V9 -9- 2N-325,2N325,2N-325 V2 -B- 2N-304,2N-304,214-304 V32 -.- 2N-317,2N-317,2N-317 V2 -X- 2N-326,2N-326,2N-326 V3 --e- 2N-304,2N304P21,2N-304PB1 V12 -B- 2N-317,Plan:2N-317A,2N-317A(wp01)VO -e- 2N-327,2N-327,2N-327 V13 $- 2N-305,2N-305,2N-305 V6 - 2N-318,2N-318,2N-318 V4 -9--�� 2N-329,2N329,2N-329 V2 -X- 2N-305,2N-305A,2N-305A VO -A- 2N-318,2N-318A,2N-318A V0 --n�- Prelim:2N-301(Zebra),2N-301,2N-301(wp03)V3 -h- 2N-306,2N-306,2N-306 V1 -e-- 2N-319,2N-319,2N-319 V2 -i- Prelim:2N-301(Zebra),2N-301PB1,2N-301PB1(NP03)VO - -- 214-307,2N-307,214-307 V7 9-- 2N-319,2N-319A,2N-319A VO -A-- Prelim:2N-324(Purple),2N-324,2N324wp03 VO -0-- 2N-308,2N-308,214-308 V2 - 214-320,2N-320,2N-320 V2 -B- Prelim:214-330(Peggy),2N-330,2N-330(wp02)VO -e- 2N-309,2N-309,214-309 V2 .-- 2N-321,2N-321,2N-321 V2 -e- Prelim:214-330(Peggy),2N-330PB1,2N-330PB1(wp02)VO -B- 2N-310,2N-310,2N-310 V6 --A- 214-321,2N-321A,2N-321A V4 -B- 2N312wp04.1 -X- 2N311,2N-311,2N-311 V1 --8- 2N-322(Lexington),2N-322,214-322 VO ORIGINAL 0 0 ConocoPhillips 2N-31 2wp04. 1 Scb[umberger Afaska 3 ILI,IC r, s r C.N1 NN H f1 N Z N ---1.-: . �IP!d i I �At� r ' 1 :/ ; 7 P 60 1D ■�ItlIl!_ ���:i� c• Utl _��� r ��_ . �'rar 4.., T ..I I I j30 • v♦r11®_ r : sll®DDLiiail��ll'/',���'1/' A� 4pij1jgi11imgiPø 110• Equivelant Magnetic Distance, 0 I I I I I I I I I I I I I I I I I I I I I I I I 0 400 800 1200 1600 2000 2400 Displayed interval could be less than entire range: Measured Depthi39.50 To 13063.32 ANTI-COLLISION SETTINGS Interpolation Method: MD, interval:25.00 Depth Range From: 39.50 To 13063.32 Results Limited By: Centre Distance: 1502.38 SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 39.50 1000.00 2N-312wp04.1 (Plan:2N-312) GYD-GC-SS 1000.00 2000.00 2N-312wp04.1 (Plan:2N-312) MWD 1000.00 2791.25 2N-312wp04.1 (Plan:2N-312) MWD+IFR-AK-CAZ-SC 2791.25 4291.25 2N-312wp04.1 (Plan:2N-312) MWD 2791.25 12120.17 2N-312wp04.1 (Plan:2N-312) MWD+IFR-AK-CAZ-SC 12120.17 13063.32 2N-312wp04.1 (Plan:2N-312) MWD CASING DETAILS TVD MD Name Size 120.00 120.00 16"x 42" 16 2440.20 2791.25 10-3/4"x 13-1/2" 10-3/4 5387.50 12120.17 7-5/8"x 9-7/8" 7-5/8 5773.50 13063.32 3-1/2"x 6-1/2" 3-1/2 LEGEND X 2L-330,2L-330,2L-330 V8 -B- 2N-311,2N-311A,2N-311A W --e- 2N-322(Lexington),2N-322PB1,2N-322PB1 VS -a- Plan:2L-328(Sierra),2L-328,2L-328 wp08 VO --I- 2N-313,2N-313,2N-313 V2 ---X- 2N-322(Lexington),2N-322PB2,2N-322PB2 VO - 2N-302,2N-302,2N-302 V11 -8- 2N-314,2N-314,2N-314 V3 -X- 2N-323,2N-323,2N-323 V2 --e- 2N-303,2N-303,2N-303 V4 --e- 2N-315,2N-315,2N-315 V2 --h- 2N-323,25-323A,2N-323A V0 -0- 2N-303,Plan:2N-303A,2N-303A VO -A- 2N-316,2N-316,2N-316 V9 -X- 2N-325,2N-325,2N-325 V2 -0- 2N-304,2N-304,2N-304 V32 -e- 2N-317,2N-317,2N-317 V2 -a- 2N-326,2N-326,2N-326 V3 - 2N-304,2N-304PB1,2N-304PB1 V12 -0- 2N-317,Plan:2N-317A,2N-317A(wp01)VO --X- 2N-327,2N-327,2N-327 V13 -A- 2N-305,2N-305,2N-305 VS -e- 2N-318,2N-318,2N-318 V4 -e-- 2N-329,2N-329,2N-329 V2 ---I--- 2N-305,2N-305A,2N-305A V0 -8- 2N-318,2N-318A,2N-318A V0 -8- Prelim:2N-301(Zebra),2N-301,2N-301(wp03)V3 -8- 2N-306,2N-306,2N-306 VI -A- 2N-319,2N-319,2N-319 V2 -e- Prelim:2N-301(Zebra),2N-301PB1,2N-30IPB1(WP03)VO --e- 2N-307,2N-307,2N-307 V7 -j- 2N-319,2N-319A,2N-319A V0 $ Prelim:2N-324(Purple),2N-324,2N324wp03 V0 --A- 2N-308,2N-308,2N-308 V2 -I- 2N-320,2N-320,2N-320 V2 --0- Prelim:2N-330(Peggy),2N-330,2N-330(wp02)VO -$- 2N-309,2N-309,2N-309 V2 - 2N-321,2N-321,2N-321 V2 -X- Prelim:2N-330(Peggy),2N-330PB1,2N-330PB1(wp02)VO -0- 2N-310,2N-310,211-310 V6 -8- 2N-321,2N-321A,2N-321A V4 -8- 2N-312wp04.1 2N-311,2N-311,211-311 V1 -0- 2N-322(Lexington),2N-322,2N-322 VO ORIGINAL. Inc Azi TVD eN/-5 1-E/-W Dleg TFacect Target 0.00 0.00 39.50 0.00 0.00 0.00 0.00 �0 0.00 0.00 300.00 0.00 0.00 0.00 2N-312wp04.1 600.00 4.50 135.00 599.69 8.333 8.33 1.50 135.00 -1.23 .. 1081.26 16.53 135.00 1072.00 -70.32 70.32 2.50 0.00 -10.39 250 440 39.50 To 13063.32 2791.25 16.53. 135.00. 2440.20 -91.31. 956:29 3.50 -80.00 6 0.00 0.00 44.77 440 640 2811.25 60.51 64.92 2450.05 62.66 972.06 0.00 0.00 660.43 3695.35 72.20 33.49 2811.64 589.60 1567.38 3.50 -74.92 1444.59 640 830 ``4 r 12354.96 72.20 33.49 5459.28 7465.39 6117.34 0.00 0.00 9651.47 i'Rk „..,,,,z, :°. a > 12358.94 72.31 33.58 5460.50 7468.56 6119.44 3.50 35.90 9655.25 2N-312wp04 EB 20Nov14 830 1020 """""" """" 13063.32 54.70 33.58 5773.50 7991.69 6466.75 2.50 180.00 10280.37 SURVEY PROGRAM 1020 1220 D o1n From Depth To Survey/Plan Tool 0 .0.00 2.312,04.1(Plan:co-micro-cc-so 1220 1410 000.00 2000.00 2113124p04.1(Plan:21.1J12)MWD 1000.00 2791.25 2313124004.1(Plan:211312)13W13+1FR-AKCAS.SC 1410 - 1600 2791.25 4291.25 2N3122/704.1(Plan:2312K.1WD 2791.25 12120.17 211-3124011.1(Plan:211312)MWWIFR-AK-CA2SC p 12120.17 13093.32 293122/209.1(POn:2N312)MWD 1600 2080 CASING DETAILS 2080 2550 TVD MD Name Size 2550 3030 120.00 120.00 16"x 42" 16 2440.20 2791.25 10-3/4"0 13-1/2" 10-3/4 3030 3500 5387.50 12120.17 7-5/8"x 9-7/8" 7-5/8 5773.50 13063.32 3 1/Z 0 6-1/2" 3-1/2 3500 3980 3980 4450 EMI 231_3061 4450 4930 EzEa 1 0/360 ETEE / I2N305/4� 4930 5400 I2N•3091 ,:,, ; °��+�I`i r3 - ,,; . 7 �'-i / 5400 6360 EMIE0/330 /.�i'�%q: +>;„'lt _i r ' g.4� : �.��i�s��;az =r.o 0 231.30 6360 7320 3z ` 1 /p� ..„,;•,-...-„,,, '''et y0' 4.e- :�, . 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(-- Lead De.,,,..-..;,:, ,,:,r ..,...':,:. ,,, f Legal Description(NAD27 only) _ 4.4 Starting Coordinates: Legal Description 4 X: 11607502.99 Township: 1010 IN :1 Range: [OF IE ...7.1 Y: 15919676.26 Meridian: EU .7.1 Section:125 ' , ,......., . . ... , ..,.,.. ...4.,, 1FINL ,r1 [2608.4847 FEITiri 14712.6266 ' _ rt ........_ Transform ---1 Quit I Help I ------- ORIGINAL . • *cation for Permit to Drill,Well 2N-312 Saved: 12-Feb-15 Attachment 2—Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) 2N-312 Drilling Hazards Summary 13-1/2" Hole / 10-3/4" Casing Interval Event Risk Level Mitigation Strategy Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate If observed -control drill, reduce pump rates, reduce drilling fluid temperatures, Additions of Lecithin. Gravel/Sand Sloughing Moderate Increase mud weight/viscosity, High viscosity sweeps. Monitor fill on connections Hole Swabbing/Tight Hole on Moderate Circulate hole clean prior to trip. Proper hole fill Trips (use of trip sheets), Pumping out of hole as needed. Lost Circulation Low Prevent by keeping hole clean. If losses occur- reduce pump rates and mud rheology, use LCM 9-7/8" Hole / 7-5/8" Casing Interval Event Risk Mitigation Strategy Level Campanian/Iceberg Sands Low Control with higher MW and proper drilling practices. High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, PWD Tools, Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 6-3/4" Hole / 3-1/2" Liner Interval Event Risk Mitigation Strategy Level High ECD and swabbing with Moderate Condition mud prior to trips. Monitor ECD's with higher MW's required PWD tool while drilling across pay interval. Pump and rotate out on trips as a last resort. Abnormal Reservoir Pressure Low Plan to top set the 7-5/8" intermediate casing above the Bermuda placing the entire intermediate section behind pipe prior to drilling the Bermuda Mud weight will be used for offsetting formation pressure Lost Circulation Low Use PWD to monitor hole cleaning. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 2N'-312 APD Page 11 of 7 RtGINA ) Printed. 12-Feb-15 • •cation for Permit to Drill,Well 2N-312 • Saved: 12-Feb-15 Well Proximity Risks: Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. A separation factor(or proximity ratio) using the ratio of center-to-center distance divided by the combined ellipses of uncertainty between two wellpaths is used to determine wellbore collision risk. A ratio of greater than 1.0 indicates two different well path ellipses of uncertainty do not touch. The traveling cylinder plot is used on the rig to keep track of the wellpath position relative to close approaches to offset existing wellbores. In the event that the wellpath falls behind the curve, drilling is stopped and the motor bend can be increased or the survey frequency can be increased. In general, no significant clearance issues exist with the 2N-312 well plan. Anti-collision analysis indicates the following separation factors between the planned 2N-312 well plan and the following existing wellbores. 2N-310 (Separation Factor= 1.547, 7.3' ellipse separation ata depth of 700' MD) 2N-311A(Separation Factor= 2.273, 9.01' ellipse separation at a depth of 425' MD) 2N-304 (Separation Factor= 2.061, 103.44' center to center at a depth of 4750' MD) Drilling Area Risks: Reservoir Pressure: Offset injection conduits have the potential to increase reservoir pressure over predicted, although this is unlikely, the rig will be prepared to weight up if required. Due to the greater degree of reservoir pressure uncertainty in the Bermuda targeted interval, the Bermuda will first be topset to keep the shallower unstable shale behind pipe prior to penetrating the Bermuda. Mandatory flow checks will be performed upon penetration and when tripping out of suspected gas or overpressured zones such as the Campanian, Iceberg, and Bermuda intervals. Lower Shale Stability: Unstable shale and ash in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. Good drilling practices will be stressed to minimize the potential of surging or swabbing the formation. 2NT-312 APD Page 12 of 7 ORI Glkt\1 Printed: 12-Feb-15 • Illation for Permit to Saved:Drill,Well 2N-312 12-Feb 15 Attachment 3—Proposed Well Schematic Tam 2N-312 ShangriLa Grass Roots Topset Slant Injector ono C Phillips Proposed Wellbore Schematic c,kr t i kg N 4-k'tree.top Joint is 4-b'12.6019TM,tort ee BruunsWI k 2l10.�15 Not Yet Installed Conductor i8, 62.6r H-40 3 4"Camco DS Nipple 2.875" s. 428'MDI Driliplex Spud 4281VD Mud 9-5 PPG 3%Cameo MMC314'X1Y:'o 13'f:"Surface Hole xxxx MDdxxxz'TVD wldummy Strface Casing 10-314"45.5#L-80 Hydril 563 2,791'MD/2,440'1 VD @ 600 3 W Cameo MMG 31.XIV* it xxxx'MD txxxx ND sr/dummy 9 Carnpani:,r:Top 3,057'MD 11,566-TVD); . Tubin is 314'Camco MMG 3./..•X 1 Y:' '- '' 3-1/1 9.3#F L-80 EUE8RD xxxx`MD l am'TVD is/dummy LSND 9.6 PPG Keep up with Dilution TOC 15.11 ppg 0+s'-r.100°MO 3WCamco MMG3WX1Y:'w; Y 9-718"Intermediate Hole Sav@ xxxx'MDftau'TVD 1 3 W Baker CMU Sliding geese 2.E 12"Caruso DS Prot'ile xxxi MD I max'ND 1 C-37 Top 8.6014'MD {4;341r TWj : ! 4 `i.. 314-Camco D Nipple 2.75" 1 jet 4°xxxx MD!tom'ND li 7-5t6'.ZXP Liner Top Packer am'MDF xxxx'TVD 1 7-516"x 3-W Baker Flex Lock Liner hanger ve RS Nipple. r+• xxxx'MD/xxxx'TVD I� , 4"m Seal Bore Extension % ', li Intermediate Casino Topset: + 1 ;. 7-5/8"29-7#L-80 HYD563 12,120'MD 15,38T TVD @!72g r. TOP of.Beenuc14412251 MD 54`r TVLI 1� y 1021 ly �-3.4 Production Hole i 7103+PFG 1 r Bermuda Pore Pressure i EE EE EE EE I 8.1 — 10.2 11.97 ppg `y - 5 . t' 2na -2,900 - 3,tn'trs� w : .tit IL Base Bermuda 12 553iA.6 5,577• jpr`� 11 C:enlented Production Liner: 3 112"9.3#%L-80 Hydric 563 13,063'MD/5,773'TVD©54° 2N'-312 APD Page 13 of 7 Printed: 12-Feb-15 ORIGINAL • *cation for Permit to Saved:Drill,Well 2N-b31125 Attachment 4-Cement Summary 10-3/4" Surface Casing run to 2791' MD 12440' TVD Cement from 2791' MD to 2200' (591' of fill)with 12.0 ppg DeepCRETE, and from 2200' to surface with ASL @ 11.0 ppg DeepCRETE. Assume 250%excess annular volume in permafrost and 50% excess below the permafrost(1134' MD). Lead slurry: (2200- 1134')X 0.3634 ft3/ft X 1.5 (50% excess) = 582 ft3 below permafrost 1134'X 0.3634 ft3/ft X 3.5 (250% excess) = 1443 ft3 above permafrost Total volume = 582 + 1443 =2025 ft3=> 1050 Sx @ 1.93 ft3/sk Tail slurry: 591'X 0.3634 ft3/ft X 1.5 (50% excess) = 323 ft3 annular volume 80'X 0.5397 ft3/ft=44 ft3 shoe joint volume Total volume = 323 + 44 = 367 ft3=>226 Sx @ 1.63 ft3/sk System: 226 Sx 12.0 ppg DeepCRETE & 1050 Sx ASL 11.0 ppg DeepCRETE 7-5/8" Intermediate Casing run to 12114' MD/5387' TVD Cement from 12,114' MD to 8100' MD. A minimum of 500' above C-37 w/Class G @ 15.8 PPG. Assume 40% excess annular volume. Tail Slurry: (12,114'-8,100') X 0.2146 ft3/ft X 1.4 (40%excess) = 1206 ft3annular vol. 80'x 0.2577 ft3/ft=21 ft3 shoe joint volume Total volume= 21 ft3+ 1206 ft3= 1227 ft3=> 1049 Sx @ 1.17 ft3/sk System: 1049 Sx 15.8 ppg Class G 3-1/2" Liner run to 13057' MD/5773' TVD Cement from 13,057' MD to liner top packer @ - 11,980' MD with Class G @ 15.8 ppg. Assume 40% excess annular volume Tail Slurry: (13057' - 11980')x 0.1815 ft3/ft x 1.4 (40% excess) =274 ft3annular vol. Total Volume = 274 ft3=> 234 Sk @ 1.17 ft3/sk System: 234 Sx 15.8 ppg Class G A 2N'-312 APD RI (� L Page 14 of-17 10"ft PrinteFeb-15 • • i 0 0 N N O 0 360 9 - 349 Q 348 Q T�/� .8.- 347 9 V1 a -Q 0 rii - 343 9 342 9 (3n 0 Q .,... 330 9 o 0 336 9 sae _ 3349 r 3339 r = CA _ 327 p 326 9 lin 8.—326-9 324 Q 3a 323 Q ri n 14 322 9 2N Access Road o Z ^--3awQ =>-519 9 c75 o O 318 9 -317 9 O 378 Q y aid-(9 7 O Pi314 9 9 � o. El t0m N 311 D 'D 310 Q r O V f7 o N 396 Q —ae7-Q n ti 306 9 O A 306 9 3 m y 304 9 C N m 303 Q * 302 9 n O O 301 9 O Z Fri ®_ D 01 c) 01 cr. 2 In w4m N Del ./ n m Z 4 N Z 9 CA N • • Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, February 18, 2015 12:27 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 2N-312: Permit to Drill Application Sorry, it's an injector, not planning to produce. Sent with Good (www.good.com) From: Bettis, Patricia K (DOA) <patricia.bettis@alaska.gov> Sent: Wednesday, February 18, 2015 3:06:19 PM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2N-312: Permit to Drill Application Good afternoon Scott, On the Form 10-401, Box 1B Proposed Well Class, both "Development Oil" is checked and "Service-WAG". Please verify which is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at (907)793- 1238 or patricia.bettis@alaska.gov. 1 • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Wednesday, February 18, 2015 12:06 PM To: Brunswick, Scott A (Scott.A.Brunswick@conocophillips.com) Subject: KRU 2N-312: Permit to Drill Application Good afternoon Scott, On the Form 10-401, Box 1B Proposed Well Class, both "Development Oil" is checked and "Service-WAG". Please verify which is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and,so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907)793-1238 or patricia.bettis@ialaska.gov. 1 • • Bettis, Patricia K (DOA) From: Brunswick, Scott A <Scott.A.Brunswick@conocophillips.com> Sent: Wednesday, February 18, 2015 3:52 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 2N-312: Permit to Drill Application No plans to pre-produce. Sent with Good (www.good.com) From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent: Wednesday, February 18, 2015 5:21:06 PM To: Brunswick, Scott A Subject: FW: [EXTERNAL]KRU 2N-312: Permit to Drill Application Scott, One more question,will KRU 2N-312 be pre-produced? Thank you, Patricia Original Message From: Bettis, Patricia K (DOA) Sent: Wednesday, February 18, 2015 12:28 PM To: 'Brunswick, Scott A' Subject: RE: [EXTERNAL]KRU 2N-312: Permit to Drill Application Thank you Scott. I didn't want to presume. Original Message From: Brunswick, Scott A [mailto:Scott.A.Brunswick@conocophillips.com] Sent: Wednesday, February 18, 2015 12:27 PM To: Bettis, Patricia K(DOA) Subject: RE: [EXTERNAL]KRU 2N-312: Permit to Drill Application Sorry, it's an injector, not planning to produce. Sent with Good (www.good.com<http://www.good.com>) From: Bettis, Patricia K(DOA) <patricia.bettis@alaska.gov> Sent:Wednesday, February 18, 2015 3:06:19 PM To: Brunswick, Scott A Subject: [EXTERNAL]KRU 2N-312: Permit to Drill Application 1 • • Good afternoon Scott, On the Form 10-401, Box 1B Proposed Well Class, both "Development Oil" is checked and "Service-WAG". Please verify which is correct. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, AK 99501 Tel: (907) 793-1238 CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Patricia Bettis at(907) 793- 1238 or patricia.bettis@alaska.gov. 2 • • 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: IC R,(K I PTD: c2JS_o2 _Development Service Exploratory _Stratigraphic Test _Non-Conventional FIELD: Kr4 POOL: l& ot,14-(r k✓yl ()1I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI The permit is for a new wellbore segment of existing well Permit LATERAL No. , API No. 50- - - - (If last two digits Production should continue to be reported as a function of the original in API number are API number stated above. between 60-69) In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well Pilot Hole name ( PH) and API number (50- - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to produce/inject is contingent upon issuance of a conservation Spacing Exception order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 AAC 25.071(a)authorizes the AOGCC to specify types of well logs to be run. 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Technical Report Title Date Client: ConocoPhillips Alaska, Inc Field: Kuparuk River Unit Rig: Doyon 25 Date: May 30, 2015 Surface Data Logging End of Well Report 2N-312 TABLE OF CONTENTS 1. General Information 2. Daily Summary 3. Days vs. Depth 4. After Action Review 5. Mud Record 6. Bit Record 7. Morning Reports 8. Survey Report Digital Data to include: Final Log Files Final End of Well Report Final LAS Exports Halliburton Log Viewer EMF Log Viewer GENERAL WELL INFORMATION Company: Conoco Phillips Rig: Doyon 25 Well: 2N-312 Field: Tarn Borough: North Slope Borough State: Alaska Country: United States API Number: 50-103-20706-00-00 Sperry Job Number: AK-XX-0902410359 Job Start Date: 13 May 2015 Spud Date: 08 May 2015 Total Depth: 12950’ MD, 5715’ TVD North Reference: True Declination: 18.57° Dip Angle: 80.75° Total Field Strength: 57533 nT Date Of Magnetic Data: 18 May 2015 Wellhead Coordinates N: North 70° 10’ 12.522” Wellhead Coordinates W: East 150° 19’ 2.187“ Drill Floor Elevation 157.5’ Ground Elevation: 117.7’ Permanent Datum: Mean Sea Level SDL Engineers: Macy Williams, Jacob Hansen, Eli Callan SDL Sample Catchers: Mike Frazier, Bradley Craig Company Geologist: Kelly Umlauf Company Representatives: Lee Martin, Granville Rizek SSDS Unit Number: 125 DAILY SUMMARY 05/11/2015 Currently rigging up power, gas and communication lines to the unit. Current operations on the rig include running in 10.75 inch casing to bottom. 05/12/2015 Currently finishing rigging up the unit and calibrating gas gear. Current rig operations include performing a cement job as per schlumberger cement program. 05/13/2015 Nippled up BOP stack and tested. Tested MPD skid. Picked up new BHA and began to trip in to 2541’MD. Currently circulating and conditioning mud for casing test. Gas: The max trip gas was 25 units and the average background gas was 6 units 05/14/2015 Tested Casing and MPD tools. Drilled out of cement, float and casing shoe into 20 feet of new formation to 2763’MD. Displaced well to new 9.6ppg LSND fluid and performed and leak off test to 16.6 ppg. Currently drilling ahead at report time from 2763 at report time. Gas: The max gas was 90 units at 2863’ MD and the average drilling background gas was 15 units. Geology: The samples have been predominantly transitioning from claystone to siltstone with and increase in sandstone later in the day. The samples predominantly consisted of a light gray to medium gray color, soft to firm texture and a blocky to sub-blocky shape. The siltstone transitioned from being slightly arenaceous to occasionally argillaceous. 05/15/2015 Drilled ahead from 3302’MD to 5574’MD. Circulated mud to clean hole and began back reaming up the hole from 5574’MD to casing shoe. Gas: The max gas was 81 units at 3461’ MD and the average drilling background gas was 40 units. Geology: The samples have been predominantly transitioning from clay stone to siltstone with an occasional transition to sandstone. The samples predominantly consisted of a light gray to medium gray color, soft to firm texture and a blocky to sub-blocky shape. The siltstone transitioned from being slightly arenaceous to occasionally argillaceous with traces of pyrite. The sandstone was a white to gray color, predominantly fine grained, firm and mostly consolidated from a calcite cement matrix with the occasional unconsolidated grains. 05/16/2015 Drilled ahead to 6922’ MD. Short tripped from 4625’MD to the casing shoe. Fix and test upper and lower IBOP. Run back in the hole from 2734’MD to 5482’MD. Dilute mud system. Began drilling ahead from 5482’MD to 6865’ MD. Pumped sweep due to bit balling up at 6865’MD and 6919’ MD Continue drilling ahead from 6919’ MD at report time Gas: The max gas was 90 units at 6756’ MD and the average drilling background gas was 55 units. Geology: The samples have been predominantly transitioning from siltstone to sandstone. The siltstone samples predominantly consisted of a medium gray to dark gray color, soft to slightly firm microcrystalline texture and a blocky to sub-blocky shape. The siltstone transitioned from being slightly arenaceous to occasionally argillaceous with traces of pyrite. The sandstone was a white to gray color, predominantly fine grained, firm and slightly consolidated from a calcite cement matrix. Mostly unconsolidated grains were present throughout the samples. 05/17/2015 Drill ahead from 6922’MD to 8036’MD. Performed a 580 bbl dilution. Continue drilling to 8316’MD. Installed MPD bearing. Continue drilling to 8856’ MD. Start closing chokes at 8790’ MD Continue drilling ahead at time of report. Gas: The max gas was 153 units at 8807’ MD and the average drilling background gas was 100 units. Geology: The samples have been predominantly transitioning from siltstone to sandstone with some shale stringers occasionally showing up in the samples. The siltstones are a dark gray to medium gray color, soft to moderately hard with a blocky to flaky texture, earthy dull lusters with the occasionally microcrystalline sparkling surfaces. Some traces of tuff, pyrite and quartz grains are present. The Sandstones are translucent, opaque to white, light to medium gray in color. Fine to medium grain size, sub-round to round in shape and moderately well sorted. Predominately unconsolidated. 05/18/2015 Continue drilling ahead from 8886’ MD to 11,519’ MD. Currently drilling ahead. Gas: The max gas was 1192 units at 9493’ MD and the average drilling background gas was 129 units. Geology: The samples have been predominantly transitioning from siltstone to sandstone with some shale stringers occasionally showing up in the samples. The siltstones are a dark gray to medium gray color, soft to moderately hard with a blocky to flaky texture, earthy dull lusters with the occasionally microcrystalline sparkling surfaces. Some traces of tuff, pyrite and quartz grains are present. The Sandstones are translucent, opaque to white, light to medium gray in color. Fine to medium grain size, sub-round to round in shape and moderately well sorted. Predominately unconsolidated. Some oil shows were found in some of the sandstone intervals 05/19/2015 Continued drilling ahead from 11519’ MD to TD of 11,688’MD. Circulated and conditioned mud. Pumped a high viscosity sweep and circulated out with a minimal increase in cuttings. Monitored well to make sure it was static. Pumped a low viscosity sweep. Back reamed out of the hole from 11,630’ MD to 3939’ MD Gas: The max gas was 389 units at 11688’ MD and the average drilling background gas was 48 units. Geology: The samples were predominately sandstone with some small percentages of siltstone and shale stringers present. The samples consisted of light gray to medium gray with translucent to white opaque colors. Very fine to medium grain. Spherical to sub-angular shaped grains, moderately well sorted. Mostly unconsolidated with occasional consolidated fragments. Traces of biotite, quartz and pyrite present. 05/20/2015 Back reamed out of the hole from 3969’MD to 2743’MD. Pumped a high viscosity sweep. Monitored well to make sure it was static. Pulled MPD bearing. Pumped slug and pulled out of the hole. Layed down BHA and flushed and drained BOP stack. Changed pipe rams and tested BOP. Performed dummy run with hanger. Run 7.625” casing to 2187’MD Gas: The max gas was 8 units at 11688’ MD and the average drilling background gas was 5 units. 05/21/2015 Ran 7.625” casing from 2167’MD to 2710’MD. Circulated the hole clean at 6 barrels per minute. Continued running casing to 5070’MD. Circulated the hole clean. Ran casing to 9072’MD Circulated and conditioned the mud. Pulled up and did a DDV and function test. Continue to run casing. Gas: The max gas was 292 units at 11688’ MD and the average drilling background gas was 27 units. 05/22/2015 Continued to run in hold with 7.625” casing to 11635’MD. Circulated and conditioned mud for cement job. Pumped 50 bbls of 11.5ppg MUDPUSH, 196bbls of 15.8ppg cement, 10 bbls of fresh water displace with 520 bbls of mud. Flushed stack and landed hanger. Slipped and cut drill line. Freeze protect with 84 bbls of diesel. Lay down 5” drill pipe Gas: No significant gas data. 05/23/2015 Lay down 5” drill pipe. Nippled down BOP. Change out pipe rams. Gas: No significant gas data. 05/24/2015 Finished testing the BOP. Picked up 4” drill pipe and racked back. Picked up 6.5” Powerdrive BHA. Tripped into hole with 4” drill pipe. Log while tripping into the hole from 7600’MD to 10,628MD. Gas: The max gas was 11 units at 11688’ MD and the average drilling background gas was 6 units. 05/25/2015 Tripped into hole while singling in with 4” drill pipe to 11,568’MD. Circulated and conditioned mud for casing test. Tested casing to 3000 psi for 30 minutes. Results were satisfactory. Drilled out cement, float and shoe. Drilled new hole to 11,708’ MD. Circulated and conditioned mud for FIT. Performed FIT to 16.0 ppg EMW. Displaced well to 10.2 ppg LSND. Washed down to 11,682’ MD. Performed fingerprint and MPD parameter adjustments. Continued to drill ahead to 12058’ MD Gas: The max gas was 35 units at 11987’ MD and the average drilling background gas was 10 units. Geology: The samples were predominately sandstone with siltstone and shale increasing their percentages as we got closer to 12,000’MD. The samples stayed a light gray to dk gray in color The sandstone was very fine to medium grain moderately well sorted, unconsolidated with the occasional consolidated fragments. The siltstone was soft to firm and friable, predominantly platy in texture. The shale also increased in the samples in the lower section. It was moderately hard, dense to brittle, platy and flaky in texture, earthy dull luster. 05/26/2015 Drilled ahead from 12,068’ MD to TD of 12,950’ MD. Circulated bottoms up 3 times. Monitored well with choke closed with a result of 8 psi. Opened the RCD port and had minimal flow back. Circulated and conditioned. Weighted up the mud to 10.5 ppg Gas: The max gas was 2629 units at 12950’ MD and the average drilling background gas was 244 units. 05/27/2015 Pulled out of hole from 12,950’ MD to 11,603’ MD, holding pressure per MPD trip schedule. Monitored well – slight flow that decreased over time. Continued to pull out of hole from 11,603’ MD to 601’ MD, holding pressure as per MPD trip schedule. Monitored well – slight flow, well was U- tubing. Pulled all the way out of hole and laid down BHA. Rigged up and began to run 3.5” production liner to 1,175’ MD. Gas: No significant gas data. 05/28/2015 Run in hole with liner to 12,843’ MD. Washed down from 12,843’MD to 12,938’MD. Circulate Bottoms up while reciprocating, conditioning mud. Pump cement job as per schlumberger. Displace well with Seawater Gas: No significant gas data. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 12000 13000 14000 15000 0 5 10 15 20 25 30 Me a s u r e d D e p t h Rig Days Prognosed Actual WELL NAME: 2N-312 OPERATOR: ConocoPhillips Alaska, Inc MUD CO: Mi Swaco RIG: Doyon 25 SPERRY JOB: AK-XX-0902410359 Days vs. Depth 11 May 2015 Sperry SDL Arrived on Location 13 May 2015 Sperry SDL Services Online LOCATION: Kuparuk River Unit AREA: North Slope Borough STATE: Alaska SPUD: 8-May-2015 TD: 26-May-2015 Commenced 9.875" Intermediate Hole Section On Bot: 17:45 14 May 2015 Drill 9.875" hole to 6922' STP to Shoe to change IBOP 16 May 2015 TD Intermediate Hole Section 11688' MD, 5257' TVD Off Bot: 02:06 19 May 2015 Landed 7.625" Casing 11677' MD, 5254' TVD 22 May 2015 Commenced 6.5" Production Hole Section On Bot: 08:00 25 May 2015 Landed 3.5" Liner 12949' MD, 5715' TVD 28 May 2015 TD Production Hole Section 12950' MD, 5715' TVD Off Bot: 13:15 26 May 2015 WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We had some depth coorection issues as well as some gas data that wasn’t lining up right while writing to the log. We recailbrated and flowed the equipment for the next section. Recommendations: N/A Innovations and/or cost savings: Flow tested equipment in house instead of sending it to the shop in Deadhorse to be flow tested. AK-XX- 902410359 Doyon 25 Jacob Hansen Kuparuk River Unit North Slope Borough Alaska Intermediate 19-May-2015 What went as, or better than, planned: We had enough time to rig up and calibrate gas equipment smoothly. We made it TD with no major data losses or missed samples. 2N-312 ConocoPhillips Alaska, Inc Surface Data Logging After Action Review Surface Data Logging WELL NAME:LOCATION: OPERATOR:AREA: SPERRY JOB:STATE: RIG:HOLE SECTION: EMPLOYEE NAME:DATE: Sperry Drilling Confidential Document v 3.0 Difficulties experienced: We had some issues collecting gas from the flow line from the CVE at the start of the Production Section. Turns out the suction tube was clogged with some clay from the flow line. Suction tube was cleaned up. Recommendations: N/A Innovations and/or cost savings: N/A AK-AM-902410359 Doyon 25 Jacob Hansen Kuparuk River Unit North Slope Borough Alaska Production 27-May-2015 What went as, or better than, planned: Used Casing break to re-flow gas gear.. We made it to TD with no major data losses or missed samples. Gas equipment was recalibrated and flow tested. Everything else went well. 2N-312 ConocoPhillips Alaska, Inc Surface Data Logging After Action Review Surface Data Logging 2N-312 ConocoPhillips Alaska, Inc Mi Swaco Doyon25 AK-XX-0902410359 Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 13-May 2743 9.50 52 12 22 8/9/10 7.1 46/34/29/23/9/8 1/-6.0 *3/91 *-0.85 9.7 1.3 .70/2.00 600 40 Circ & Condition Mud 14-May 3302 9.60 49 13 24 9/10/12 6.4 50/37/31/23/10/9 1/-6.0 *3/91 *-0.60 10.0 2.5 .30/1.50 700 54 Drilling Ahead 15-May 5574 9.60 51 17 23 9/15/25 4.7 57/40/33/25/10/9 1/-7.5 *3/9 0.25 0.80 10.1 20.0 .50/1.10 800 40 BROOH 16-May 6922 9.60 47 14 21 8/12/17 4.8 49/35/29/23/9/8 1/-8.0 *2/90 0.50 0.50 10.2 20.0 .30/1.20 900 30 Drilling Ahead 17-May 8886 9.60 47 12 21 8/9/10 4.5 45/33/28/21/9/8 1/-8.0 *2/90 0.50 0.40 9.8 22.5 .30/1.30 600 40 Drilling Ahead 18-May 11519 9.70 45 1 20 8/9/10 4.5 42/31/27/21/9/8 1/-9.0 *2/89 0.50 0.30 9.5 16.3 .20/1.30 800 40 BROOH 19-May 11688 9.70 45 10 23 8/9/10 4.0 43/33/37/20/9/8 1/-9.0 *2/89 0.50 0.50 9.7 23.8 .40/1.20 800 40 Running Casing 20-May 11688 9.70 45 10 17 7/8/9 4.0 37/27/24/18/8/7 1/-9.0 *2/89 0.50 0.50 10.0 25.0 .30/1.20 800 40 Running Casing 21-May 11688 9.80 45 11 18 7/8/9 4.2 40/29/23/18/8/7 1/-9.0 *2/89 0.50 0.30 9.6 25.0 .20/1.10 700 40 L/D Drill Pipe 22-May 11688 9.70 47 11 18 6/7/8 4.4 40/29/23/18/7/6 1/-9.0 *2/89 0.50 0.40 9.7 25.0 .30/1.30 600 40 Test BOP 23-May 11688 9.70 48 12 17 6/7/8 4.2 41/29/23/19/7/6 1/-9.0 *2/89 0.50 0.40 9.7 25.0 .30/1.30 700 40 TIH 24-May 11718 9.70 48 11 20 7/8/9 4.2 42/31/24/20/8/7 1/-9.0 *2/89 0.50 0.30 9.6 25.0 .20/1.10 700 40 Drilling Ahead 25-May 12078 10.20 50 15 22 7/8/9 3.8 52/37/30/22/8/7 1/-8.0 *2/90 tr 0.40 9.9 10.0 .30/1.60 600 180 Circulate/clean well Date Depth Wt Vis PV YP Gels Filt R600/R300/R200/R100/ R6/R3 Cake Solids Oil/Water Sd Pm pH MBT Pf/Mf Chlor Hard Remarks ft - MD ppg sec lb/100 lb/100ft2 m/30m Rheometer 32nds %%%ppb Eqv mg/l Ca++ 26-May 12950 10.5 46 12 20 *6/7/8 3.6 44/32/27/20/7/6 1/-10 *2/88 tr 0.4 9.9 15 .30/1.20 500 80 Monitor Well 27-May 12950 10.6 45 13 19 *6/7/8 3.6 45/32/27/19/7/6 1/-10 *2/88 tr 0.4 9.9 15 .30/1.10 600 80 Running Liner 28-May 12950 8.5 27 ---------------Displace with seawater Casing Record Remarks 10.75" Casing @ 2733' MD, 2733' TVD 7.625" Casing @ 11677' MD, 5254' TVD 3.5" Casing @ 12949' MD, 5715' TVD WELL NAME:LOCATION:Kuparuk River Unit OPERATOR:AREA:North Slope Borough MUD CO:STATE:Alaska RIG:SPUD:8-May-2015 SPERRY JOB:TD:26-May-2015 W a t e r a n d O i l B a s e d M u d R e c o r d BHA#SDL RUN #Bit #Bit Type Bit Size Depth In Depth Out Footage Bit Hours TFA AVG ROP WOB (max) RPM (max) SPP (max) FLOW GPM (max)Bit Grade Comments 3 100 3 PDC 9.83 2743 11688 8945 87.51 0.991 102.2 10000 175 3025 700 1-1-NO-A-X-I-NOTD TD Intermediate Hole Section 4 200 4 PDC 6.50 11688 12950 1262 15.08 0.383 83.7 7000 175 2910 255 1-1-NO-A-X-I-NOTD TD Production Hole Section Alaska RIG:Doyon25 SPUD:8-May-2015 WELL NAME:2N-312 LOCATION:Kuparuk River Unit OPERATOR:ConocoPhillips Alaska, Inc AREA:North Slope Borough MUD CO: SPERRY JOB:AK-XX-0902410359 TD:26-May-2015 Mi Swaco STATE: B i t R e c o r d . . * rig Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l 600.00 4 27 Depth Condition ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: - Max Gamma, Res, ECD, Directional Morning Report Report # 1 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Bit # 3 6.0 9.875 9.50 PDC 9.50 Size 2743' 100% Gas In Air=10,000 Units-Connection 45 API FL Chromatograph (ppm) 2743' WOB 2733' 22 Avg Min Comments RPM ECD (ppg) ml/30min -Background (max) Trip Average - Mud Type Lst Type Depth in / out Cht Cement 0 26 C-4n Cly 2 0 0 Hours C-3 C-4i AK-AM-0902410359 Installing MPD Bearing PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP (lb/100ft2) 9.70 C-1 C-5i LSND 7.1 GvlCoal 45.5 Weight Footage Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst Tuff C-5n Avg to Flow In (gpm) Flow In (spm) Current Date: 24 hr Max 13-May-2015 12:00 AM 2743' 2743' 0' Max @ ft cP 12 (ppb Eq) 0 65 Depth Time: Set At in 2 - 6 Gas Summary Depth 1.3 - C-2 52 Tools 0 25 SPP (psi) Gallons/stroke TFABit Type Minimum 1 MBT pH 0.991 0 18886 10.75'' - - Units* Casing Summary Lithology (%)Siltst 907-659-7599Unit Phone: 30 Macy Williams Maximum Report By:Logging Engineers:Jake Hansen \ Macy Williams Size Grade Intermediate 49 9 (max)(current) 636 0 24 hr Recap: Nipple up BOP and test. Test MPD skid. Pick up BHA and begin to trip in to 2541' MD. Circulate and condition mud for casing test. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time . . * 24 hr Recap: Test casing and MPD. Drill out cement, float, and casing shoe. Drill new hole to 2763' MD. Displace well to new 9.6ppg LSND fluid. Perform LOT to 16.6 ppg. Drill ahead from 2763' MD. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 249.84 (max)(current) 1439 0 2479305.41 55.57 15 6 19 Grade Intermediate 907-659-7599Unit Phone: 27 Macy Williams Maximum Report By:Logging Engineers:Jake Hansen \ Macy Williams 10.75'' 702 166 Units* Casing Summary Lithology (%)Siltst Size Minimum 2 MBT pH 0.991 0 690 SPP (psi) Gallons/stroke TFABit Type Depth 2.5 2863' 176.0 C-2 49 Tools Set At in 1 2763' 15 Gas Summary 0 0 13 Depth Time: 2743' 3302' 559' Max @ ft cP 13 (ppb Eq) 3299'131.0 Date: 24 hr Max 14-May-2015 12:00 AM Tuff C-5n Avg to 222.0 Flow In (gpm) Flow In (spm) Current Ss Silt (current) Granville Rizek/Rob Reinhardt ShClyst LSND 6.4 GvlCoal 45.5 Weight Footage YP (lb/100ft2) 10.00 C-1 C-5i AK-AM-0902410359 Drilling Ahead PV Yesterday's Depth: Current Depth: 24 Hour Progress: 3 Hours C-3 30% 7668 Cement 0 24 C-4n ClyCht 60% 0 C-4i Mud Type Lst 10% Type Average 46-50Background (max) Trip 24 Avg Min Comments RPM ECD (ppg) ml/30min Chromatograph (ppm) 2743' WOB 2733' Depth in / out 100% Gas In Air=10,000 UnitsConnection 5 9.875 9.60 PDC 9.60 Size 3021' Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: Morning Report Report # 2 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 1960 Max Gamma, Res, ECD, Directional Depth Condition 1 1339 700.00 Bit # 3 6.0 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL rig . . * 24 hr Recap: Drill ahead from 3302' MD to 5574' MD. Circulate hole clean and begin back reaming out of hole from 5574' to the casing shoe. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 399.51 (max)(current) 4962 0 Intermediate Set At 492.06 92.55 80 907-659-7599Unit Phone: 35 Macy Williams Maximum Report By:Logging Engineers:Jake Hansen \ Macy Williams 702 166 Units* Casing Summary Lithology (%)Siltst Size Grade Minimum 0 MBT pH 0.991 0 081 SPP (psi) Gallons/stroke TFABit Type 10.75'' C-2 51 Tools 34 in 2 3928' 40 Gas Summary 0 0 3169 19 (ppb Eq) Tuff 6 Depth Time: Depth 20.0 3461' - 24 hr Max 15-May-2015 12:00 AM 3302' 5574' 2272' Max @ ft cP C-5n Avg to 319.0 Flow In (gpm) Flow In (spm) Current Ss Granville Rizek/Rob Reinhardt ShClyst 4344'162.6 LSND 4.7 GvlCoal 45.5 Weight Footage (lb/100ft2) 10.10 C-1 C-5i Silt 17 AK-AM-0902410359 Changing I-BOP PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: Hours C-3 9419 0 23 C-4n Cly Chromatograph (ppm) Cht 80% 0 C-4i Mud Type Lst 20% Type Average -Background (max) Trip 8.229.19 Avg Min Comments RPM ECD (ppg) ml/30min Connection 0 2743' 23 9.60 Size 5101'800.00 Depth in / out WOB 2733' 23 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 10.58 Doyon 25 Report For: Morning Report Report # 3 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad ROP ROP (ft/hr) 4.23 @ Mud Data Current Pump & Flow Data: 1960 Max Gamma, Res, ECD, Directional Condition 714 Depth 9.875 9.60 PDC Cement (current) Bit # 3 7.5 Density (ppg) out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL rig 0 100% Gas In Air=10,000 Units . . *100% Gas In Air=10,000 Units rig 10 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL PDC Cement (current) Bit # 3 Depth 9.875 9.60 310 Mud Data Current Pump & Flow Data: 1960 Max Gamma, Res, ECD, Directional Density (ppg) 2N Pad ROP ROP (ft/hr) 4.23 @ Morning Report Report # 4 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 21 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: 11.09 Doyon 25 Report For: Connection 16 2743' 46 10.78 Avg Min Comments RPM ECD (ppg) ml/30min 900.00 WOB 13Background (max) Trip Average 210 Mud Type Lst 70% Type Cht 30% 0 C-4i 0 0 C-4n Cly Chromatograph (ppm) C-3 12572 AK-AM-0902410359 Drilling Ahead PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i Silt 14 HoursSize Depth in / out GvlCoal 45.5 Weight 2733' 6421'195.0 LSND 4.8 Footage (lb/100ft2) 10.20 Current Ss Granville Rizek/Rob Reinhardt ShClyst C-1 9.606804' Max @ ft cP C-5n Avg to5574' 286.0 Flow In (gpm) Flow In (spm) 16-May-2015 12:00 AM 5574' 6922' 1348' 10.44 Condition 8.0 6 Depth Time: Depth 20.0 6756' 80.0 24 hr Max 4978 30 Tuff in 6 6080' 55 Gas Summary 6 0 C-2 47 Tools 77 (ppb Eq) 90 SPP (psi) Gallons/stroke TFABit Type 10.75'' Minimum 4 MBT 6922' pH 0.991 11 9 702 166 Units* Casing Summary Lithology (%)Siltst Size Grade 907-659-7599Unit Phone: 5 Macy Williams Maximum Report By:Logging Engineers:Jake Hansen \ Macy Williams Intermediate Set At 612 116.5 7686 (max)(current) 6736 56 24 hr Recap: Trip out of hole from 4625' MD to the casing shoe. Fix and test upper and lower IBOP. Run back into the hole from 2734' MD to 5482' MD. Dilute mud system. Begin drilling ahead from 5482' MD to 6865' MD. Pumped sweep due to bit balling up at 6865' MD and 6919' MD. Continue drilling ahead from 6919' MD. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 496.41 . . *100% Gas In Air=10,000 Units153 rig 77 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP PDC Cement (current) Bit # 3 10% Depth 9.875 9.70 6179 0 Mud Data Current Pump & Flow Data: 35 Max Gamma, Res, ECD, Directional Density (ppg) 4.23 @ Current 17-May-2015 12:00 AM 697 Morning Report Report # 5 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: 11.53 Doyon 25 Report For: ROP ROP (ft/hr) 226 C-3 21 Job No.: Daily Charges: Total Charges: ml/30min 600.00 WOB Connection 383 2743' 100Background (max)Trip Average Mud Type Lst 30% Type Cht 0 C-4i 33 C-4n Cly Chromatograph (ppm) 60% 16177 C-2 AK-AM-0902410359 Drilling Ahead PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i Silt 12 HoursSize Depth in / out GvlCoal 45.5 Weight 2733' Comments 7509'152.0 LSND 4.5 Footage (lb/100ft2) 9.80 Granville Rizek/Rob Reinhardt ShClyst C-1 9.658889' Max @ ft C-5n Avg to6922' 312.0 Flow In (gpm) Flow In (spm) 91 6922' 8889' 1967' 10.39 Condition 8.0 10.94 Avg Min Depth Time: Depth 22.5 8807' 170.0 24 hr Max 6390 35 Tuff in 2 8257' 50 Gas Summary 0 0 10.75'' 47 Tools 896 (ppb Eq) Intermediate Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum 21 MBT 8889' pH 0.991 0 74 165 Units* Casing Summary Lithology (%)Siltst Size Grade 907-659-7599Unit Phone: 24 Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan Set At 789 151 161 153 (max)(current) 6096 0 24 hr Recap: Directionally drill 9 7/8" hole from 6922' to 8036'. Perform 580 bbl dilution. Continue drilling to 8316'. Install MPD bearing. Continue drilling to 8886'. Start closing chokes at 8790'. Continue to drill ahead. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 637 0 . . *100% Gas In Air=10,000 Units1192 rig 410 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP PDC Cement (current) Bit # 3 Depth 9.875 9.75 4916244 0 Mud Data Current Pump & Flow Data: 2990 Max Gamma, Res, ECD, Directional Density (ppg) 4.23 @ Current 18-May-2015 12:00 AM 702 Morning Report Report # 6 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: 11.34 Doyon 25 Report For: ROP ROP (ft/hr) 762 C-3 20 Job No.: Daily Charges: Total Charges: ml/30min 800.00 WOB Connection 2692 2743' 85Background (max)Trip Average Mud Type Lst 70% Type Cht 30% 17 C-4i 162 C-4n Cly Chromatograph (ppm) 95900 C-2 AK-AM-0902410359 Drilling Ahead PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i Silt 11 HoursSize Depth in / out GvlCoal 45.5 Weight 2733' Comments 10049'204.0 LSND 4.6 Footage (lb/100ft2) 9.50 Granville Rizek/Rob Reinhardt ShClyst C-1 9.6511519' Max @ ft 49.12 C-5n Avg to8889' 345.0 Flow In (gpm) Flow In (spm) 745 8889' 11524' 2635' 10.83 Condition 9.0 11.12 Avg Min Depth Time: Depth 16.3 9493' 185.0 24 hr Max Tuff in 6 11241' 129 Gas Summary 0 0 10.75'' 45 Tools 5908 (ppb Eq) Intermediate Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum 66 MBT 11524' pH 0.991 27 337 165 Units* Casing Summary Lithology (%)Siltst Size Grade 907-659-7599Unit Phone: 157 Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan Set At 579 1192 (max)(current) 11633 36 24 hr Recap: Continue to directionally drill 9 7/8" hole from 8886' to 11,519'. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time . . *100% Gas In Air=10,000 Units rig 297 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min PDC Cement (current) Bit # 3 Depth 9.875 9.60 5917545 0 Mud Data Current Pump & Flow Data: 2097 Max Gamma, Res, ECD, Directional Density (ppg) 4.23 @ Current 19-May-2015 12:00 AM 681 175.0 Lee Martin/Rob Reinhardt Flow In (gpm) Morning Report Report # 7 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: 11.28 Doyon 25 Report For: ROP ROP (ft/hr) 373 C-3 23 Job No.: Daily Charges: Total Charges: 20856 800.00 WOB Connection 949 2743' 92 10Background (max)Trip Average 123 Mud Type Lst Type Cht 0 C-4i C-4n Cly Chromatograph (ppm) C-2 AK-AM-0902410359 POOH PV 11688' Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoalSilt 10 HoursSize Depth in / out 45.5 Weight 2733' Comments 10.75'' Grade LSND 4.0 Footage (lb/100ft2) 9.70 ShClyst C-1 9.6011688' Max @ ft 56.71 C-5n Avg to11524' 300.0 Flow In (spm) 416 11524' 11688' 164' 11.09 Condition 9.0 11.20 Avg Min Depth Time: Depth 23.8 11688' 0.0 24 hr Max 45 Tools Tuff in 3 11393' 48 Gas Summary 0 0 1369 (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum 54 MBT 11688' pH 0.991 0 141 161 Units* Casing Summary Lithology (%)Siltst Size 907-659-7599Unit Phone: 111 Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan Set At 90 389 (max)(current) 4962 0 24 hr Recap: Directionally dilled 9 7/8" hole from 11,519' to a TD of 11,688' MD. Circulated and conditioned mud. Pumped a high viscosity sweep and circulated out with a minimal increase in cuttings. Monitered well - static. Pumped a low viscosity sweep. Back reamed out of hole from 11,630' to 3939'. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time . . *100% Gas In Air=10,000 Units rig out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min PDC Cement (current) Bit # 3 Depth 9.875 9.70 Mud Data Current Pump & Flow Data: Max Density (ppg) 4.23 @ Current 20-May-2015 12:00 AMLee Martin/Rob Reinhardt Flow In (gpm) Morning Report Report # 8 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) C-3 17 Job No.: Daily Charges: Total Charges: 800.00 WOB Connection 2743' 11688' 5Background (max)Trip Average Mud Type Lst Type Cht C-4i C-4n Cly Chromatograph (ppm) 8945' C-2 AK-AM-0902410359 Running 7 5/8" Casing PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoalSilt 10 HoursSize Depth in / out 45.5 Weight 2733' Comments 10.75'' Grade LSND 4.0 Footage (lb/100ft2) 10.00 ShClyst C-1 9.4011688' Max @ ft 56.71 C-5n Avg to Flow In (spm) 11688' 11688' 0' Condition 1,1,NO,A,X,1,NO,TD 800.0 Avg Min Depth Time: Depth 25.0 24 hr Max 45 Tools Tuff in 3 5 Gas Summary (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum MBT pH 0.991 Units* Casing Summary Lithology (%)Siltst Size 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan Set At 8 (max)(current) 24 hr Recap: Back reamed out of hole from 3969' to 2743'. Pumped two high viscosity sweeps. Monitored well - static. Pulled MPD bearing. Pumped slug. Pull of of hole. Lay down BHA. Flushed and drained stack. Changed pipe rams and tested BOP. Performed dummy run with hanger. Run 7 5/8" casing to 2187'. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time . . * 24 hr Recap: Ran 7 5/8" casing from 2187' to 2710'. Circulated the hole clean at 6 bpm. Continued running casing to 5070'. Circulated the hole clean. Ran casing to 9072'. Circulated and conditioned the mud. Pulled up and did a DDV and function test. Continue to run casing. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 292 (max)(current) Set At 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 0.991 Units* Casing Summary Lithology (%)Siltst Size RPM ECD (ppg) Minimum MBT pH (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type in 2 27 Gas Summary Tuff 24 hr Max 45 Tools Avg Min Depth Time: Depth 25.0 Flow In (spm) 11688' 11688' 0' Condition 1,1,NO,A,X,1,NO,TD 9.09.8011688' Max @ ft 56.71 C-5n Avg to LSND 4.2 Footage (lb/100ft2) 9.60 ShClyst C-1 2733' Comments 10.75'' Grade Silt 11 HoursSize Depth in / out 45.5 Weight Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoal 8945' C-2 AK-AM-0902410359 Running 7 5/8" Casing PV C-4n Cly Chromatograph (ppm) Cht C-4i Mud Type Lst Type Average 2923Background (max)Trip 700.00 WOB Connection 2743' 11688' C-3 18 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 9 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad 4.23 @ Current 21-May-2015 12:00 AMLee Martin/Rob Reinhardt Flow In (gpm) Mud Data Current Pump & Flow Data: Max Density (ppg) Depth 9.875 9.80 PDC Cement (current) Bit # 3 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min rig 100% Gas In Air=10,000 Units . . *100% Gas In Air=10,000 Units rig out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min PDC Cement (current) Bit # 3 Depth 9.875 9.70 Mud Data Current Pump & Flow Data: Max Density (ppg) 4.23 @ Current 22-May-2015 12:00 AMLee Martin/Rob Reinhardt Flow In (gpm) Morning Report Report # 10 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) C-3 18 Job No.: Daily Charges: Total Charges: 600.00 WOB Connection 2743' 11688' Background (max)Trip Average Mud Type Lst Type Cht C-4i C-4n Cly Chromatograph (ppm) 8945' C-2 AK-AM-0902410359 Laying down 5" DP PV Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoalSilt 11 HoursSize Depth in / out 45.5 Weight 2733' Comments 10.75'' Grade LSND 4.4 Footage (lb/100ft2) 9.70 ShClyst C-1 9.7011688' Max @ ft 56.71 C-5n Avg to Flow In (spm) 11688' 11688' 0' Condition 1,1,NO,A,X,1,NO,TD 9.0 Avg Min Depth Time: Depth 25.0 24 hr Max 47 Tools Tuff in Gas Summary (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum MBT pH 0.991 Units* Casing Summary Lithology (%)Siltst Size 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan Set At (max)(current) 24 hr Recap: Continued to run in hole with 7 5/8" casing to 11,635'. Circulated and conditioned mud for cement job. Pumped 50 bbls of 11.5ppg MUDPUSH, 196 bbls of 15.8ppg cement, 10bbls of fresh water displace with 520 bbls of mud. Flushed stack and landed hanger. Slipped and cut drill line. Freeze protect with 84bbls of diesel. Lay down 5" drill pipe. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time . . * 24 hr Recap: Lay down 5" drill pipe. Nippled down BOP. C/O spacer spools. C/O pipe rams. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time (max)(current) Set At 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 0.991 Units* Casing Summary Lithology (%)Siltst Size RPM ECD (ppg) Minimum MBT pH (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type in Gas Summary Tuff 24 hr Max 48 Tools Avg Min Depth Time: Depth 25.0 Flow In (spm) 11688' 11688' 0' Condition 1,1,NO,A,X,1,NO,TD 9.09.7011688' Max @ ft 56.71 C-5n Avg to LSND 4.2 Footage (lb/100ft2) 9.70 ShClyst C-1 2733' Comments 10.75'' Grade Silt 12 HoursSize Depth in / out 45.5 Weight Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoal 8945' C-2 AK-AM-0902410359 Testing BOP PV C-4n Cly Chromatograph (ppm) Cht C-4i Mud Type Lst Type Average Background (max)Trip 700.00 WOB Connection 2743' 11688' C-3 17 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 11 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad 4.23 @ Current 23-May-2015 12:00 AMLee Martin/Rob Reinhardt Flow In (gpm) Mud Data Current Pump & Flow Data: Max Density (ppg) Depth 9.875 9.70 PDC Cement (current) Bit # 3 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min rig 100% Gas In Air=10,000 Units . . * 24 hr Recap: Finished testing the BOP. Picked up 4" drill pipe and racked back. Picked up 6 1/2" PowerDrive BHA. Trip into hole with 4" drill pipe. Log while tripping into the hole from 7600' to 10,628'. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 11 (max)(current) 7.63'' Set At 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 0.991 Units* Casing Summary Lithology (%)Siltst Size RPM ECD (ppg) Minimum MBT pH (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type in 2 6 Gas Summary Tuff 24 hr Max 48 Tools Avg Min Depth Time: Depth 25.0 Flow In (spm) 11688' 11688' 0' Condition 1,1,NO,A,X,1,NO,TD 9.09.7011688' Max @ ft 56.71 C-5n Avg to LSND 4.2 Footage (lb/100ft2) 9.60 ShClyst C-1 2733' Comments 10.75'' Grade Silt 11 HoursSize Depth in / out 45.5 Weight Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoal 8945' C-2 AK-AM-0902410359 Singling into hole PV C-4n Cly Chromatograph (ppm) Cht C-4i Mud Type Lst Type Average 115Background (max)Trip 700.00 WOB Connection 2743' 11688' C-3 20 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 12 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad 4.23 @ Current 24-May-2015 12:00 AMLee Martin/Rob Reinhardt Flow In (gpm) Mud Data Current Pump & Flow Data: Max Density (ppg) Depth 9.875 9.70 PDC Cement (current) Bit # 3 11677'Intermediate 29.7 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min rig 100% Gas In Air=10,000 Units . . *100% Gas In Air=10,000 Units rig 37 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min PDC Cement (current) Bit # 3 11677'Intermediate 29.7 40% Depth 9.875 10.25 2161 0 Mud Data Current Pump & Flow Data: 2862 Max Gamma, Resistivity, Neutron Density, VPWD Density (ppg) 4.23 @ Current 25-May-2015 12:00 AM 253 80.0 Lee Martin/Rob Reinhardt Flow In (gpm) Morning Report Report # 13 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad MWD Summary 96% Rig Activity: 11.78 Doyon 25 Report For: ROP ROP (ft/hr) 45 C-3 22 Job No.: Daily Charges: Total Charges: 40% 3364 600.00 WOB Connection 243 2743' 11688' 19 25Background (max)Trip Average Mud Type Lst 10% Type 3 Cht 0 C-4i 11688' C-4n Cly Chromatograph (ppm) 10% 8945' C-2 AK-AM-0902410359 Drilling ahead though production PV 11973' Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoalSilt 15 HoursSize Depth in / out 45.5 Weight 6.5 0.384 2733' Comments PDC 10.75'' Grade LSND 3.8 Footage (lb/100ft2) 9.90 ShClyst C-1 10.2012078' Max @ ft 56.71 C-5n Avg 11688' 187.0 Flow In (spm) 115 11688' 12058' 370' 11.42 Condition 1,1,NO,A,X,1,NO,TD 8.0 11.59 Avg Min Depth Time: Depth 10.0 11987' 60.0 24 hr Max 50 Tools 3705 62 Tuff 0 in 3 11708' 10 Gas Summary 0 0 274 (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type RPM ECD (ppg) Minimum 4 MBT 12058' pH 0.991 0 35 60 Units* Casing Summary Lithology (%)Siltst Size 907-659-7599Unit Phone: 22 Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 7.63'' Set At 551 128 22 35 (max)(current) 659 0 24 hr Recap: Tripped into hole picking up 4" drill pipe to 11,568'. Circulated and conditioned mud for casing test. Tested casing to 3000 psi for 30 minutes. Results were satisfactory. Drilled out cement, float and shoe. Drilled new hole to 11,708'. Circulated and conditioned mud for FIT. Performed FIT to 16.0 ppg EMW. Displaced well to 10.2 ppg LSND. Washed down to 11,682'. Perform fingerprint and MPD parameter adjustments. Continue to directionally drill 6 1/2" hole. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 373 . . * 8 24 hr Recap: Directionally drilled 6 1/2" hole from 12068' to a TD of 12950'. Circulated bottoms up 3 times. Monitored well with choke closed with a result of 8 psi. Opened the RCD port and had minimal flow back. Circulated and conditioned. Weighted up the mud to 10.5 ppg. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 396 2629 (max)(current) 13052 7.63'' Set At 587 137.9 65 907-659-7599Unit Phone: 1635 Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 0.991 11 2855 52 Units* Casing Summary Lithology (%)Siltst Size RPM ECD (ppg) Minimum 375 MBT 12950' pH 11701 (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type in 5 12056' 244 Gas Summary 0 0 3811 73 Tuff 0 24 hr Max 46 Tools 11.73 Avg Min Depth Time: Depth 15.0 12950' 0.0 Flow In (spm) 8372 12058' 12950' 892' 11.33 Condition 1,1,NO,A,X,1,NO,TD 10.010.5012950' Max @ ft 56.71 C-5n Avg 12058' 206.0 LSND 3.6 Footage (lb/100ft2) 9.90 ShClyst C-1 0.384 2733' Comments PDC 10.75'' Grade Silt 12 HoursSize Depth in / out 45.5 Weight 6.5 Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoal 8945' C-2 AK-AM-0902410359 Monitoring well PV 12749' 11688' C-4n Cly Chromatograph (ppm) Cht 16 C-4i Mud Type Lst Type 3 Average 30Background (max)Trip 500.00 WOB Connection 10450 2743' 11688' 1483 1583 C-3 20 Job No.: Daily Charges: Total Charges: 109638 MWD Summary 96% Rig Activity: 12.47 Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 14 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad 4.23 @ Current 26-May-2015 12:00 AM 199 116.0 Lee Martin/Rob Reinhardt Flow In (gpm) Mud Data Current Pump & Flow Data: 619 Max Gamma, Resistivity, Neutron Density, VPWD Density (ppg) 3261238278 0 Depth 9.875 10.50 PDC Cement (current) Bit # 3 11677'Intermediate 29.7 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min rig 1557 100% Gas In Air=10,000 Units2122 . . * 24 hr Recap: Pulled out of hole from 12950' to 11603', holding pressure per MPD trip schedule. Monitored well - slight flow, decreasing over time. Continued to pull out of hole from 11603' to 601' holding pressure per MPD trip schedule. Monitored well - slight flow, well U-tubing. Pulled all the way out of hole and layed down BHA. Rigged up and began to run 3 1/2" liner to 1175'. Volumes Hole Capacity (bbls) Drillstring Capacity (bbls) Annular Volume (bbls) Lag Correction (bbls) Bottoms Up Strokes Bottoms Up Time 153 (max)(current) 7.63'' Set At 907-659-7599Unit Phone:Elijah Callan Maximum Report By:Logging Engineers:Jake Hansen \ Elijah Callan 0.991 0 Units* Casing Summary Lithology (%)Siltst Size RPM ECD (ppg) Minimum MBT pH (ppb Eq) Surface Ss SPP (psi) Gallons/stroke TFABit Type in 5 20 Gas Summary Tuff 24 hr Max 45 Tools Avg Min Depth Time: Depth 15.0 Flow In (spm) 12950' 12950' 0' Condition 1,1,NO,A,X,1,NO,TD 10.010.5012950' Max @ ft 56.71 C-5n Avg LSND 3.6 Footage (lb/100ft2) 9.80 ShClyst C-1 0.384 2733' Comments PDC 10.75'' Grade 15.08 1262' Silt 13 HoursSize Depth in / out 45.5 Weight 6.5 Yesterday's Depth: Current Depth: 24 Hour Progress: YP Date: C-5i GvlCoal 8945' 12950' C-2 AK-AM-0902410359 Running 3.5" Liner PV 11688' C-4n Cly Chromatograph (ppm) Cht C-4i Mud Type Lst Type 3 Average 65Background (max)Trip 600.00 WOB Connection 2743' 11688' C-3 19 Job No.: Daily Charges: Total Charges: MWD Summary 96% Rig Activity: Doyon 25 Report For: ROP ROP (ft/hr) Morning Report Report # 15 Customer: Well: Area: Location: Rig: 2N-312 Conoco Phillips TARN 2N Pad 4.23 @ Current 27-May-2015 12:00 AM 0 Lee Martin / Paul Smith Flow In (gpm) Mud Data Current Pump & Flow Data: 27 Max Density (ppg) Depth 9.875 10.50 1,1,NO,A,X,1,NO,TD PDC Cement (current) Bit # 3 11677'Intermediate 29.7 out (sec/qt) Viscosity Cor Solids % Chlorides mg/l API FL cP ml/30min rig 100% Gas In Air=10,000 Units WELL INFORMATION Created On : Jun 26 2015 Customer :ConocoPhillips Alaska, Inc. Well Name :2N-312 Job Number :AK-XX-0902410359 Rig Name :Doyon 25 Field Name :Kuparuk River Unit Country :USA Survey Report SURVEY HEADER Survey data provided by Schlumberger. DIRECTIONAL SURVEY DATA Tie-in 0.00 0.00 0.00 0.00 0.00 N 0.00 E (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 39.79 0.00 0.00 39.79 0.00 N 0.00 E 0.00 0.00 81.00 0.54 307.67 81.00 0.12 N 0.15 W 0.12 1.31 169.58 0.61 317.43 169.57 0.72 N 0.80 W 0.72 0.14 260.20 0.13 139.81 260.19 1.00 N 1.06 W 1.00 0.82 353.10 2.22 150.30 353.07 0.65 S 0.10 W -0.65 2.25 449.73 3.87 147.10 449.56 5.01 S 2.60 E -5.01 1.72 542.42 4.85 141.21 541.98 10.69 S 6.75 E -10.69 1.16 636.40 6.21 137.45 635.52 17.53 S 12.68 E -17.53 1.50 730.29 8.67 136.82 728.61 26.43 S 20.95 E -26.43 2.62 825.35 9.97 134.78 822.42 37.46 S 31.70 E -37.46 1.41 919.30 12.08 135.09 914.63 50.15 S 44.41 E -50.15 2.25 978.85 13.11 133.85 972.74 59.24 S 53.68 E -59.24 1.79 1073.02 16.29 131.51 1,063.82 75.40 S 71.28 E -75.40 3.43 1167.84 17.76 131.00 1,154.48 93.70 S 92.15 E -93.70 1.56 1262.69 19.14 120.03 1,244.48 110.98 S 116.54 E -110.98 3.93 1356.78 19.98 113.66 1,333.15 125.15 S 144.62 E -125.15 2.43 1451.24 20.01 107.25 1,421.93 136.42 S 174.84 E -136.42 2.32 1545.37 22.25 100.09 1,509.74 144.32 S 207.78 E -144.32 3.63 1639.10 23.79 90.78 1,596.03 147.69 S 244.17 E -147.69 4.21 1736.73 26.40 90.33 1,684.44 148.08 S 285.57 E -148.08 2.68 1829.24 29.73 84.95 1,766.07 146.18 S 329.00 E -146.18 4.52 1924.95 32.38 78.41 1,848.08 138.94 S 377.77 E -138.94 4.48 2019.93 34.63 74.31 1,927.28 126.53 S 428.68 E -126.53 3.36 2115.50 36.15 74.45 2,005.19 111.63 S 481.98 E -111.63 1.59 2207.97 39.00 74.55 2,078.47 96.56 S 536.31 E -96.56 3.08 2302.71 43.32 72.62 2,149.79 78.90 S 596.09 E -78.90 4.75 2397.42 47.18 70.43 2,216.46 57.55 S 659.86 E -57.55 4.39 2492.95 50.60 67.76 2,279.26 31.84 S 727.06 E -31.84 4.15 2587.39 54.93 67.32 2,336.40 3.11 S 796.52 E -3.11 4.60 2662.70 57.69 66.60 2,378.17 21.42 N 854.18 E 21.42 3.75 INSITE V8.1.10 Page 1Job No:AK-XX-0902410359 Well Name:2N-312 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 2758.81 59.33 63.63 2,428.38 55.91 N 928.50 E 55.91 3.14 2853.12 59.73 60.46 2,476.21 94.01 N 1,000.29 E 94.01 2.93 2948.64 61.11 56.51 2,523.37 137.44 N 1,071.07 E 137.44 3.88 3043.01 63.82 54.35 2,567.00 184.93 N 1,139.95 E 184.93 3.52 3137.21 64.77 51.92 2,607.86 235.85 N 1,207.85 E 235.85 2.53 3232.26 65.32 49.48 2,647.97 290.43 N 1,274.53 E 290.43 2.40 3328.25 65.88 45.62 2,687.64 349.42 N 1,339.01 E 349.42 3.71 3422.54 66.90 42.37 2,725.41 411.57 N 1,399.00 E 411.57 3.34 3517.42 68.85 40.45 2,761.14 477.49 N 1,457.12 E 477.49 2.78 3611.14 71.07 37.53 2,793.26 545.92 N 1,512.50 E 545.92 3.77 3706.23 72.93 36.96 2,822.65 617.91 N 1,567.23 E 617.91 2.04 3799.47 72.82 34.85 2,850.10 690.08 N 1,619.48 E 690.08 2.17 3895.29 72.78 32.52 2,878.44 766.24 N 1,670.24 E 766.24 2.32 3990.25 72.87 33.96 2,906.49 842.12 N 1,719.97 E 842.12 1.45 4083.66 72.77 35.32 2,934.08 915.54 N 1,770.70 E 915.54 1.40 4178.12 72.88 34.91 2,961.97 989.36 N 1,822.61 E 989.36 0.43 4272.84 72.84 36.18 2,989.89 1,063.01 N 1,875.23 E 1063.01 1.28 4368.28 72.87 35.40 3,018.02 1,136.98 N 1,928.56 E 1136.98 0.78 4462.34 72.88 34.25 3,045.72 1,210.77 N 1,979.89 E 1210.77 1.17 4555.72 72.90 33.56 3,073.19 1,284.84 N 2,029.68 E 1284.84 0.71 4651.71 72.74 33.23 3,101.55 1,361.41 N 2,080.15 E 1361.41 0.37 4747.02 72.30 32.61 3,130.17 1,437.72 N 2,129.56 E 1437.72 0.77 4841.17 71.82 32.53 3,159.17 1,513.21 N 2,177.78 E 1513.21 0.52 4935.64 71.82 31.94 3,188.65 1,589.12 N 2,225.65 E 1589.12 0.59 5030.51 71.74 32.23 3,218.31 1,665.47 N 2,273.52 E 1665.47 0.30 5124.49 71.79 33.87 3,247.72 1,740.29 N 2,322.20 E 1740.29 1.66 5219.39 71.86 34.09 3,277.32 1,815.06 N 2,372.59 E 1815.06 0.23 5314.27 71.88 34.89 3,306.85 1,889.38 N 2,423.65 E 1889.38 0.80 5408.61 71.88 33.61 3,336.19 1,963.49 N 2,474.11 E 1963.49 1.29 5503.32 71.82 32.37 3,365.69 2,038.97 N 2,523.11 E 2038.97 1.25 5597.63 72.09 32.98 3,394.91 2,114.45 N 2,571.52 E 2114.45 0.68 5693.00 72.19 33.90 3,424.16 2,190.20 N 2,621.54 E 2190.20 0.92 5787.71 72.16 34.84 3,453.15 2,264.62 N 2,672.44 E 2264.62 0.95 5882.50 72.17 34.46 3,482.18 2,338.85 N 2,723.75 E 2338.85 0.38 5977.12 72.18 34.63 3,511.15 2,413.05 N 2,774.83 E 2413.05 0.17 6071.44 72.21 34.25 3,539.99 2,487.11 N 2,825.61 E 2487.11 0.38 6165.42 72.09 34.43 3,568.79 2,560.97 N 2,876.08 E 2560.97 0.22 6260.60 72.16 33.84 3,598.01 2,635.95 N 2,926.91 E 2635.95 0.59 6355.45 72.07 33.10 3,627.14 2,711.25 N 2,976.69 E 2711.25 0.75 6449.85 72.04 33.11 3,656.22 2,786.48 N 3,025.74 E 2786.48 0.03 6543.78 72.01 32.98 3,685.21 2,861.37 N 3,074.46 E 2861.37 0.14 6638.78 72.15 32.84 3,714.44 2,937.26 N 3,123.57 E 2937.26 0.20 6734.13 72.07 32.59 3,743.73 3,013.60 N 3,172.61 E 3013.60 0.26 6828.41 71.98 32.45 3,772.83 3,089.22 N 3,220.82 E 3089.22 0.17 6922.86 72.13 32.14 3,801.93 3,165.17 N 3,268.83 E 3165.17 0.35 INSITE V8.1.10 Page 2Job No:AK-XX-0902410359 Well Name:2N-312 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 7018.18 72.09 32.81 3,831.21 3,241.70 N 3,317.53 E 3241.70 0.67 7111.99 72.57 34.22 3,859.69 3,316.22 N 3,366.89 E 3316.22 1.52 7207.03 72.66 35.49 3,888.08 3,390.64 N 3,418.72 E 3390.64 1.28 7301.42 72.70 36.75 3,916.18 3,463.43 N 3,471.84 E 3463.43 1.28 7396.02 72.58 36.83 3,944.41 3,535.74 N 3,525.91 E 3535.74 0.15 7491.18 72.44 36.01 3,973.01 3,608.77 N 3,579.80 E 3608.77 0.83 7585.17 72.67 35.32 4,001.19 3,681.62 N 3,632.08 E 3681.62 0.74 7680.15 72.64 34.92 4,029.50 3,755.78 N 3,684.23 E 3755.78 0.40 7774.51 72.21 34.44 4,058.00 3,829.75 N 3,735.42 E 3829.75 0.67 7869.12 72.25 34.07 4,086.87 3,904.22 N 3,786.13 E 3904.22 0.37 7963.87 72.25 33.53 4,115.76 3,979.21 N 3,836.33 E 3979.21 0.54 8058.25 71.60 32.63 4,145.04 4,054.38 N 3,885.30 E 4054.38 1.14 8152.69 71.69 31.85 4,174.78 4,130.20 N 3,933.12 E 4130.20 0.79 8247.75 71.74 31.37 4,204.61 4,207.07 N 3,980.43 E 4207.07 0.48 8343.16 71.71 31.21 4,234.52 4,284.49 N 4,027.48 E 4284.49 0.16 8437.17 71.73 31.58 4,264.01 4,360.68 N 4,073.98 E 4360.68 0.37 8531.83 71.73 32.29 4,293.69 4,436.97 N 4,121.53 E 4436.97 0.71 8626.50 72.18 33.13 4,323.01 4,512.70 N 4,170.17 E 4512.70 0.97 8721.12 72.19 34.29 4,351.96 4,587.64 N 4,220.16 E 4587.64 1.17 8815.35 72.16 34.68 4,380.81 4,661.58 N 4,270.95 E 4661.58 0.40 8909.84 72.22 35.34 4,409.71 4,735.26 N 4,322.57 E 4735.26 0.67 9004.33 72.13 35.00 4,438.63 4,808.80 N 4,374.38 E 4808.80 0.36 9098.39 72.24 34.69 4,467.41 4,882.29 N 4,425.55 E 4882.29 0.33 9193.64 72.16 34.15 4,496.53 4,957.10 N 4,476.81 E 4957.10 0.55 9288.30 72.21 33.68 4,525.49 5,031.89 N 4,527.09 E 5031.89 0.48 9382.28 72.13 31.63 4,554.27 5,107.21 N 4,575.36 E 5107.21 2.08 9477.42 72.26 30.26 4,583.36 5,184.90 N 4,621.94 E 5184.90 1.38 9571.75 72.18 29.94 4,612.17 5,262.61 N 4,666.99 E 5262.61 0.33 9667.29 72.18 29.52 4,641.40 5,341.59 N 4,712.10 E 5341.59 0.42 9762.31 72.22 30.47 4,670.45 5,419.95 N 4,757.32 E 5419.95 0.95 9855.97 72.27 32.08 4,699.01 5,496.18 N 4,803.63 E 5496.18 1.64 9951.96 72.14 34.32 4,728.35 5,572.65 N 4,853.67 E 5572.65 2.23 10045.22 72.21 33.83 4,756.90 5,646.19 N 4,903.41 E 5646.19 0.51 10141.12 72.28 34.89 4,786.15 5,721.59 N 4,954.96 E 5721.59 1.06 10235.44 72.24 37.01 4,814.89 5,794.30 N 5,007.70 E 5794.30 2.14 10330.37 72.27 37.37 4,843.82 5,866.33 N 5,062.35 E 5866.33 0.36 10424.57 72.14 38.02 4,872.61 5,937.30 N 5,117.19 E 5937.30 0.67 10520.03 72.28 38.05 4,901.78 6,008.90 N 5,173.20 E 6008.90 0.15 10613.65 72.16 36.69 4,930.37 6,079.74 N 5,227.30 E 6079.74 1.39 10708.69 71.98 33.92 4,959.63 6,153.53 N 5,279.56 E 6153.53 2.78 10770.73 71.95 30.67 4,978.84 6,203.39 N 5,311.07 E 6203.39 4.98 10801.22 72.19 30.57 4,988.23 6,228.35 N 5,325.85 E 6228.35 0.85 10898.02 72.34 30.45 5,017.71 6,307.78 N 5,372.65 E 6307.78 0.19 10992.16 72.46 30.38 5,046.18 6,385.17 N 5,418.08 E 6385.17 0.15 11087.40 72.19 32.43 5,075.10 6,462.61 N 5,465.36 E 6462.61 2.07 INSITE V8.1.10 Page 3Job No:AK-XX-0902410359 Well Name:2N-312 Survey Report DIRECTIONAL SURVEY DATA (ft) Measured Depth DoglegVertical SectionDeparture (ft) Latitude (ft) Vertical Depth (deg) DirectionInclination (deg)(ft)(ft)(°/100') 11181.80 72.23 33.44 5,103.94 6,538.05 N 5,514.23 E 6538.05 1.02 11276.38 72.25 33.66 5,132.79 6,613.12 N 5,564.01 E 6613.12 0.22 11370.46 72.46 34.07 5,161.31 6,687.56 N 5,613.97 E 6687.56 0.47 11465.67 72.35 34.21 5,190.09 6,762.68 N 5,664.91 E 6762.68 0.18 11560.91 72.40 33.68 5,218.93 6,837.98 N 5,715.59 E 6837.98 0.53 11617.50 72.31 32.95 5,236.08 6,883.04 N 5,745.21 E 6883.04 1.24 11714.45 74.03 33.50 5,264.15 6,960.67 N 5,796.06 E 6960.67 1.86 11809.11 72.28 33.67 5,291.58 7,036.14 N 5,846.17 E 7036.14 1.86 11905.96 72.27 31.26 5,321.07 7,113.97 N 5,895.68 E 7113.97 2.37 12001.74 72.31 32.41 5,350.21 7,191.48 N 5,943.81 E 7191.48 1.14 12096.39 72.41 32.35 5,378.89 7,267.66 N 5,992.12 E 7267.66 0.12 12139.95 72.46 32.38 5,392.04 7,302.73 N 6,014.35 E 7302.73 0.13 12234.10 72.59 33.17 5,420.31 7,378.24 N 6,062.96 E 7378.24 0.81 12329.71 71.80 32.73 5,449.54 7,454.63 N 6,112.47 E 7454.63 0.94 12425.08 68.51 29.66 5,481.92 7,531.33 N 6,158.95 E 7531.33 4.59 12519.63 66.84 34.17 5,517.85 7,605.55 N 6,205.15 E 7605.55 4.75 12614.82 65.17 33.76 5,556.56 7,677.68 N 6,253.73 E 7677.68 1.80 12709.64 63.67 34.25 5,597.50 7,748.57 N 6,301.56 E 7748.57 1.65 12803.89 61.69 35.50 5,640.76 7,817.27 N 6,349.43 E 7817.27 2.41 12898.88 58.37 36.36 5,688.20 7,883.90 N 6,397.70 E 7883.90 3.58 12915.20 57.76 35.26 5,696.84 7,895.13 N 6,405.81 E 7895.13 6.83 DIRECTIONAL SURVEY DATA NOTES - Calculation based on minimum curvature method. - Survey coordinates relative to well system reference point. - TVD values given relative to drilling measurement point. - Vertical section relative to well head. - Vertical section is computed along a direction of 0.00 degrees (True) - A total correction of 18.57 deg from Magnetic north to True north has been applied - Horizontal displacement is relative to the well head. - Horizontal displacement (closure) at 12,915.20 feet is 10,166.98 feet along 39.05 degrees (True) INSITE V8.1.10 Page 4Job No:AK-XX-0902410359 Well Name:2N-312 Survey Report WARRANTY HALLIBURTON ENERGY SERVICES, INC. WILL USE ITS BEST EFFORTS TO FURNISH CUSTOMERS WITH ACCURATE INFORMATION AND INTERPRETATIONS THAT ARE PART OF, AND INCIDENT TO, THE SERVICES PROVIDED. HOWEVER, HALLIBURTON ENERGY SERVICES, INC. CANNOT AND DOES NOT WARRANT THE ACCURACY OR CORRECTNESS OF SUCH INFORMATION AND INTERPRETATIONS. UNDER NO CIRCUMSTANCES SHOULD ANY SUCH INFORMATION OR INTERPRETATION BE RELIED UPON AS THE SOLE BASIS FOR ANY DRILLING, COMPLETION, PRODUCTION, OR FINANCIAL DECISION OR ANY PROCEDURE INVOLVING ANY RISK TO THE SAFETY OF ANY DRILLING VENTURE, DRILLING RIG OR ITS CREW OR ANY THIRD PARTY. THE CUSTOMER HAS FULL RESPONSIBILITY FOR ALL DRILLING, COMPLETION, AND PRODUCTION OPERATION. HALLIBURTON ENERGY SERVICES, INC. MAKES NO REPRESENTATIONS OR WARRANTIES, EITHER EXPRESSED OR IMPLIED, INCLUDING, BUT NOT LIMITED TO, THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS FOR A PARTICULAR PURPOSE, WITH RESPECT TO THE SERVICES RENDERED. IN NO EVENT WILL HALLIBURTON ENERGY SERVICES, INC. SERVICES BE LIABLE FOR FAILURE TO OBTAIN ANY PARTICULAR RESULTS OR FOR ANY DAMAGES, INCLUDING, BUT NOT LIMITED TO, INDIRECT, SPECIAL OR CONSEQUENTIAL DAMAGES, RESULTING FROM THE USE OF ANY INFORMATION OR INTERPRETATION PROVIDED BY HALLIBURTON ENERGY SERVICES, INC. INSITE V8.1.10 Page 5Job No:AK-XX-0902410359 Well Name:2N-312 Survey Report