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Home My WebLink About212-100MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 1, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2A-27A KUPARUK RIV UNIT 2A-27A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/01/2024 2A-27A 50-103-20604-01-00 212-100-0 W SPT 5778 2121000 1500 2000 2000 2000 2000 278 389 353 336 4YRTST P Adam Earl 5/19/2024 4-year 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 2A-27A Inspection Date: Tubing OA Packer Depth 830 2710 2665 2660IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE240521073203 BBL Pumped:3.3 BBL Returned:3.1 Monday, July 1, 2024 Page 1 of 1             MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Guy Cook Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 11, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2A -27A KUPARUK RIV UNIT 2A -27A Src: Inspector Reviewed By P.I. Supry --1 h Comm Well Name KUPARUK RIV UNIT 2A -27A API Well Number 50-103-20604-01-00 Inspector Name: Guy Cook Permit Number: 212-100-0 Inspection Date: 5/6/2020 IUSp Num: mitGDC200507160706 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well 2A -27A Type Inj w - TVD 5778 Tubing 2284 2287 2293 2275 -- -�-- -- 2lzl000 "Type Test SPT 'Test psi 1500 IA PTD a65 3000 2940 2915 ' !-- 1 BBL Pumped: 4.6 BBL Returned: 4 OA 277 433 '� 387 ' 360- -_.---- — - - — Interval 4YRTST !p/F P Notes' Testing was done with a Little Red Services pump truck and calibrated gauges. ' Monday, May 11, 2020 Page I of I Schlumberger -Private 21210 3119Delivered Originated: to: Schlumberger DATE `\ 47 AOGCC 1 1 Se 19-JW01 PTS- PRINT CENTER s ATTN: Natural Resources Technician II 6411 A Anchoraage,ge, A AK 9 ` Alaska Oil & Gas Conservation Commision (907) 273-1700 main main (907)273-4760 fax + 333 W. 7th Ave, Suite 100 -., Anchorage, AK 99501 Schlumberger -Private • MEMORANDUM TO: Jim Regg "(�&f q -5`I Z4 II P.I. Supervisor FROM: Johnnie Hill Petroleum Inspector 0 State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 09, 2016 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2A -27A KUPARUK RIV UNIT 2A -27A Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A -27A Insp Num: mitJWH160508214612 Rel Insp Num: API Well Number 50-103-20604-01-00 Permit Number: 212-100-0 Inspector Name: Johnnie Hill Inspection Date: 5/7/2016 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2A -27A Type Inj v PT Di 2121000 Type Test SPT Test --TrTVD ; 577s I Tubing 1600 - 1600 - 1600 • 1600 " — ----- — psi 1500 IA 420 2510 - 2470 - 2465 - Interval 4YRTST p/F P ✓ OA 307 330- 1 330- 330 . - --L - - --- - - --- -- -- - Notes: 3.7 bbls of diesel , SaMAE® SEP 2 7 2016 Monday, May 09, 2016 Page 1 of I Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Sunday, February 08, 2015 9:52 AM To: Wallace, Chris D (DOA) Cc: NSK Problem Well Supv; Senden, R. Tyler; CPF2 Prod Engrs Subject: RE: 2A -27A (PTD 212-100-0) Report of IA pressure anomaly Attachments: Picture (Device Independent Bitmap) 1 jpg; Picture (Device Independent Bitmap) 2 jpg; 2A -27A 90 day TIO plot.JPG; 2A -27A schematic.pdf; MIT KRU 2A -27A Diagnostic MITIA 01-15-15.xls; 2A -27A 30 day TIO plot.JPG Chris, Kuparuk injector 2A -27A is about 5 days away from completing the 30 day test cycle. After the passing MITIA a larger differential pressure was left between the IA and OA. During the monitor period the annuli have continued to maintain the differential with no indications of IAxOA communication. The IA had a few pressure fluctuations that could be attributed to thermal responses as the WHT was not very stable. I have attached a 30 day TIO plot for the approved test period for reference. It is ConocoPhillips intention to return the well to normal injection and continue to monitor as per AIO 2C. If any further indications of suspected communication are identified, the well will be reported to AOGCC and further diagnostics performed at that time. Let me know if you disagree with this plan. 15001 �} ,_. 4r'rahh_ sj Well Name 2A -27A Notes: Start Date 1/912015 Days 30 End Date 2/8/2015 Annular Communication Surveillance 4404 - 12 _ %VHP _ 1AP 3500 OAP 12 �,'JHT 3400 12 2500 12 in 2000 a 12 1500 12 1004 11 E00 0 11 Jan -1E Jan -15 Jan -15 Jan -15 Jan -15 Jan -15 Feb -15 Feb -15 9= o a000 - MC:i O 7000 m dry yyn {000 OWU X000 =00 1000- 0. Jan -15 Jan -15 Jan -15 Jan -15 Jan -15 Jan -15 4-15 Feb -1f Date Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 WELLS TEAM From: NSK Problem Well Supv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to ilmseaq gl7alaska.gov. AOGCC Inspectors(abalaska qov, phoebe brooks(a)alaska qov chns wallace()alaska qov OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2A DATE: 01/15/15 OPERATOR REP: Beck / Manlarrez AOGCC REP: Notes: Diagnostic MITIA OAJ 2801 2751 2751 2751 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min, 60 Min We112A-27A T In W TVD 5,778' Tubing 2010, 2,0101 2,0101 2,0101 1 1 Intervall O P T D. 12121000 1 Type test I P I Test psi 1 1500 Casingl 3101 3,0001 2,9601 2,950 P/F I P Notes: Diagnostic MITIA OAJ 2801 2751 2751 2751 1 Well D = Differential Temperature Test Type Inj TVD Tubing Interval P T D Type test Test psi Casing P/F Notes: I OA Well Type Inj I TVD I I Tubingl I Interval P T D. Type test Test psi I Casing P/F Notes: I OA Well Type Inj I TVD I I Tubing 1 11 1 Interval P T D Type test I Test psi I I Casi P/F Notes: I OA Well Type Inj I TVD I I Tubingl I I I Interval P T D Type test I Test psi I Casi P/F Notes: I OA Well Type Inj I TVD I Tubingl I I I I I I Interval P T D Type test I Test psi I I Casi P/F Notes: I OA Well Type Inj I TVD I I Tubing I I I Interval P T.D Type test I Test psi I Casi P/F Notes: I OA Well Type Ini I TVD I I Tubing I I I Interval P T D Type test I Test psi I I Casi P/F Notes: I OA Well Type In'. TVD I Tubing I I Interval P T.D. Type test Test psi I Casing] P/F Notes: I OA Well Type I nj TVD I Tubing Interval P T.D Type test Test psi I Casin P/F Notes: I OA Weill Type I nj I I TVD I Tubing Interval PTD. Type test Test psi I Casing P/F Notes: I OA Well I Typelrij.1 I ND I I Tubingi I I I I I I Interval P T D.1 I Type test I I Testpsi] Casi P/F Notes: I OA Well Type Inj I I TVD I I Tubingl I I Interval P T D.1 I Type testl I Test psil I Casi P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT KRU 2A -27A Diagnostic MITIA 01-15-15 xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) Conoc4illips Alaska, Inc. ;O Reducing, 75 JNDUCTOR, 36120 NIPPLE, 453 SURFACE, 35-3,374 WINDOW NIPPLE, SEAL, PBR, PACKER, INJECTION 7 543 SLEEVE -C. 7,603 WERE, PACKER, NIPPLE, WLEG, 7, KUP SVC 2A -27A Well AttributeIs. Max Angle & MD TD Wellbore API/UWI 501032060401 Field Nam.Wellbore Status Incl (1) MD (RKB) KUPARUK RIVER UNIT SVC 53.08 5,530.87 Act Elm (RKB) 8,017.0 Comment SSSV: NIPPLE 1128 (ppm) I Data Annotation End Dab Last W0: 12/22/2012 KB•Ord (R) 34.00 Rig R.I.- Dab 12/112009 Annotation Depth (RKB) End Data Last Tag: SL. 7,839.0 922013 Annotation Rev Reason: TAG, OPEN CMU last Mod By hipshk( End Data 9/32013 Casing Strings Casing Description CONDUCTOR String 0... String ID ... 20 19.124 Top (ftKB) Set Depth (f... 35.0 1200. Set Depth (TVD) ... 120.0 String Wt... 62.60 String... H-40 String Top Thrd WELDED Casing Description SURFACE String 0... String ID ... 13 3/8 12.412 Top (RKB) Set Depth (f... 34.6 3,374.0 Set Depth (TVD) ... 2,929.1 String Wt... 68.00 String ... L-80 String Top Third TC -II Casing Description INTERMEDIATE Post S/T String 0... String ID ... 95/8 8.835 Top IRKS) Set Depth If 33.3 5,489.9 Set Depth (TVD) ... 4,358.8 String Wt... 40.00 String L-80 String Top Thrd BTCM Cuing Description WINDOW A String 0... String ID ... 9 8.000 Top (RKB) Set Depth If 5,454.0 5,464.0 Sat Depth (TVD) ... 4,343.2 String Wt.. String ... String Top Thrd Casing Description LINER A String 0... Stri7ID ... 7 6.276 Top (RKB) Set Depth (f... 5,240.6 8,015.0 Bet Depth (TVD) ... 6,188.7 String Wt.. 26.00 String _. L-80 String Top Third BTCM Liner Details Top Depth (TVD) Topinel Top (RKB) (RKB) (") Ibm Description Comment Nomi... ID (in) 5,240.6 4,203.4 49.50 PACKER 2RH ZXP w/ HD LINER TOP PACKER 6.160 5,260.9 4,216.51 49.60 HANGER FLEX LOCK LINER HANGER 6.190 Tubing Strings Tubing Description TUBING WO -Upper String 0 15tring ID... 31/2 2.992 ITop (RKB) I Set Depth (f... Sat Depth (TVD) ... 22,3 7,423.1 5,770.8 String Wt... String ... 9.30 L-80 String Top Thrd EUE COMM ion Details Top Depth (TVD) Topinel Top (RKB) (R(B) () Ibm Description Comment N -L.. ID On) 22.3 22.3 -0.01 HANGER FMC 4.5" TUBING HANGER 3.958 75.3 75.3 0.14 XO Reducing XO BUSHING 4.5"x3.5" 3.980 452.8 452.8 0.81 NIPPLE CAMCO DB NIPPLE 2.875 7,357.7 5,724.8 45.55 NIPPLE CAMCO'X' NIPPLE 2.812 7,400.4 5,754.7 45.29 LOCATOR BAKER LOCATOR 2.992 7,401.4 5,755.4 45.28 SEAL ASSY BAKER 80-00 SEAL ASSEMBLY 2.992 Tubing Dw crlption TUBING WO -Lower String 0... St dng ID ... 31/ 2.992 Top (RKB)Set Depth (f... Sat Depth (TVD) ... 7,406.4 7,743.8 5,995.0 String Wt... String... 9.30 1 L-80 [String Top Third EUE Completion Details Top Depth (TVD) Topincl Top (RKB) (RKB) (') It.. Description Comment Nomi...', 10 (in) 7,406.4 5,758.91 45.25 PBR BAKER 80-40 PBR 3.000 7,433.2F5,976.2 45.08 PACKER BAKER PREMIER PACKER 2.670 7,603.4 46.08 SLEEVE -C CMU SLIDING SLEEVE (OPEN 92/13) 2.810., 7,658,0 45.98 PACKER BAKER PREMIER PACKER 2.870 7,716.9 45.72 NIPPLE 2.81" CAMCO XN NIPPLE, NO GO 2.7507,743.1 45.50 WLEG WIRELINE RE-ENTRY GUIDE 2.9921 Perforations & Slots Top (RKB) Ban (f(RKB) ) Btm (TVD) Shot Dens Zone Dab (ah... Type Comment 7,602.0 7,6 5,922.6 C Sand, 2A -27A 12/162012 5.0 IPERF 7,678.0 7,64 A(ftK 5,954.2 A5, 2A -27A 12/162012 5.0 IPERF 7,694.0 7,74 5,970.0 A4, 2A -27A 12/162012 5.0 IPERF 7,720.0 7,74 5,986.0 A3, 2A -27A 12/162012 5.0 IPERF Notes: General & Safety End Date Annotation 12/112009 NOTE: 2A-27 was drilled to cement off 2A-06 w/Perfs, cement squeezed kill string in hole 12222009 NOTE: WELL SIDETRACKED TO'A'-PRE-CTD Mandrel Details Top Depth Top g,,, (TVD) Incl N••• Top (fd(B) 0") r) Malta ODVal. Latch Modal (in) 8.ry Type Type Pon Stas TRO Run (in) (psl) Run Dab Com... 1 7,301.9 5,686.0 45.89 Camoo MMG 1 12 INJ JDMY RK 0.000 0.0 2202013 2 7,484.1 5,814.6 46.28 Cameo MMG-W 1 12 INJ JDMY RK 0.000 0.0 12202012 3 7,543.5 5,855.6 46.18 Camoo MMG-W 1 12 INJ JDMY RK 0.000 0.0 121202012 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Thursday, January 15, 2015 10:22 PM To: Wallace, Chris D (DOA) Cc: NSK Problem Well.Supv; Senden, R. Tyler Subject: 2A -27A (PTD 212-100-0) Report of IA pressure anomaly Attachments: 2A -27A schematic.pdf; MIT KRU 2A -27A Diagnostic MITIA 01-15-15.x1s Chris, Kuparuk produced water injector 2A -27A (PTD 212-100-0) was reported to have an IA pressure drop. The pressure drop may be due to the drop in rate coupled with the slight decline in temperature. Initial diagnostics performed by DHD were a passing MITIA and passing inner casing packoff tests. Following the MITIA, 1000 psi was left on the IA to have a larger differential pressure between the IA and OA for pressure monitoring. It is ConocoPhillips intention to leave the well on water injection for 30 days to monitor the wellhead pressures. A follow up report will be submitted to update the AOGCC with the results. Pending those results the well will continue to remain on normal injection or further diagnostics will be done if IAxOA communication is confirmed. Please let me know if you disagree with this plan. Attached are the wellbore schematic, 90 day TIO plot and the MITIA test results. Well Name 2A -27A Notes: Start Date 10/16/2014 Days 90 End Date 1/14/2015 Annular Communication Surveillance loco VJH P OAP 120 ,L T oocc 100 2ECC Be L 'tA 2000 Q Z ec 1Eco aC loco 20 ECC co Oct -14 Oct-1Oct-14 Nov -14 Nou-14 Nou 14 DeG14 Dea14 De�14 Jan -1E Jan -1E Jan -1E ifMO jai 041 O � a maw.. /wi d- sca aw V „j Oct -14 Oct -14 Oct -14 Nor 14 Nov -14 Nou14 De�14 Dea14 Dea14 Jan -15 Jan -15 Jan -15 Date Brent Rogers I Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 WELLS TEAM Caring Descr KUP SVC ��'w, Co ocoPhfillipsWeil SURFACE Attributesell AIB51G3 Inc.Wre Annotation I/UWI KB•Grd (K)Last 5bo010AP32060401 "'SSSV: Comment NIPPLE Well Conf : DEVIATED - 2A -27A 9/3/2013 3 45 25 PM Schematic-ACNeI 12/22/2012 Annotation Dap HANGER, 22 End DataAnntation Last Tag:SLM 7 Casing Dead CONDUCTOR, Caring Descr 2A -27A & MD TD KUPARUK RIVER UNIT SVG Od.Uts O,DJU.B�Rigftl. SURFACE H25 (ppm) Dab Annotation Casing Descr KB•Grd (K)Last 7,302 INTERMEDI Top Depth WO: 12/22/2012 Post Srr XO Reducing. 75 End DataAnntation Casing Dead CONDUCTOR, Leat Mo,839.0 WINDOW A Ceeing Desel 35-120 7,406.4 5,758.9 45.25 PBR BAKER 80-00 PBR LINER A Liner Del NIPPLE, 453 7,603.4 5,897.2 46.08 SLEEVE -C CMU SLIDING SLEEVE (OPEN 9/2(13) T 7,658.0 5,935.1 45.98 PACKER BAKER PREMIER PACKER String 0... Top KKB) 5,240.6 Set Depth (f... Set Depth (TVD) ... String Wt... — 5,260—.9 String Top Thrd 20 19.124 Tubing 120.0 120.0 62.60 Tubing Desc WELDED String 0... String ID ... Top (ftKB) Sat Depth If Sat Depth (TVD) ... TUBING W( Com let String Top Thrd k 12.412 T SURFACE,_ 35-3,374 ` i 68.00 2A -27A & MD TD KUPARUK RIVER UNIT SVG Od.Uts O,DJU.B�Rigftl. 7,401.4 5,755.4 45.28 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY H25 (ppm) Dab Annotation End Dab KB•Grd (K)Last 7,302 Top Depth WO: 12/22/2012 34.00th(KKB) End DataAnntation (TVD) Topincl Leat Mo,839.0 92/2013 Rev Reason: TAG, OPEN CMUhips 7,406.4 5,758.9 45.25 PBR BAKER 80-00 PBR 7,433.2 5,777.9 45.08 PACKER BAKER PREMIER PACKER 7,603.4 5,897.2 46.08 SLEEVE -C CMU SLIDING SLEEVE (OPEN 9/2(13) 7,658.0 5,935.1 45.98 PACKER BAKER PREMIER PACKER String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 20 19.124 35.0 120.0 120.0 62.60 H-40 WELDED String 0... String ID ... Top (ftKB) Sat Depth If Sat Depth (TVD) ... String Wt... St -ring.. String Top Thrd 133/8 12.412 34.6 3,374.0 2,929.1 68.00 L-80 TC -11 String 0... String ID ... Top (ftKB) Sat Depth (f... Set Depth (TVD) ... String Wt. string Top Thrd 95/8 8.835 33.3 5,489.9 4,358.8 40.00 L-80 BTCM String 0... String ID ... Top (KKB) Sat Depth (f... Set Depth (TVD) ... String Wt... Shing ••• String Top Thud 9 8.000 5,454.0 5,464.0 4,343.2 Strirp 0... String ID ... Top (kK8) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 7 6.276 5,240.6 8,015.0 6,188.7 26.00 L-80 BTCM Toro,nel Non Ing v... er ,n ... , vP I—— ..e. ...y... l.... .......-....... ....o ...... - 31/2 2.992 22.3 7,423.1 5770.8 9.30 L-80 I EUE Peet s/r, 33.5,490 7,401.4 5,755.4 45.28 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY INJECTION, Tubing Description String 0... String ID ... Top (KKB) Sat Depth (f... Set Depth (TVD) ... String W TUBING WO -Lower 3 1/2 2.992 7,406.4 7,743.8 5,995.0 9.30 Com letion Details 7,302 Top Depth (TVD) Topincl Top KKB) (KKB) (o) Item Description Comment NIPPLE, 7,358 7,406.4 5,758.9 45.25 PBR BAKER 80-00 PBR 7,433.2 5,777.9 45.08 PACKER BAKER PREMIER PACKER 7,603.4 5,897.2 46.08 SLEEVE -C CMU SLIDING SLEEVE (OPEN 9/2(13) 7,658.0 5,935.1 45.98 PACKER BAKER PREMIER PACKER 7,716.9 5,976.2 45.72 NIPPLE 2.81" CAMCO XN NIPPLE, NO GO LOCATOR, 7,400 7,743.1 5,994.5 45.50 WLEG WIRELINE RE-ENTRY GUIDE Perforations & Slots SEAL ASSY, 7.-1 Shot PBR, 7,405 Top (TVD) Bt. (rVD) Dans Top (KKB) Btm (KKB) (KKB) (KKB) Zone Data (ah"' Type 7,602.0 7,640.0 5,896.2 5,922.6 C Sand, 2A -27A 12/162012 5.0 (PERF 'ACKER, 7,433 _. _ 7.R7R.6 7.685.0 5.949.4 5.954.2 A5, 2A -27A 12/162012 5.0 IPERF SLEEVE -C, 7,803 (PERF, 7002-7,840 (PERF, 7,8947,708 NIPPLE, 7,717 (PERF, 7.720-7.731 WLEG, 7,743 LINER A. 5,241_8,015 TD (2A -27A), 8,017 12/112009NOTE: 2A-27 was drilled to cement off 2A-06 w/Perfs, cement squeezed kill string In role NI/1TF• WFII CIIirTPAt.KFn Tn'A'-PRF-CTD EUE S...I k B) I Incl I O) I I Valva Latch Sin TRO IR N... Toe INKBI ( ) PI Make MoMI tin 9ary TYPa t ( ) 1pa l Run Dab Com. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: AOGCC.InspectorsCaalaska.gov; phoebe. brooks(&alaska.gov chris.wallace(&alaska.aov OPERATOR: ConocoPhillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / KRU / 2A DATE: 01/15/15 OPERATOR REP: AOGCC REP: Beck / Manjarrez Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I 2A -27A Type In'. I W TVD 5,778' Tubing 2,0101 2,0101 2,0101 2,0101 1 1 Interval O P.T.D. 2121000 I Type test I P Test psi 1500 Casingl 3101 3,0001 2,9601 2,950 P/F I P Notes: Diagnostic MITIA OAI 2801 2751 2751 2751 1 Well I Type Inj.J TVD Tubing Interval P.T.D. Type test Test psi I Casingl I I P/F Notes: I OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing[P/F Notes: I OA Well I I Typelni.1 I TVD I I Tubing I I Interval P.T.D.1 Type test I I Test psi I I Casin P/F Notes: I OA WeIll Type In'. I TVD I Tubingl I I Interval P.T.D.1 Type test I Test psi I Casin P/F Notes: I OA Weill I TypeInj.J TVD I Tubingl Interval P.T.D. Type test Test psi I CasinglP/F Notes: I OA Well I Typelni.1 I TVD I I Tubingl Interval P.T.D. Type test Test psi I CasinglP/F Notes: I OA Well Type In'. TVD I Tubingl I Interval P.T.D. Type test Test psi I Casin P/F Notes: I OA Weill I Typelnj.1 TVD I Tubing I I Interval P.T.D.1 I Type test I Test psi I Casin P/F Notes: I OA WeIll Type In'. I TVD I Tubingl Interval P.T.D.1 I Type test I Test psi I Casin P/F Notes: I OA Weill I Typelnj.1 I TVD I I TubinglInterval P.T.D. Type test Test psi I Casin P/F Notes: I OA Well T e In'. TVD I Tubing Interval P.T.D. Type test Test psi I CasinglP/F Notes: I OA Well Type In'. TVD Tubing Interval P.T.D. I Typetestl Test psi Casing[ P/F Notes: I OA TYPE INJ Codes TYPE TEST Codes D = Drilling Waste M = Annulus Monitoring G = Gas P = Standard Pressure Test I = Industrial Wastewater R = Internal Radioactive Tracer Survey N = Not Injecting A = Temperature Anomaly Survey W = Water D = Differential Temperature Test Form 10-426 (Revised 11/2012) MIT KRU 2A -27A Diagnostic MITIA 01-15-15.xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance O = Other (describe in notes) 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. C�J Q - IQ a Well Histnflle Identifier Organizing (done) vV` "wo-sided R CAN: OVERSIZED: olor Items: 11 ❑ ps: VGrayscale Items: Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Rescan Needed NOTES: ❑ Other: BY: Maria Date: ! p� ` /s/ Project Proofing BY: Maria Date: ` ` /s/ Scanning Preparation BY:T Maria Production Scanning x30= �6 Date: I [ /a + = TOTAL PAGES ( (Count does not include cover sheet) �. /s/ Stage 1 Page Count from Scanned File: U V (Count does include cover et) Page Count Matches Number in Scan7577,14 ration: YES NI/Oj� BY: Maria Date: i 1 /s/ Y Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO 1 BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked filp 7/8/2014 Well History File Cover Page_20140708.doc DATA SUBMITTAL COMPLIANCE REPORT 8/20/2013 Permit to Drill 2121000 Well Name/No. KUPARUK RIV UNIT 2A -27A MD 8028 TVD 6198 Completion Date 12/22/2012 REQUIRED INFORMATION Mud Log No DATA INFORMATION 1 �\ Types Electric or Other Logs Run: GR / RES, CBL Well Log Information: Operator \CONOCOPHILLIPS ALASKA INC Completion Status 1WINJ Current Status 1WINJ Samples No API No. 50-103-20604-01-00 UIC Yes Directional Survey Y%s (data taken from Logs Portion of Master Well Data Maint) Log/ Data Type Electr Digital Dataset Med/Frmt Number Name Log Log Run Scale Media No Interval Start Stop OH/ CH Received Comments ED C Pdf 22110 Plug 300 5600 12/20/2012 Plug Setting Record + Graphics las, tiff ED C Pdf 22111 Perforation 10600 10975 12/20/2012 Perforating Records + Graphics tiff, las Log 22133 See Notes 25 Col 4337 8028 Open 1/14/2013 TVD ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron Log 22133 See Notes 25 Col 5454 6198 Open 1/14/2013 MD ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron ED C Pdf 22133 See Notes 5454 6198 Open 1/14/2013 ROP Rate of Penetration DGR Dual Gamma Ray EWR Electromagnetic Wave Resistivity ALD Azimuthal Lithodensity CTN Compensated Thermal Neutron + Graphics cgm, emf, las, dlis, ver, pdf, tiff ED C Tf 22918 Correlation 7300 7740 Open 1/20/2013 Tubing Correlation 2A- 27A_Correlation_19DEC12_img.tiff ED C Tf 22918 Correlation 7300 7740 Open 1/20/2013 Tubing Correlation 2A- 27A_Corre lation_20DEC 12_img.tiff ED C 22918 Digital Data 7283 7763 1/20/2013 A- Electronic Data Set, Filename: 2A- 27A—Correlation-1 9DEC 12. LAS 27ACorrelation19DEC12.LAS ED C 22918 Digital Data 6724 7724 1/20/2013 Electronic Data Set, Filename: 2A - 27A Correlation 20DEC12.LAS ED C 22925 Digital Data 7207 7515 7/5/2013 A- Electronic Data Set, Filename 2A- 27A—Correlation-1 8DEC 12. LAS 27ACorrelation18DEC12.LAS AOGCC Page 1 of 2 Tuesday, August 20, 2013 DATA SUBMITTAL COMPLIANCE REPORT 8/20/2013 Permit to Drill 2121000 Well Name/No. KUPARUK RIV UNIT 2A -27A Operator CONOCOPHILLIPS ALASKA INC MD 8028 TVD 6198 Completion Date 12/22/2012 ED C 22927 Digital Data ED C 22927 Digital Data ED C 22927 Digital Data Log 22927 Leak Well Cores/Samples Information: Name Interval Start Stop API No. 50-103-20604-01-00 Completion Status 1WINJ Current Status 1WINJ UIC Yes 1/20/2013 Electronic File: 2A-27A_ACE_16DEC12.dlis 1/20/2013 Electronic File: 2A-27A_ACE_16DEC12_img.tiff 1/20/2013 Electronic File: 2A- 27A_CASTM_16DEC12_img.tiff 0 0 2121000 KUPARUK RIV UNIT 2A -27A LOG HEADERS Sample Set Sent Received Number Comments INFORMATION RECEIVJED \ \ Completion Report Y Directional / Inclination Data Y Mud Logs, Image Files, Digital Data Y / NA Core Chips Y / NA Production Test Information Y / NA Geologic Markers/Tops �Y Mechanical Integrity Test Information Y / NA Daily Operations Summary �Y Composite Logs, Image, Data Files Y \ Cuttings Samples Y / NA Core Photographs Y / NA Laboratory Analyses Y / NA COMPLIANCE HISTORY Completion Date: 12/22/2012 Release Date: 8/2/2012 Description Date Comments Comments: VA 4 AA Compliance Reviewed B0 Date: _- AOGCC Page 2 of 2 Tuesday, August 20, 2013 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS'i,,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon[_ Repair well P r Plug Perforations r Perforate (" ' Other ji WI NJ to WAG Alter Casing r Pull Tubing r Stimulate - Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate - Other r Re-enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r Stratigraphic r Service F0 212-100-0 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20604-01 7. Property Designation (Lease Number): 8. Well Name and Number: ADL25570 2A -27A 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8028 feet Plugs (measured) None true vertical 6198 feet Junk (measured) None Effective Depth measured 8017 feet Packer (measured) 75, 7358, 7400, 7406, 7433, 7603 true vertical 6190 feet (true vertical) 75, 5725, 5755, 5759, 5778, 5897 Casing Length Size MD TVD Burst Collapse CONDUCTOR 85 20 120 120 0 0 SURFACE 3339 18.5 3374 2929 0 0 WINDOW A 10 9 5464 4343 0 0 INTERMEDIATE 5457 9.625 5490 4359 0 0 LINER A 2774 8.43 8015 6189 0 0 0 0 0 Perforation depth: Measured depth: 7602-7640,7678-7685,7694-7708,7720-7731 True Vertical Depth: 5896-5923,5949-5954,5960-5970,5978-5986 RECEIVED Tubing (size, grade, MD, and TVD) 3.5, L-80, 7743 MD, 5994 TVD AOS? Packers & SSSV (type, MD, and TVD) XO REDUCING -XO BUSHING 4.5"X3.5" @ 75 MD and 75 TVD `•+C NIPPLE - CAMCO'X' NIPPLE @ 7358 MD and 5725 TVD LOCATOR - BAKER LOCATOR @ 7400 MD and 5755 TVD PBR - BAKER 80-40 PBR @ 7406 MD and 5759 TVD PACKER - BAKER PREMIER PACKER @ 7433 MD and 5778 TVD SLEEVE -C - CMU SLIDING SLEEVE (OPEN 9/2/13) @ 7603 MD and 5897 TVD SSSV= None 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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 4738 837 1430 Subsequent to operation 7658 1807 3123 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r • Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WINJ WAG l.% GINJ r SUSP r SPLUG r- 17. 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A If C.O. Exempt: N/A or Sundry Number required here Contact Bob Christensen/Darrell Humphrey Email n1139ccDconocophillips.com Printed Name Darrell R. Hum hre y Title NSK Production Engineering Specialist Signature Phone: 659-7535 Date 12-141-13 Form 10-404 Revised 10/2012 VL RStMt DEC2013)� Submit Original Only 2A -27A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/18/13 O ened the MI blind and put on MI injection- Well converted to MI injection ConocoPhillipsaMI•i',. Alaska. Inc. ncc%tvll,ps �: _ -_-- Well Crffi '.. DEVIATED -2A -27A 9/32013 3:4525 PM -_--- Schematic -Actual HANGER, 22 - XO Reducing, 75 CONDUCTOR, 35720 NIPPLE,453 SURFACE, 11 L 35-3.374 WINDOW A, 5,454-5,464 INTERMEDIATE Plat SR, 33-5,490 INJECTION, 7,3D2 a NIPPLE, 7,158 LOCATOR, 7,400 SEAL ASSY, 7,401L__.___ _- PBR, 7,406 -- -- PACKER. 7,433 INJECT CI, 7 484 INJECTION, 7.543 SLEEVE -C, 7,603 WERE, 7.602-7,640 PACKER, 7,68 IPERF, 7,678-7,685 WERE, 7,6947,708 NIPPLE, 7,717- I.. IPERF, 7.720.7,731 WLEG. 7,743 - LINER A 5,241-8,015 TD (2A -27A), 8,017 KUP SVC 4 2A -27A .Well Attributes I Max Angle & MD TD Wellbore API/UWI Field Name Wellbore Status Incl I') MD (RKB) 501032060401 KUPARUK RIVER UNIT SVC 53.08 5,530.87 Act Stm(ftKB) 8,017.0 Comment H2S (ppm) Date Annotation End Drte SSSV: NIPPLE Last WO: 12222012 KB -Ord (R) 34.00 Rig Release Daft 12/1120M Annotation Depth (ftKB) End Date Annotation Last Tag: SUM 7,839.0 922013 Rev Reason: TAG, OPEN CMU Last Mod By hipshkf End Drte 9/32013 Casing Strings Casing Description String 0... CONDUCTOR 20 String ID ... 19.124 Top (RKB) 35.0 Set Depth if 120.0 Set Depth (TVD) ... 120.0 String Wt... String ... 62.60 H-40 String Top Thrd WELDED Casing Description String 0... SURFACE 133/8 String ID ... 12.412 Top (RKB) 34.6 Set Depth If 3,374.0 Set Depth (ND) ... 2,929.1 String Wt.. String ... 68.00 L-80 String Top Third TC -II Casing Description String 0... INTERMEDIATE 95/8 Post S/F String ID ... 8.835 Top (RKB) 33.3 Set Depth (f... 5,489.9 Set Depth (TVD)... 4,358.8 String WL.. String ... 40.00 L-80 String Top Thrd BTCM Casing Description String C... WINDOW A 19 String ID.-. 1 8.000 Top (WB) 1 5,454.0 Set Depth (f... 5,464.0 Sat Depth IND)... 4,3432 String WL.. String... String Top Thrd Casing Description String 0... LINER 7 String ID ... 6.276 Top (RKB) 5,240.6 Set Depth (f... 8,015.0 Set Depth (ND) ... 6,188.7 String Wt... String ... 26.00 L-80 String Top Thrd BTCM ner Details Top Depth (ND)Top Incl Top(RKB (RKB) V) Rem Description Comment Nomi... ID (in) 5,240.6 4,203.4 49.50 PACKER 2RH ZXP w/ HD LINER TOP PACKER 6.160 5,260.9 4,216.5 49.60 HANGER FLEX LOCK LINER HANGER 6.190 Tubing Strings Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... TUBING WO -Upper 31/2 2.992 22.3 7,423.1 5,770.8 String Wt... String ... 9.30 L-80 String Top Thrd EUE Com letion Details Top Depth (ND) Top Incl Top (RKB) (RKB) () Item Description Comment Nomi... ID (in) 22.3 22.3 401 HANGER FMC 4.5" TUBING HANGER 3.958 75.3 75.3 0.14 XO Reducing XO BUSHING 4.5"x3.5" 3.980 452.8 452.8 0.81 NIPPLE CAMCO DB NIPPLE 2.875 7,357.7 5,724.8 45.55 NIPPLE CAMCO'X' NIPPLE 2.812 7,400.4 5,754.7 45.29 LOCATOR BAKER LOCATOR 2.992 7,401.41 5,755.4 45.28 SEAL ASSY I BAKER 80-40 SEAL ASSEMBLY 2.992 Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) .- TUBING WO -Lower 31/2 2.992 7,406.4 7,743.8 5,995.0 String Wt... String ... 9.30 L-80 String Top Thrd EUE borripletion Details Top Depth (ND) Top Incl Top IIICB (11111111) (•) Item Description Comment Nomi... ID Qn) 7,406.4 5,758.9 45.25 PBR BAKER 80-40 PBR 3.000 7,433.2 5,777.9 45.08 PACKER BAKER PREMIER PACKER 2.870 7,603.4 5,897.2 46.08 SLEEVE -C CMU SLIDING SLEEVE (OPEN 9/2/13) 2.810 7,658.0 5,935.1 45.98 PACKER BAKER PREMIER PACKER 2.870 7,716.9 5,976.2 45.72 NIPPLE 2.81" CAMCO XN NIPPLE, NO GO 2.750 7,743.1 5.994.5 45.50 WLEG WIRELINE RE-ENTRY GUIDE Perforations &_Slots 2.992 Shot Top (ND) Bt.(TVD) Dens Top (RKB) Btm (WB) (RKB) (RKB) Zone Data (sh••• Type Comment 7,602.0 7,640.0 5,896.2 5,922.6 C Sand, 2A -27A 12/162012 5.0 IPERF 7,678.0 7,685.0 5,949.4 5,954.2 A5, 2A -27A 12/162012 5.0 IPERF 7,694.0 7,708.0 5,960.4 5,970.0 A4, 2A -27A 12/162012 5.0 IPERF 7,720.0 7,731.01 5,978.4 5,986.0 A3, 2A -27A 12/162012 5.0 IPERF W-otelifilliniiiiiii & Safety End Date Annotation 12/112009 NOTE: 2A-27 was drilled to cement off 2A-06 w/Perfs, cement squeezed kill string in hole 12222009 NOTE: WELL SIDETRACKED TOW - PRE -CTD Mandrel Details Top Depth Top 5,,, (ND) Incl OD Valve Latch N... Top(ftKB) tftKB) I') Make Model (in) SON Type Type _ Pori Size TRO Run (in) (Psi) Run Date Com... 1 7,301.91 5,686.0 45.89 Camp MMG 1 12 INJ DMY RK 10.000 0.0 2202013 2 7,484.11 5,814.6 46.28 Cameo MMG-W 1 12 INJ DMY RK 0.000 0.0 12202012 3 7.543.51 5,855.6 46.18 Cameo MMG-W 1 12 INJ DMY RK 0.000 0.0 12202012 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2A -27A Run Date: 9/26/2013 DATA L GED Co / 12013 M K BENDER October 15, 2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. - L�.'L - -- J Matthew Cook, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 2A -27A -- Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20604-01 Injection Profile Log 1 Color Log 50-103-20604-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Signed: ' r` MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, August 20, 2013 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2A -27A KUPARUK RIV UNIT 2A -27A Src: Operator Well Name KUPARUK RIV UNIT 2A -27A API Well Number 50-103-20604-01-00 Inspector Name: Jeff Jones Permit Number: 212-100-0 Inspection Date: 4/5/2013 Insp Num: MITOP000004316 Rel Insp Num: mttJJ130416142021 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2A -27A Type Inj W TVD 5778 IA 1185 2840 2790 2780 —1 TD L 2121000 Type Testi sPT Test psi 1500 OA 265 379 362 350 IntervalInitial Test p�F Pass Tubing 2101 2100 2095 2107 Notes: Tuesday, August 20, 2013 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 17, 2013 TO: Jim Regg � P.I. Supervisor hC�lj li t� SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 2A -27A FROM: Jeff Jones KUPARUK RIV UNIT 2A -27A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry , jF NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2A -27A API Well Number 50-103-20604-01-00 Inspector Name: Jeff Jones Permit Number: 212-100-0 Inspection Date: 4/5/2013 Insp Num: mitJJ130416142021 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2A -27A W 5935 - 1185 2840 2790 2780 1 Well Type Inj ITVD IA PTD '--- - 2121000 Type TestSPT �,'I`CSt psi! 1500 - OA 265 379 i 362 350 Interval 'INiTAL _ — PIF -1 P Tubing 2101 2100 -_ 2095 —�_ 2107 -- — Notes: 2.8 BBLS diesel pumped l well inspected, no exceptions noted Wednesday, April 17, 2013 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned ❑ Suspended ❑ 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑✓ - WAG ❑ WDSPL ❑ Other ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service El' Stratigraphic Test ❑ 2 Operator Name. ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: December 22, 2012 12 Permit to Drill Number: 212-100/. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: December 9, 2012 13. API Number: 50-103-20604-01 4a. Location of Well (Governmental Section): Surface: 476' FSL, 227' FWL, Sec. 13, T11 N, R8E, UM • Top of Productive Horizon: 292' FNL, 1533' FWL, Sec. 23, T1 IN, R08E, UM Total Depth 62' FN L, 1339' FWL, Sec. 23, T11 N, R08E, UM 7 Date TD Reached: December 10, 2012 ' 14. Well Name and Number 2A -27A - 8. KB (ft above MSL): 119' RKB , GL (ft above MSL): 92 AMSL. 15. Field/Pool(s): Kuparuk River Field - Kupuruk River Oil Pool 9 Plug Back Depth (MD + TVD). 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 498621 y- 5959898 Zone- 4 • TPI: x- 494648 y- 5959131 Zone -4 Total Depth: x- 494454 - 5959361 Zone -4- 10. Total Depth (MD + TVD): 8028' MD / 6198' TVD • 16. Property Designation - ADL 25570 11 SSSV Depth (MD + TVD)- landing nipple @ 453' MD / 453' TVD 17. Land Use Permit: 2668 18. Directional Survey: Yes ❑� . No 1-1 (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore. N/A (ft MSL) 20. Thickness of Permafrost MD/TVD: 1524' MD / 1500' TVD ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25 071): GR/Res, CBL 22. Re-drill/Lateral Top Window MD/TVD 5454' MD / 4337' TVD 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT. GRADE TOP BOTTOM SETTING DEPTH TVD OLE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 62.5# H-40 35' 154' 35' 154' 42" 12 cu yds AS 1 13.375" 68# L-80 34.6' 3374' 34.6' 2930' 16" 530 sx AS Lite, 390 sx LiteCRETE 9.625" 40# L-80 33' 5490' 33' 4359' 12.25" 678 sx Class G 7" 26# L-80 5241' 8015' 4203' 6189' 1 8.75" 1590 sx Class G 24. Open to production or injection? Yes ❑ No ❑✓ If Yes, list each Interval open (MD+TVD of Top & Bottom; Perforation Size and Number), ` 7602'-7640' MD 5896'-5923' TVD ' 7678'-7685' MD 5949'-5954' TVD - 7694'-7708' MD 5960'-5970' TVD -7720'-7731' MD 5978'-5986' TVD Z r 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 7744' 5241' MD / 4203' TVD, 7433' MD/ 5778' TVD, - 7658' MD / 5935' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No 0 ' DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED cement retainer @ 5483' FiraEIV EEO 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 Test Period -> OIL -BBL GAS -MCF WATER -BBL CHOKE SIZEGaS-OIL RATIO Flow Tubing Press. Casing Pressure Calculated 24 -Hour Rate -> OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (torr) 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 21. Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071 RBDMS JAN 2 8 2014 NONE Form 10-407 Revised 10/2012 CONTINUED ON REVERSE C ✓Y v 1// 2113 Submit original only I t� '9. GEOLOGIC MARKERS (List all formations and r s encountered) 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes ❑� No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Top ground surface ground surface Permafrost - Bottom 1524' 1500' needed, and submit detailed test information per 20 AAC 25.071. Kuparuk C 7602' 5896' Kuparuk A 7671' 5944' N/A Formation at total depth: Kuparuk C 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic, final directional survey 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265-1487 Email: Haibin.Guo(cDconocoohillips. com Printed Name G. Alvord Title: Alaska Drilling Manager - '^ 0) 1 12-0 13 Signature Phone 265-6120 Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 WINDOWA, 5.M�._. ITERE SATE E / Post SR Post S, ---- 33-5,490 INJECTION, 7.302 NIPPLE, 7,358 SEAL ASSY, 7.401 L_ POR, 7,408 PACKER, 7,433 INJECTION, 7.484 INJECTION, 7,543 SLEEVE, 7,603 IPERF, 7,602-7.640 PACKER. 7.658 IPERF, 7,678-7,685 IPERF, 7.694-7.708 NIPPLE, 7,717 IPERF, 7,720-7,731 WLEG, 7.743 LINER A, 5,241-0,015 TO (2A -27A), 8,017 w ........s .,�a,...r...... .......e a ,"" ' 7.'.,.,,r „�...oP.,, 1,... „e. ,.eP.,, ,,,P .,.,,. TUBING WO -Lower 3 1/2 2.992 7,406.4 7,743.8 5,995.0 9.30 L-80 EUE Completion Details Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (°) I Item Description Comment ID (in) Perforations & Slots KUP 2A -27A ,re , e ` COtlOCO�IIlfipS Well Attributes Dene Top (ftKBI Stm(ftKB) (RKB) Max Angle & MD TD AlaSlta hy; Wellbore APVUWI Field Name 5.0 IPERF Well Status Incl (°) MD (ftKB) Act at. (ftKB) 5.0 IPERF 501032060401 KUPARUK RIVER UNIT SVC 53.08 5,530.87 8,017.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Oak ••• SSSV:NIPPLE Last WO: 1222/2012 34.00 12/11/2609 Well Conr' DEVIATED -2A-27A Ill 5120139'. 04'.15 AM Scnematic -Actual Annotation Depth(ftKB) End Date Annotation Last Mod ... End Date _ Last Tag: ReV Reason: SIDETRACKED TOW, WORKOVER osborl 1 1/15/2013 HANGER, 22 Casing Strings Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd CONDUCTOR 20 19.124 35.0 120.0 120.0 62.60 H-40 WELDED ..,.. ._ Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String WL.. String ... String Top Thrd SURFACE 133/8 12.412 34.6 3,374.0 2,929.1 68.00 L-80 TC -II Casing Description String O... String ID ... Top(Id(B) Set Depth (f Set Depth (TVD) String WL.. String... String Top Thrd L INTERMEDIATE 9518 8.835 33.3 5,489.9 4,358.8 40.00 L-80 BTCM Post S/T Casing Description String 0... String ID ... Top (ftKB) Set Depth If... Set Depth IWO) — String Wt... String ... String Top Thrd KO Reducing. _ WINDOWA 9 8.000 5,454.0 5,464.0 4,343.2 75 _ Casing Description String 0... String ID ... Top (ftKB) Set Depth if Set Depth (WD) ... String Wt... String ... String Top Thrd CONDUCTOR. 35-120 LINER 7 6.276 5,240.6 8,015.0 6,188.7 26.00 L-80 BTCM Liner Details Top Depth . NIPPLE. 453 - -- (WD) Top Incl Nomi. Top (ftKB) (ftKB) (°) Item Description Comment ID (in: 5,240.6 4,203.4 49.50 PACKER 2RH ZXP w/ HD LINER TOP PACKER 6.16 5,260.9 4,216.5 49.60 HANGER FLEX LOCK LINER HANGER 6.19 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Deplh (f... Set Depth (WD) ... String IN String ... String Top Thrd TUBING WO -Upper 3 1/2 2.992 22.3 7,423.1 5,770.8 9.30 L-80 EUE ,Completion Details Top Depth SURFACE,_ - (WD) Top In I Nomi. 35FACE Top (RKB) (ftKB) Item Description Comment ID (in; WINDOWA, 5.M�._. ITERE SATE E / Post SR Post S, ---- 33-5,490 INJECTION, 7.302 NIPPLE, 7,358 SEAL ASSY, 7.401 L_ POR, 7,408 PACKER, 7,433 INJECTION, 7.484 INJECTION, 7,543 SLEEVE, 7,603 IPERF, 7,602-7.640 PACKER. 7.658 IPERF, 7,678-7,685 IPERF, 7.694-7.708 NIPPLE, 7,717 IPERF, 7,720-7,731 WLEG, 7.743 LINER A, 5,241-0,015 TO (2A -27A), 8,017 w ........s .,�a,...r...... .......e a ,"" ' 7.'.,.,,r „�...oP.,, 1,... „e. ,.eP.,, ,,,P .,.,,. TUBING WO -Lower 3 1/2 2.992 7,406.4 7,743.8 5,995.0 9.30 L-80 EUE Completion Details Top Depth (TVD) Top Incl Top (ftKB) (ftKB) (°) I Item Description Comment ID (in) Perforations & Slots Shot Top (TVD) Bt. (TVD) Dene Top (ftKBI Stm(ftKB) (RKB) (ftKB) Zone Date (5-h... Type Comment 7,602.0 7,640.0 5,896.2 5,922.61C Sand, 2A -27A 12116/20121 5.0 IPERF 7,678.0 7,685.0 5,949.4 5,954.21A5, 2A -27A 12115120121 5.0 IPERF 7,694.0 7,708.0 5,960.4 —5,970.01A4, 2A -27A 12/16120121 5.0 IPERF was IStnl Top(RKB)I ITV 8) I I(") I Make I Model I DID I l ) Sery I Type Type (in) IT(psi) Run Date ICom...I Conoco hillips Time Log & Summary WeRview Web Repo�dpg Report Well Name: 2A-27 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 12/2/2012 9:00:00 PM Rig Release: 12/22/2012 3:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/01/2012 24 hr Summary Move Rig & Camp f/ 3C-11 t/ 2A-27, spot rig and R/U, rig accepted @ 2100 hrs. R/U t/ displace freeze protect. 00:00 02:30 2.50 MIRU MOVE MOB P Move pipe sheds & rock washer, move & stage complexes on pad. 02:30 08:30 6.00 MIRU MOVE MOB P Move complexes f/ 3C-11 t/ 2A pad 08:30 09:00 0.50 MIRU MOVE MOB P Pull sub off of 3C-11 09:00 12:00 3.00 MIRU MOVE MOB P Move sub & pipe sheds f/ 3c pad t/ 2A pad 12:00 1600 4.00 MIRU MOVE MOB P Spot sub over 2A -27A, spot pipe sheds, power pack & rockwasher 16:00 21:00 5.00 MIRU MOVE MOB P Work on rig acceptance, simops move camp f/ 3C pad t/ 2A pad. Rig accepted @ 2100 hrs 21:00 00:00 3.00 SLOT WHDBO RURD P Install secondary IA valve, R/U circ lines in cellar, simops spot tiger tank & hook up hard lines. 12/02/2012 Pull BPV, R/U cellar lines attempt t/ Displace freeze protect, VR plugs in IA, Pull VR plugs displace freeze protect, OWFF f/ 30 min well static, Set TWC N/D tree & adaptor flange, N/U BOP & riser, Change rams, & saver sub, Rig up and test BOPE 00:00 03:30 3.50 0 0 SLOT WELCTL RURD P Continue R/U hardlines t/ choke house & tiger tank, Simops take on sea water to pits, test lines U tiger tank t/ 2500 psi, test Mud pumps t/ 3500 psi, Pull BPV 03:30 05:30 2.00 0 0 SLOT WELCTL CIRC P Attempt t/ displace freeze protect unable t/ pump, VR plugs still in Both IA valves. 05:30 07:15 1.75 0 0 SLOT WELCTLOTHR P R/U & pull VR plugs 07:15 08:30 1.25 0 0 SLOT WELCTL CIRC P Displace freeze protect @ 210 gpm 450 psi, to tiger tank, pump 220 bbls 8.5 ppg sea water. 08:30 09:30 1.00 0 0 SLOT WELCTL OWFF P Blow down lines observe well for flow f/ 30 min, well static. 09:30 10:30 1.00 0 0 SLOT WELCTL OTHR P Set TWC test t/ 1000 psi in direction of flow & f/ top down. 10:30 12:00 1.50 0 0 SLOT WHDBO NUND P Nipple down tree & adaptor flange. 12:00 12:15 0.25 0 0 SLOT WHDBO OTHR P Inspect threads on hanger & prep 9 5/8 casing spool 12:15 14:15 2.00 0 0 SLOT WHDBO NUND P Nipple up adaptor flange & BOP, Riser & flow lines. 14:15 17:45 3.50 0 0 SLOT WHDBO NUND P Change rams in upper and lower cavities t/ 3.5 x 6 in upper and 2 7/8 x 5 in lower rams. Simops C/O saver sub. Page 1 of 22 Ne Time Logs Dae From To Dur S. De th E. De th Phase Coe Subcode T Comment 17:45 20:30 2.75 0 0 SLOT WHDBO RURD P Clear Floor R/U U test BOP'S, R/U test equipment. (OA Pressure was 280 psi and bled down to zero) 2030 00:00 3.50 0 0 SLOT WHDBO BOPE P Test BOPE with 4.5" test joint to 250 / 3500 psi and record on chart. Test # 1: Upper 3.5 x 6" VBR, Choke valves 1, 12, 13, 14 & manual kill valve. Test # 2: Upper IBOP, HCR kill, choke valves 9 & 11. Test # 3: Choke valves 5, 8 & 10. Test # 4: Choke valves 4, 6 & 10. Test # 5: Choke valve 2 (Lower IBOP failed several attempts) Test # 6: HCR choke & 4" kill line demco valve. (Test witness waived by AOGCC John Crisp 12/03/2012 Continue testing BOP's, M/U landing jt pull hanger U rig floor, Pull Kill string out of hole total recovered 2068', bullhead 60 bbls 9.6 ppg brine down OA, OWFF, flowing, Bullhead 35 bbls 8.6 ppg sea water down OA, OWFF 00:00 03:30 3.50 0 0 SLOT WHDBO BOPE P Continue testing BOP's test all rams ann. & choke valves 1-14 t/ 250/3500 accumulator test, (Test witness waived by John Crisp) 03:30 04:00 0.50 0 0 SLOT WHDBO OTHR P Blow down lines choke & kill R/D test equip. 04:00 04:45 0.75 0 0 SLOT RPCOM OTHR P Drain stack pull TWC 04:45 06:00 1.25 0 0 SLOT RPCOM RURD P R/U t/ pull kill string, M/U landing jt. BOLDS 06:00 06:45 0.75 0 2,318 SLOT RPCOM PULL P Pull hanger t/ rig floor monitor well static 06:45 10:30 3.75 2,318 0 SLOT RPCOM PULL P L/D 4.5 kill string 66 jts. X nipple mule shoe total length pulled 2068'. 10:30 12:00 1.50 0 0 SLOT RPCOM RURD P R/D tubing equipment, clear floor. 12:00 13:00 1.00 0 0 SLOT RPEQPI OTHR P Mix 60 bbls of 9.6 ppg brine. 13:00 13:45 0.75 0 0 SLOT RPEQPI CIRC P Bullhead 60 bbls of 9.6 ppg brine down OA 126 gpm 1200 psi broke over @ 1100 psi 13:45 1500 1.25 0 0 SLOT RPEQPI OWFF P Bleed off and Monitor well, 13.7 bbls back. 15:00 16:30 1.50 0 0 SLOT RPEQPI OWFF P Observe well for flow well folwing back @ 1.15 bph slowed t/.7 bph no change 16:30 17:00 0.50 0 0 SLOT RPEQPI CIRC P Bullhead 35 bbls 8.6 sea water down OA @ 84 gpm 1050 psi broke over , 1050 psi. 17:00 00:00 7.00 0 0 SLOT RPEQPI OWFF P Observe well for flow, 20.4 bbls back in 7 hours, flow decreased to .29 BPH, SIMOPS work on MP2's clean and organize rig. 2/04/2012 Monitor OA till 14:00 hrs (flow down to .14 bph) R/U to lubricate and bleed as per -schedule, R/U and test BOPE with 5" test Jt., Set wear ring, Cont. lube & bleed, M/U scraper BHA with upper mill 8-3/4" OD, would not past pack -off inner lip, call town, LID upper mill and RIH with scraper and P/U 5" dp from shed. Page 2 of 22 Ne Time Logs Date From To Dur S. DeDth E. De th Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 SLOT RPCOM OWFF P PJSM, Monitor OA flowing back @ .27 bph, SIMOPS scrub rig, work on MP2's, Flow rate slowed to .14 bph in 12 hrs. 12:00 14:00 2.00 0 0 SLOT RPCOM KLWL P MONITOR WELL, FLOW DN TO 0.15 BHP 14:00 16:30 2.50 0 0 SLOT RPCOM KLWL P R/U LINES F/ LUBRICATE & BLEED W/ 10 BBL WEIGHTED SEA H2O @ 2 BPM DN OA. 1150 PSI BROKE OVER, SHUT IN & WAIT 30 MIN PRESSURE HELD @ 600 PSI, BLEED OFF F/ 15 MIN, SHUT IN & MONITOR PRESSURE F/ 15 MIN, GAINED 15 PSI, BULL HEAD ADDITIONAL 10 BBL. BROKE OVER W/ 950 PSI. SIMPOPS P/U & RACK BACK 3 STDS OF 6 3/4 DC & 1 STD HWDP. 16:30 17:15 0.75 0 0 SLOT RPCOM BOPE P R/U TEST EQUIP. & 5" TEST JT 17:15 18:30 1.25 0 0 SLOT RPCOM BOPE P BOPE TEST: LWR 2 7/8x5" VBR, UPPER 3 5x6" VBR & ANNULAR W/ 5" TEST JT TO 250/3500 PSI F/ 5 MIN EA. 18:30 18:45 0.25 0 0 SLOT RPCOM BOPE P R/D TEST EQUIP. 18:45 19:00 0.25 0 0 SLOT RPCOM OTHR P SET WEAR BUSHING, ID 12 7/16" 19:00 19:30 0.50 0 0 SLOT RPEQPI OWFF P CONT. LUBE & BLEED SCHEDULE 19:30 21:15 1.75 0 0 SLOT RPEQPI PULD P PJSM, M/U SCRAPER ASSY. 8.75" OD STRING MILL TAGGED UP ON PACKOFF INNER LIP (8.77 ID), P/U AND RACK BACK STAND OF DC's, REGAUGE STRING MILL (GOOD) 21:15 22:45 1.50 0 0 SLOT RPEQPI PULD T P/U SINGLE HWT AND M/U TOP DRIVE WAIT ON ORDERS. 22:45 00:00 1.25 0 125 SLOT RPEQPI PULD T L/D SINGLE AND STRING MILL & RIH WITH SCRAPER bha # 2 TO 125' and 12/05/2012 Cont. RIH P/U singles with scraper BHA T/ 6687' MD, swap well over to 8.5 ppg sea water, spot 95 bbls 9.0 corrosion inhibitor brine, POOH, L/D scraper, R/U & pull 9 5/8 pack -off found seals damaged, M/U Baker swedge and drift top of stub no issues, attempt setting new pack -off, no go, wait on new pack -off, wash around stub & vac out around stub. 00:00 00:30 0.50 125 769 SLOT RPCOM OWFF P PJSM - CONT. M/U BHA T/ 769' MD. PUMP 9.6 PPG KWF DOWN OA EVERY 1.5 HRS @ 2BPM, 900 PSI, SHUT IN F/ 0.5 HR BLEED OFF F/ 15 MIN, TAKE READINGS X3. OPEND OA T/ TRIP TANK AND MONITORED 6.7 BBL GAIN. 00:30 06:30 6.00 769 5,500 SLOT RPCOM TRIP P CONT. SINGLE IN HOLE W/ SCRAPER ASSEMBLY T/ 5500'MD, P/U=150K, S/0=100K 06:30 07:30 1.00 5,500 5,400 SLOT RPCOM CIRC P BREAK CIRC@ 5500'MD, ROT/RECIP T/ 5400'X 3, PUMP 550 GPM, 1800 PSI, ROT 30 RPM, TQ=5-6K, ROT WGHT=126K. Page 3 of 22 Time Logs Dae From To Dur S. De th E. De th Phase Code Subcode T Comment 07:30 09:00 1.50 5,400 6,604 SLOT RPCOM TRIP P BD TD, CONT RIH T/ 6604'MD, P/U=150K, S/0=100K . CAL DISP=70.1 BBL, ACTUAL=70.6 BBL 09:00 10:00 1.00 6,604 6,687 SLOT RPCOM WASH P BREAK CIRC. WASH T/ 6661'MD @ 2BPM, 150 PSI HIT FILL @ 6661' MD. INCREASE PUMP T/ 500 GPM, WASH T/ 6687' MD TAG TOC.WOB 2-10K, TAG CMT 3 TIMES. P/U=170K, S/O=115K 10:00 10:45 0.75 6,687 6,687 SLOT RPCOM CIRC P CBU@500 GPM, 1700 PSI. RECIP PIPE. 10:45 12:00 1.25 6,687 6,687 SLOT RPCOM CIRC P PJSM - DISPLACE WELL OVER T/ CLEAN 8.5 SEA H2O @ 6 BPM, 900 PSI, RECIP PIPE. 12:00 13:00 1.00 6,687 6,687 SLOT RPCOM CIRC P CONT. DISP. WELL W/ CLEAN 8.5PPG SEA H20@ 14 BPM 2000 PSI, PUMP 90 BBL 9.0 PPG CORROSION INHIB. PILL @ 4.5 BPM 200 PSI & SPOT W/ 92 BBL OF CLEAN SEA H2O. 13:00 13:15 0.25 6,687 6,657 SLOT RPCOM OWFF P PULL STD & OBSERVE FLUID DROP IN HOLE, BLOW DN T/D & MONITOR WELL (STATIC). 13:15 16:45 3.50 6,657 57 SLOT RPCOM TRIP P POOH F/ 6600'& L/D SCRAPER ASSY. FILL F/ TRIP =ACT 68.15 BBL, CALC 66.79 BBL 16:45 17:15 0.50 57 0 SLOT RPCOM OTHR P PULL WEAR BUSHING 17:15 18:30 1.25 0 0 SLOT RPCOM OTHR P M/U PACKOFF RETRIVAL TOOL & PULL PACKOFF W/ 25K O/P, PULL TO FLOOR & INSP. SIGNIFICANT SEAL DAMAGE 18:30 20:30 2.00 0 0 SLOT RPCOM OTHR P WAIT ON BOT SWEDGE, SIMOPS CLEAN FLOOR, SERVICE RIG 20:30 21:00 0.50 0 0 SLOT RPCOM PULD P P/U BOT SUBS 21:00 21:15 0.25 0 0 SLOT RPCOM OTHR P M/U 8 3/4" SWEDGE ON SINGLE & DRIFT TOP OF CSG STUB (GOOD). 21:15 21:45 0.50 0 0 SLOT RPCOM PULD P L/D BOT SUBS. 21:45 22:15 0.50 0 0 SLOT RPCOM OTHR T PJSM, ATTEMPT TO SET NEW PACK-OFF W/30K X 2 WITH NO SUCCESS, PULL TO FLOOR & INSPECT AND FOUND DAMAGE SEALS. 22:15 00:00 1.75 0 0 SLOT RPCOM OTHR T PJSM, ATTEMPT TO SET NEW PACKOFF NO GO, ELVAUATE OPTIONS, WAIT ON NEW PACK-OFF, OBSERVED SLUDGE AND SAND AROUND OUTSIDE OF STUB CLEAN OUT WITH VAC & RINSE, FILL STACK WITH SEA WATER, OBSERVED CASING SPOOL PLUGGED OFF BETWEEN IA & OA, CONT. ATTEMPT TO ESTABLISH COMMUNICATIONS BETWEEN ANNULUS WITH PACK-OFF OUT. Page 4 of 22 Time Logs Date From To Dur S. Depth E. Depth Phase Code Su c de T Comment 2/06/2012 24 hr Summary Continue flush & clean casing stub. Install new 9 5/8" packoff, RILDS and test same to 2470 PSI. Install Wear bushing - ID = 12 7/16". Test casing to 1500 PSI - 30 minutes on chart. Good test. Pump 10 BBLS of 8.6 PPG seawater down OA at 2 BPM - 880 PSI. Continue freeze protect OA with diesel with LRS pumping 90 BBLS diesel at 1.25 BPM - 950 PSI. FCP = 800 PSI. Make dummy run with 8.75" OD string mill. Slip & cut Drilling line. RU HES wireline crew and wireline in hole with 9 5/8" K-1 Cement retainer. Correlate & set retainer 6' from collar at 5483' WLM. WLOH, RD HES. Test casing & Plug to 2500 PSI, 30 min on chart. Good test. Held PJSM Make up 9 5/8" whipstock assembly, orient whipstock face to high side at 45° R, MU BHA, and TIH. Pulse test MWD. Continue trip in hole at 2 minutes / stand. 00:00 02:15 2.25 0 0 MIRU RPCOM SEQP P Continue flush and clean 9 5/8" casing stub. Make a dummy run with old packoff. Observed when running new packoff, damaged seals. Install new packoff as per FMC rep. Set down 30K to verify set and located. 02:15 03:00 0.75 0 0 MIRU RPCOM SEQP P RILDS. Rig up and test 9 5/8" packoff to 2470 PSI, 10 minute test witnessed by Co. Rep. Good test. 0300 03:30 0.50 0 0 MIRU RPCOM OTHR P Install wear bushing. ID = 12 7/16". RILDS. 03:30 04:30 1.00 0 0 MIRU RPCOM PRTS P Rig up, and test casing to 1500 PSI. 30 minutes on chart - good test. 04:30 05:00 0.50 0 0 MIRU RPCOM OTHR P Rig up and pump 10 BBLS of 8.5 PPG seawater down OA at 2 BPM - 880 PSI 05:00 0530 0.50 0 0 SLOT RPCOM OTHR P Make up 8 4/4" OD string mill. RIH to 35' with no issues through packoff and casing stub. POOH lay down mill. 05:30 05:45 0.25 0 0 SLOT RPCOM SVRG P Held PJSM. Dicuss safety & hazard recognition issues. Discuss rocedure to slip & cut drilling line. 05:45 07:30 1.75 0 0 SLOT RPCOM SVRG P Slip & cut 42' of drilling line. Service top drive and drawworks. Inspect brakes. 07:30 08:00 0.50 0 0 SLOT RPCOM FRZP P Spot Little Red services. Held PJSM Rig up lines. 08:00 09:00 1.00 0 0 SLOT RPCOM FRZP P Load and test lines to 2500 PSI. Pump 90 BBLS of diesel down OA at 1.25 BPM. ICP = 950 PSI. FCP - 800 PSI. Shut in PSI on OA - 660 PSI. Held PJSM - SIMOPS mtg with HES wireline crew and BOT rep. Spot HES E -line unit. 09:00 10:45 1.75 0 0 SLOT RPCOM PACK P Hang sheaves, and rig up e -liners. Make up BOT K-1 Wireline set cement retainer on wireline. 10:45 11:15 0.50 0 0 SLOT RPCOM PACK P WLIH with retainer to 500'. Observed CCL not working. POOH. 11:15 12:00 0.75 0 0 SLOT RPCOM PACK T Trouble shoot tool string. Could not fiind any issues with the tool. Crew change 12:00 13:15 1.25 0 0 SLOT RPCOM PACK P WLIH with tools string to correlate. Observed CCL working good. Log to correlate casing collar depths. Locate & set cement retainer at 5483' WLM, 6' above collar. Page 5 of 22 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 1315 14:00 0.75 0 0 SLOT RPCOM PACK P �WLOH, and rig down HES wireline crew and equipment. 14:00 14:45 0.75 0 0 SLOT RPCOM PRTS P Rig up lines, and pressure test casing and plug to 2500 PSI. 30 Minutes on chart - good test. 1445 15:15 0.50 0 0 SLOT RPCOM SFTY P Held PJSM with crew, Sperry Sun and BOT reps. Discuss safety and hazard recognition issues. Discuss procedure to make up 9 5/8" whipstock assembly. 15:15 17:00 1.75 0 0 SLOT RPCOM PULD T Make up 9 5/8" whipstock assembly with flex joint as per BOT and Sperry reps. Orient MWD to whipstock face with offset at 238.96 Deg. 17.00 18:15 1.25 0 950 SLOT RPCOM PULD P Make up remaining BHA with Drill collars and HWDP. Total BHA length with whipstock - 832.35'. Make up one stand of 5" drill pipe. 18:15 18:30 0.25 950 950 SLOT RPCOM TRIP P Screw into top drive and perform pulse test on MWD assembly. Pumps at 350 GPM - 500 PSI. Good test. 18:30 21:45 3.25 950 5,450 SLOT RPCOM TRIP P Continue trip in hole with whipstock assembly at 2 minutes / stand as per BOT rep. Observed proper displacement. 21:45 22:15 0.50 5,450 5,476 SLOT RPCOM WPST P Screw into top drive. Pumps at 350 GPM's- 650 PSI. Orient whipstock face to 45 deg right of high side as per plan. Slack off to tag wireline set plug at 5476'. Set down to shear bolt at 35K. Work string to verify free of whi stock. Top of whipstock - 5454' 22:15 23:30 1.25 5,454 5,454 SLOT RPCOM CIRC P Position window mill above whipstock. Held PJSM with crew - discuss safety & hazard recognition issues. Discuss procedure to complete displacement and mill window, and displace well with 9.5 PPG milling fluid with 1.25% lube. Pumps at 400 GPM's - 780 PSI. Obtain SRPs @ 5454' MD, TVD 4335'MD MWT 9.5 23:30 00:00 0.50 5,454 5,454 SLOT RPCOM WPST P Begin milling window at 5454' MD, Mill with 90RPM's, WOB - 2 K Torque= 5/10 K GPM= 420, Pressure= 900. Observed good metal cuttings in returns. Pump super sweeps as needed. 2/07/2012 Finish milling window, mill new hole to 5480' circ & cond due to air in mud, take on another 100 bbls new milling mud and blend in system, cont milling new hole to 5493' MD, pull back to 5440' MD and perform leak off test broke over @ 1250 psi, POOH & UD mills, Mills in gage, M/U stack washer and flush out BOP's 00:00 06:00 6.00 5,454 5,471 SLOT RPCOM OTHR P PJSM, Mill window F/ 5454'T/ 5471' MD, 120 SPM, 490 GPM, 1000 psi, RPM=100, TQ= 2-14K, WOB= 4-8K, pump 20 bbl super sweep @ 5459' MD, Recovered 400 lbs of metal Page 6 of 22 Time Logs Dae From To Dur S. De th E. De th Phase Code Subcode T Comment 06:00 09.45 3.75 5,471 5,480 SLOT RPCOM OTHR P Cont. milling through window with upper mil and drill new hole T/ 5480' MD, @ 400 gpm, 800 psi, 100 RPM, TQ= 6K, WOB= 10-25K, attempt different drilling parameters due to slow ROP. 09.45 11:00 1.25 5,480 5,450 SLOT RPCOM CIRC P Pulled back to 5450' MD, circ & cond mud, aired up mud, 6.5 bpm 270 m, 350 psi. 11:00 12:00 1.00 5,450 5,450 SLOT RPCOM OTHR P Take on 100 bbl of new 9.5 ppg mill fluid & blend in system. 12:00 16:30 4.50 5,450 5,493 SLOT RPCOM OTHR P Cont. milling new hole F/ 5480' T/5493' MD, RPM=120, 450 gpm, 1125 psi, WOB= 25K, Tq= 8K, pumped 20 bbl super sweep, P/U & ream through window x 4, x 2 with no rotation or pump. 16:30 17:00 0.50 5,493 5,440 SLOT RPCOM TRIP P Rack back stand to 5440' MD & blow down Top Drive, R/U head pin and cement line for FIT. 17:00 17:30 0.50 5,440 5,440 SLOT RPCOM LOT P Preform leak -off test with 1 bpm, broke over @ 1250 psi, pumped 6 bbl total, shut in & held for 10 min 1100 psi final pressure. 17:30 18:00 0.50 5,440 5,440 SLOT RPCOM OWFF P R/D lines and monitor well. (Static) 18:00 23 00 5.00 5,440 0 SLOT RPCOM TRIP P PJSM, POOH with milling BHA F/5440' MD T/4050' MD, pumped dry job, cont POOH to suface and UD BHA. Act= 60.94 bbl, Calc= 56.97 bbl. 23:00 23:15 0.25 0 0 SLOT RPCOM OTHR P Clean and clear rig floor. 23:15 00:00 075 0 0 SLOT RPCOM OTHR P M/U stack washer and flush out BOP's with 20 bpm 100 psi. 2/08/2012 P/U and run magnet BHA to 5493' MD. Displace 9.5ppg milling fluid with 9.6ppg LSND mud; monitored static well. POOH. P/U and run drilling BHA T/ 2425' Service Top Drive, Continue TIH T/ 5389' Oreint 45R and slide throu h window, No issues, Establish PWD baseline. 00:00 00:15 0.25 0 0 SLOT RPCOM SFTY P PJSM ON M/U MAGNET BHA. (BLOW DOWN T.D.) 00:15 01:45 1.50 0 832 SLOT RPCOM PULD P M/U MAGNET BHA AS PER BAKER REP. 01:45 03:15 1.50 832 2,869 SLOT RPCOM TRIP P SINGLE IN HOLE F/ 832' MD T/ 2869' MD, (66 JTS) 03:15 05:00 1.75 2,869 5,454 SLOT RPCOM TRIP P RIH F/ 2869' MD T/ 5454' MD, FILL EVERY 25 STDS. CALC DISP = 60.29, ACT DISP = 54.83. 05:00 06:00 1.00 5,454 5,493 SLOT RPCOM TRIP P CONT RIH T/ 5475' MD, WOB = 10K, REAM F/ 5475' MD T/ 5493' MD W/ 80 RPM, TQ = 7K, WOB = 5-10K, 420 GPM, 1700 PSI. INCREASED TO 100 RPM, TQ = 9.5K, WASH AND REAM F/ 5475' - 5493' MD SEVERAL TIMES, P/U T/ 5465' MD AND SLIDE BACK DOWN T/ 5493' MD NO ROT). 06:00 06:15 0.25 5,493 5,493 SLOT RPCOM SFTY P PJSM ON DISPLACING THE WELL Page 7 of 22 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 06:15 07:15 1.00 5,493 5,493 SLOT RPCOM CIRC P TREAT NEW LSND MUD IN PIT #5 AS PER MI REP. 07:15 08:45 1.50 5,493 5,493 SLOT RPCOM CIRC P DISPLACE 9.5PPG MILLING FLUID W/ 9.6 PPG LSND MUD @ 6 BPM, 700 PSI, 40 RPM, TQ=SK 08:45 0930 0.75 5,493 5,454 SLOT RPCOM OWFF P SET BACK STD, MONITOR WELL, (STATIC) BLOW DOWN T.D., CLEAN UNDER SHAKERS, EMPTY OUT T.T., AND FILL W/ 9.6 PPG LSND MUD. 09:30 12:00 2.50 5,454 832 SLOT RPCOM TRIP P POOH F/ 5454' MD, T/ 832' MD. CALC FILL = 39, ACT FILL = 40.63. 12:00 14:00 2.00 832 0 SLOT RPCOM PULD P RACK BACK HWT. L/D DRILL COLLARS AND CLEAN OUT BHA. 14:00 14:30 0.50 0 0 SLOT RPCOM OTHR P CLEAR AND CLEAN RIG FLOOR. 14:30 17:00 2.50 0 141 PROD1 DRILL PULD P PJSM, M/U DRILLING BHA.106' 17:00 17:45 0.75 141 141 PROD1 DRILL PULD P UPLOAD MWD DATA 17:45 1830 0.75 141 141 PROW DRILL CIRC P SHALLOW PULSE MWD W/ 450 GPM 100 PSI, BLOW DOWN TOP DRIVE. 18:30 19:00 0.50 141 141 PROD1 DRILL PULD P PJSM, P/U AND LOAD NUCLEAR SOURCES. 19:00 20:45 1.75 141 2,425 PROD1 DRILL TRIP P WITH DRILLING BHA F/ 141' jTIW T/2425' 20:45 21:15 0.50 2,425 2,425 PROD1 DRILL SVRG P SERVICE TOP DRIVE SWIVEL AND ROLLERS. 21:15 23:00 1.75 2,425 5,389 PROW DRILL TRIP P TI F/ 2425'T/ 5389' MD, ACT= 52.8 BBL, CALC= 53.58 BBL. 23:00 23:30 0.50 5,389 5,493 PROD1 DRILL CIRC P M/U TOP DRIVE, P/U= 140K, S/O= 115K, 450 GPM= 1600 PSI, ORIENT TOOLFACE 45° R AND SLIDE THROUGH WINDOW T/ 5493' 23:30 00:00 0.50 5,493 5,493 PROD1 DRILL CIRC P ESTABLISH PWD BASELINE W/ 450 GPM, 1450 PSI, 500 GPM, 1700 PSI, 550 GPM, 2000 PSI 2/09/2012 Drill f/ 5493' MD - 6930' MD. TVD - 5405' 00:00 06:00 6.00 5,493 5,849 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5493' - 5849' TVD = 4589'. Pumps at 550 GPM's PSI= 1950, WOB - 5/10K. PU Wt = 143K, SO WT = 120K, ROT WT - 131 K. TQ ON - 5-8 Ft LBS, TQ OFF - 4 Ft LBS. RPM's - 60. Jar HRS - 4.75. BIT HRS - 4.75. ECD - 10.39 PPG. ART= 2.86, AST= 1.71, ADT= 4.57 06:00 12:00 6.00 5,849 6,218 PROW DRILL DDRL P Directional drill 8 3/4" hole from 5849' - 6218 0. TVD = 4854'. Pumps at 550 GPM's PSI= 2100, WOB - 3/7K. PU Wt = 146K, SO WT = 122K, ROT WT - 135K. TQ ON - 8 Ft LBS, TQ OFF - 4.5 Ft LBS. RPM's - 100. Jar HRS - 7.53. BIT HRS - 7.53. ECD - 10.48 PPG. ART= 1.90, AST= 1.06, ADT= 2.96 Page 8 of 22 Time Logs Date From To Dur S. De th E De th Phase Code Subcode T Comment 12:00 18:00 6.00 6,218 6,588 PROW DRILL DDRL P Directional drill 8 3/4" hole from 6218' - 6588'. TVD = 5147'. Pumps at 550 GPM's PSI= 1950, WOB - 5-8K. PU Wt = 155K, SO WT = 127K, ROT WT - 145K. TQ ON - 7-8 Ft LBS, TQ OFF - 6 Ft LBS. RPM's - 100. Jar HRS - 11.48. BIT HRS - 11.48. ECD - 10.3 PPG. ART= 2.22, AST= 1.73, ADT= 3.95 18:00 00:00 6.00 6,588 6,930 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 6588'- 6930'. TVD = 5405'. Pumps at 550 GPM's PSI= 2075, WOB - 8-10K. PU Wt = 162K, SO WT = 132K, ROT WT - 147K. TQ ON - 6-9Ft LBS, TQ OFF - 6.5Ft LBS. RPM's - 100. Jar HRS - 15.79. BIT HRS - 15.79. ECD - 10.59 PPG. ART= 2 27, AST= 2 04, ADT= 4.31 12/10/2012 Drilled f/ 6930'- 8028' MD @ TD, TVD= 6198' Rig stopped @ 7000' MD and raised mud weight from 9.6 ppg to 10 0 ppg and Soltex & Resinex to system before penetrating the top of HRZ formation. 00:00 01:30 1.50 6,930 7,000 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 6930'- 7000'. TVD = 5462'. Pumps at 550 GPM's, PSI= 2150, WOB - 10-15 K. PU Wt = 163 K, SO WT = 132 K, ROT WT - 150 K. TQ ON - 7-9 Ft LBS, TQ OFF - 6 Ft LBS. RPM's - 100. Jar HRS - 15.79. BIT HRS - 15.79. ECD - 10.55 PPG. ART= 1. 10, AST= 1. 10, ADT= 1.47 01:30 05:15 3.75 7,000 7,000 PROD1 DRILL CIRC P Wt. up system F/ 9.6 ppg T/ 10.0 ppg as per well plan, Reciprocate @ 40 RPM, 4 bph, 400 psi,. Once wt. up, turned pumps up to 13 bpm, 2350 psi. 05:15 06:00 0.75 7,000 7,050 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7000'- 7050'. TVD = 5501'. Pumps at 550 GPM's, PSI= 2450, WOB - 10-15 K. PU Wt = 170 K, SO WT = 132 K, ROT WT-154 K. TQ ON-12 Ft LBS, TQ OFF - 6 Ft LBS. RPM's -100. 06:00 12:00 6.00 7,050 7,254 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7050'- 7254'. TVD = 5652'. Pumps at 550 GPM's, PSI= 2500, WOB - 10-15 K. PU Wt = 170 K, SO WT = 132 K, ROT WT - 154 K. TQ ON - 12 Ft LBS, TQ OFF - 9 Ft LBS. RPM's - 100 Jar HRS - 20.93. BIT HRS - 20.93. ECD - 10.85 PPG. ART= 1.52, AST= 2.15, ADT= 3.67 Page 9 of 22 Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 12:00 18:00 6.00 7,254 7,660 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7254'- 7660'. TVD = 5933'. Pumps at 550 GPM's, PSI= 2825, WOB - 8-10 K PU Wt = 175K, SO WT = 132K, ROT WT-154 K. TQ ON-12 Ft LBS, TQ OFF - 9 Ft LBS. RPM's - 100. Jar HRS - 25.65. BIT HRS - 25.63. ECD - 11.06 PPG. ART= 2.98, AST= 1.74, ADT= 4.72 18 00 22:45 4.75 7,660 8,028 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 7660'- 8028'. TVD = 6198'. Pumps at 550 GPM's, PSI= 2950, WOB - 8-10 K. PU Wt = 185K, SO WT = 137K, ROT WT-162 K. TQ ON-10 Ft LBS, TQ OFF - 8.5 Ft LBS. RPM's - 100. Jar HRS - 29.05. BIT HRS - 29.05. ECD - 11.0 PPG. ART= 3.40, AST= 0.0, ADT= 3.40 T.D Hole section 2245 00:00 1.25 8,028 8,028 PROD1 DRILL CIRC P CBU @ Drilling rate, Rotate @ 70 RPM & reciprocate string. Obtain SPRs @ TD 8028' MD, TVD= 6198' 23:30 hrs. 12/11/2012 CBU X 4. Make wiper trip t/ 5292' MD. Cut drilling line and RIH t/ 8028' MD. CBU X 3. POOH, no tight hole observed. Down load MWD and lay down BHA. C/O upper rams to 7" and test to 3500 PSI. R/U to run liner. 00:00 01:30 1.50 8,028 7,704 PROW CASING SFTY P PJSM, control circulation and condition mud @ 13 BPM, 2600 PSI, 70 RPM, TQ = 6k. (BU x 4) 01:30 01:45 0.25 7,704 7,704 PROD1 CASING OWFF P Monitor well, B/D T.D. 01 45 03:30 1.75 7,704 5,292 PROD1 CASING TRIP P POOH on elevators f/ 7704' MD t/ 5292' MD. (No problems.) Actual fill = 22.78 bbls, Calculated fill = 20.3 bbls 03:30 03:45 0.25 5,292 5,292 PROD1 CASING OWFF P Clean rig floor; monitor well. 03:45 04:00 0.25 5,292 5,292 PROD1 CASING SFTY P PJSM, HRW and HRC on slipping and cutting drig line. 04:00 05:00 1.00 5,292 5,292 PROD1 RIGMNT SLPC P Slip and cut 65' of drlg line. 05:00 05:45 0.75 5,292 5,574 PROD1 CASING TRIP P Orient tool face 45R, slid through window @ 530 GPM, 2250 PSI t/ 5574' MD - as per DD. (B/D T.D.) 05:45 07:15 1.50 5,574 7,889 PROD1 CASING TRIP P RIH f/ 5575' MD, t/ 7889' MD on elevators. Actual fill = 17.85 bbls, Calculated fill = 20.3 bbls 07:15 07:30 0.25 7,889 8,028 PROD1 CASING WASH P Wash and ream f/ 7889' MD t/ 8028' MD @ 13 BPM, 2650 PSI, 69% flow, 60 RPM, TQ = 7-8k. 07:30 09:30 200 8,028 7,889 PROD1 CASING CIRC P Circulate BU x 3 @ 13 BPM, 2650 PSI, 69% flow, 60 RPM, TQ = 7-8k, lower pump rate t/ 10 BPM on the down stroke = 1650 PSI. Racking back on STD every BU as per Halliburton rep. 09:30 09:45 0.25 7,889 7,889 PROD1 CASING OWFF P Monitor well (static), B/D T.D. Page 10 of 22 Time Logs Date From To Dur S. De th E. DeDth Phase Code Subcode T Comment 09:45 10:00 0.25 7,889 7,426 PROM CASING TRIP P POOH f/ 7889' MD t/ 7426' MD Actual fill = 4 bbls, Calculated fill = 3.9 bbls. 10:00 10:15 0.25 7,426 7,426 PROM CASING CIRC P Drop 2" OD hollow rabbit, pump 22 bbls 12 ppg slug, B/D T.D. 10:15 12.00 1.75 7,426 5,111 PROM CASING TRIP P POOH f/ 7426' MD U 5111' MD. Actual fill = 23.78 bbls, Calculated fill = 23.4 bbls. 12:00 12:15 0.25 5,111 5,111 PROD1 CASINGOWFF P PJSM, monitor well (static). 12:15 15:30 3.25 5,111 141 PROM CASING TRIP P POOH w/ DRLG assembly f/ 511 TV 141'. 15:30 16:15 0.75 141 141 PROD1 CASING SFTY P Clean floor, PJSM f/ nuclear sources. 16:15 17:45 1.50 141 141 PROD1 CASING PULD P DN load MWD. 17:45 18.30 0.75 141 0 PROD1 CASING PULD P Continue L/D BHA. 18:30 20:30 2.00 0 0 PROM WHDBO SFTY P PJSM, C/O upper 3.5x6" VBR to 7" rams, SIMOPS P/U CSG EQUIP. 20:30 21:00 0.50 0 0 PROD1 CASING PULD P P/U & M/U 10' pup to cmt head. 21:00 21:30 0.50 0 0 PROM WHDBO OTHR P BOLDS. Pull wear bushing. 21:30 23:30 2.00 0 0 PROD1 WHDBO BOPE P P/U 7" test JT & M/U test plug, R/U test equipment & test upper 7" rams & annular to 250/3500 PSI f/ 5 min each & record on chart. 23:30 00:00 0.50 0 0 PROM WHDBO BOPE P R/D test equipment. 2/12/2012 R/U casing equipment and hold PJSM. M/U new float shoe and RIH w/ 7" casing U 2866'. RIH w/ 7" casing on drill pipe t/ 7734' MD. CBU @ 2866', 4625' and 6950' Took weight @ 7734', work pipe and attempt to circ. Worked pipe free and POOH t/ 7445'. Est. circulation and stage pumps up t/ 6 BPM, CBU. Wash casing down to 8017', 11' high. Unable to et down past 8017'. Circ and condition mud for cement job. 00:00 00:15 0.25 0 0 PROD1 CASING SFTY P PJSM, install 12.437" wear ring. 00:15 01:00 075 0 0 PROD1 CASING RURD P R/U CSG equipment and fill up line. 01:00 01.30 0.50 0 0 PROM CASING SFTY P PJSM on running 7" CSG. Discuss safety & hazard recognition issues. Discuss procedure to make up and run 7" casing. 01:30 01:45 0.25 0 0 PROM CASING RNCS P P/U shoe jt. Observed when picked up shoe joint, the bottom part of the shoe fell off. Inspection indicated it may have been cracked and was damaged. 01:45 03:00 1.25 0 0 PROM CASING RNCS T Service rig, work on work orders, called for and wait on new shoe and centralizer. 03:00 03:15 0.25 0 90 PROM CASING RNCS P M/U shoe, float collar and landing collar assembly. Fill shoe track with mud, and check floats. OK. 03:15 08:15 5.00 90 2,866 PROM CASING RNCS P RIH w/ 7" CSG f/ 90't/ 2866' MD, obtaining up and down weight and filling every 10 jts. Actual fill = 26.18 bbls, Calculated fill = 26.63 bbls. 08:15 08:30 0.25 2,866 2,866 PROD1 CASING PACK P M/U 7" Baker ZXP packer and liner assembly as per Baker rep. Install wiper dart and pins. Page 11 of 22 Time Logs Date From To Dur S. Deoth E. De th Phase Code Subcode T Comment 08:30 09:00 0.50 2,866 2,866 PROM CASING RUNL P R/D CSG. equipment, fill up line, clean and clear rig floor. 09:00 09:30 0.50 2,866 2,866 PROM CASING CIRC P CBU @ 2866' MD, @ 4 BPM = 200 PSI, 58% flow 09:30 11:00 1.50 2,866 4,625 PROM CASING RUNL P RIH w/ 5" DP on elevators f/ 2866' MD U 4625' MD, filling pipe every 10 stds. 11:00 12:00 1.00 4,625 4,625 PROM CASING CIRC P CBU @ 4 BPM = 250 psi, 59% flow. Actual fill = 13.3 bbls, Calculated fill = 15.6 bbls. 12:00 12:30 0.50 4,625 5,440 PROM CASING RUNL P P/U wt 120k, S/O 100k, B/D T. D. and continue TIH f/ 4625'V 5440', Top of window. 12:30 13:00 0.50 5,440 5,440 PROM CASING CIRC P Circ DP volume above TOW, increase rate up to 4 BPM = 275 psi. 13:00 14:30 1.50 5,440 6,950 PROM CASING CIRC P TIH f/ 5440't/ 6950'. Observed pass through whipstock area with no issues. 14:30 15:30 1.00 6,950 6,950 PROM CASING CIRC P CBU @ 6950' recip. string & increase rate to 6 BPM = 450 psi. 15:30 16:30 1.00 6,950 7,734 PROM CASING RUNL P Cont to run 7" liner f/ 6950'V 7734'. At 7743' the string began to take weight. P/U= 185K, S/0=120K. Actual displacement= 28.5 bbls, Calculated displacement= 28.45 bbls. 16:30 17:30 1.00 7,734 7,734 PROM CASING RUNL P Work casing several times, pulling 50K over and 45K on liner Attempt to establish circulation by pumping @ 1-2 BPM, string was packing off. Continue working string, staying below 900 PSI. Worked string free. 17:30 18:15 0.75 7,734 7,445 PROD1 CASING RUNL P Pump out of the hole from 7734'V 7445'@ 2 BPM. Observed 35 K drag at times while POOH. 18:15 20:00 1.75 7,445 7,445 PROM CASING CIRC P Establish circulation @ 2 BPM= 350 PSI, stage pumps up to 6 BPM=500 PSI while working 90'. Circualted hole clean. 20:00 21:45 1.75 7,445 8,017 PROM CASING WASH P Wash liner down @ 6 BPM= 500 PSI V 8017'. Set down 10k, weight not washing off after several attempts. Shut down, indications point to having 11' of fill. P/U=195K, S/0= 127K. 21:45 22:30 075 8,017 8,000 PROM CASING RURD P Lay down a double, blow down and make up cement head. 22:30 00.00 1.50 8,000 8,017 PROW CASING CIRC P Establish circulation @ 6 BPM=650 PSI. Reciprocate string 30' and circulate/condition mud t/ < 20 YP and even density in/out for cement job. 2/13/2012 Circulate and condition 10ppg mud. Hold PJSM on pumping cmt. Pumped total of 40 bbls CW 100, 50 bbls of mud push, and 30 bbls of cement before job was shut down due to equipment failure. Circulated out CW 100, mud push and cement @ 7 BPM = 350 psi, 51% flow. Crew circulated and conditioned mud while reciprocating pipe; waiting on Schulmberger cementing equipment. Rigged up SLB cement equipment. Pumped 40 bbls of CW -100, 50 bbls of mud push and 123 bbls of Class G cement w/ GASBLOK. Page 12 of 22 CM circ, L OJT . CM'f Y, Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 00:15 0.25 8,017 8,017 PROD1 CASING CIRC P Circulate and condition mud @ 6 BPM = 350psi, P/U weight = 190k, S/O weight= 130k. 00:15 00:30 0.25 8,017 8,017 PROD1 CEMEN-SFTY P PJSM, HRW and HRC on pumping cement. 00:30 01:30 1.00 8,017 8,017 PROD1 CEMEN" OTHR P Prime Schlumberger lines for cementing 'ob. 01:30 02:30 1.00 8,017 8,017 PROD1 CEMEN"CMNT P Pumped 10 bbls of CW 100, successfully pressure tested cement lines t/ 1000 psi (low) and 4000 psi (high). 02:30 03:15 0.75 8,015 8,015 PROD1 CEMEN- CMNT P Pumped 30 bbls of CW 100 (total 40 bbls CW 100), followed by 50 bbls of 12ppg Mud Push, then 30.2 bbls of Gasblok cement. Pump truck could not pump at desired rate due to equipment failure; decision was made to shut down the 'ob. 03:15 05:30 2.25 8,015 8,015 PROW CEMEN- DISP T Circulate out CW 100, Mud Push and 30.2 bbls of cement @ 7 BPM = 350 psi, 51% flow. 05:30 19:30 14.00 8,015 8,015 PROD1 CEMEN-CIRC T Circulate and conditon mud @ 3 BPM, 300 psi, 47% flow, P/U weight = 250k, S/O weight = 123k. Reciprocating pipe @ all times. Waiting on Schlumberger cementing equipment. SIMOPS: clean pits 19:30 21:30 2.00 8,015 8,015 PROD1 CEMEN" RURD T Spot SLB cement trucks, SIMOPS Increase pump rate to 6 BPM=650 PSI and condition mud for cement 'ob. 21:30 22:30 1.00 8,015 8,015 PROD1 CEMEN' SFTY T Hold PJSM for cement job. Discuss safety and hazards while cementing. Established a back up plan if the cement was unable to be mixed on the fly again. 22:30 23:30 1.00 8,015 8,015 PROD1 CEMEN" CMNT T Pumped 10 bbls of CW -100 chem wash, shut in and pressure tested lines t/ 1000/4000 PSI., good. Lined back up to SLB, pumped 30 bbls of CW -100 followed by 50 bbls of 12.0 ppg Mud Push. 23:30 00.00 0.50 8,015 8,015 PROD1 CEMEN" CMNT P Shut down and batched up cement. Pumped 123 bbls of 15.8 ppg Class G cement w/ GASBLOK @ 5 BPM=220 PSI. No issues while pumping cement. 2/14/2012 Displaced cement out of liner, bumped plug @ 1803 stks. Set liner hanger and checked floats. Set liner top packer, and tested. Liner top @ 5240' MD OWFF and POOH. UD Baker running tool. C/O VBR rams and tested w/ 5" and 4" test joint t/250/3500 PSI. M/U clean out assy w/ MI Razor back/ Well patroller. RIH picking up 4" DP Page 13 of 22 CM circ, L OJT . CM'f Y, L) 1n2S' ` ;_ Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 02:15 2.25 8,015 5,241 PROD1 CEMEN- DISP P PJSM; Dart was dropped and displaced with 5.4 bbls H2O. Swap to rig pumps. Set pipe in tension and pumped @ 6.5 bpm, 275 psi, 47% flow. Liner latched up w/ 803 strokes. Pressured up t/ 650 psi. Increased pump rate back U 6 bpm @ 550 psi. PI w/ 1803 _Bump strokes, pr ssu� red up t/ 3580 psi. S/O t/ 50k, bleed off pressure and checked floats (they were ood . P/U t/ 90k and turned string 20 rotations to the right. Pressured up t/ 500 psi, P/U t/ 115k pull pack off and circulated @ 8.5 bpm, 850 psi, 15 bbls pumped. Slowed pumps t/ 1 bpm, 220 psi. S/O and saw shear @ 60k; went t/ 40k twice. Rotated at 20 RPM, TQ = 3k, S/O wt. = 110k, S/O t/ 50k. Stopped roatation, P/U 35' and circulated @ 14 bpm, 1175 psi, reciprocating pipe 15'. Pumped total of 872 bbls. No issues. Liner top set 5240' D. 02:15 02:30 0.25 5,241 5,185 PROD1 CEMEN' PULD P UD 2 singles and cement head. B/D op drive. 02:30 03:15 0.75 5,185 5,185 PROD1 CEMEN" PRTS P R/U t/ test liner and liner hanger. As the wellbore was pressured up the drill string began to hydraulic out of the hole. At 2200 PSI, 40K of string weight was lost. Successfully tested liner and liner hanger t/ 2200 psi on chart as per company man due to loss of string weight. 03:15 03:45 0.50 5,185 5,185 PROD1 CEMEN'OWFF P Monitored well (static). 03:45 05:30 1.75 5,185 40 PROD1 CEMEN-TRIP P POOH f/ 5185' MD t/ 40' MD. Actual fill = 44.2 bbls, Calculated fill = 43.68 bbls. 05:30 05:45 0.25 40 0 PROW CEMEN- PULD P Service break and UD running tool as per Baker rep. 05:45 06:00 0.25 0 0 COMPZ WELLPFOTHR P Clean and clear rig floor. 06:00 06:30 0.50 0 0 COMPZ WELLPF PRTS P Test liner and liner hanger t/ 3500 psi f/ 15 min. On chart (good). 06:30 07:30 1.00 0 0 COMPZ WELLPFOTHR P PJSM, B/D kill line, R/U and flush stack @ 20 bpm, 120 psi w/ black water. R/D Stack washer and B/D Top Drive. 07:30 07:45 0.25 0 0 COMPZ WELLPF SFTY P PJSM on chaning out 7" rams to 3.5" x 6" VBR and opening all ram doors. 07:45 08:15 0.50 0 0 COMPZ WELLPF OTHR P Drain stack, pull wear ring and set test plug. 08.15 12:00 3.75 0 0 COMPZ WHDBO NUND P Change top pipe rams f/ 7" rams U 3.5" x 6" VBR and open all ram doors t/ clean out any cement and dirt. Monitor well through annulas valve. SIMOPS: clean pits Page 14 of 22 L) 1n2S' ` ;_ R,�JN,S Time Logs Date From To Dur S. DeDth E. DeDth Phase Code Subcode T Comment 12:00 12:30 0.50 0 0 COMPZ WHDBO OTHR P Close ram doors and load single 12:30 13:30 1.00 0 0 COMPZ WHDBO SVRG P Service skate, iron roughneck, draworks & top drive. 13:30 14:00 0.50 0 0 COMPZ WHDBO SEQP P PJSM, R/U test equipment, M/U 5" test joint to test plug. 14:00 14:30 0.50 0 0 COMPZ WHDBO BOPE P Test upper 3-1/2" X 6" VBR rams to 250/3500 PSI f/ 5 min on chart, good test. 14:30 15:00 050 0 0 COMPZ WHDBO BOPE P UD 5" test joint and pick up 4" test joint. Attempt to test lower VBR, observed door hinge hydraulic leak. 15:00 16:00 1.00 0 0 COMPZ RIGMNTSVRG P Replace hinge seal on BOP stack. 16:00 16:15 0.25 0 0 COMPZ WHDBO SFTY P PJSM for crew change. Discussed in detail safety issues and hazard recognition with new crew. 16:15 17:30 1.25 0 0 COMPZ WHDBO BOPE P Test lower 2-7/8" X 5" VBR, upper 3-1/2" X 6" VBR and Annular with 4" test joint to 250/3500 PSI for 5 min on test chart, good test. 17:30 18:00 0.50 0 0 COMPZ WHDBO SEQP P R/D BOP testing equipment and wear bushing. 18:00 20:30 2.50 0 0 COMPZ WELLPF RURD P Hold PJSM. Pick up subs and handling equipment for clean out run. Tally and strap BHA. 20:30 21:30 1.00 0 0 COMPZ WELLPF PULD P PJSM, Make up tandem scraper BHA w/ MI SWACO Razor back and Well Patroller casing scrapers. 21:30 00:00 2.50 0 0 COMPZ WELLPF PULD P RIH picking up 4" drill pipe t/ 2803' MD 2/15/2012 RIH w/ MI-Swaco clean out tools. Clean the packer area and perf zone. Tag TOC @ 7866'. CBU and swap well over to sea water. Shut down and clean pits f/ filtered NaCl. Displace well t/ filtered NaCl, 49 NTUs at surface after displacing.. OOH UD clean out BHA. 00:00 02:00 2.00 2,803 7,249 COMPZ WELLPF TRIP P RIH on 5" drill pipe f/ 2803't/ 7249. 02:00 03:30 1.50 7,249 7,866 COMPZ WELLPF WASH P Establish circulation @ 7 BPM= 1300 PSI, ROT @ 60 RPM w/ 5.51K TQ. Wash and ream packer setting area and pert area three times per stand. Wash and reamed f/ 7341' MD t/ 7619' MD. RIH and teg top of cement @ 7866' MD, set 10K down on cement. 03:30 05:00 1.50 7,866 7,866 COMPZ WELLPFCIRC P Circulate hole clean and condition hole for fluid swap. Pump @ 12 BPM=3150 PSI, 60 RPM w/ 10K TQ, P/U=164K, S/O=113K, ROT= 125K. 05:00 05:30 0.50 7,866 7,866 COMPZ WELLPF DISP P Displace well to seawater. Pump 35 bbls HIVis H2O pill followed by 500 bbls of seawater @ 12 BPM=3150 PSI, 60 RPM w/ 10K TQ. Blow down top drive. Page 15 of 22 R,�JN,S Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:30 16:30 11.00 7,866 7,866 COMPZ WELLPF COND P Shut down to clean pits. Flush out all surface lines and equipment. Clean pits extremely well and check NTU's on filtered 9.0 ppg NaCl ( 24 NTUs) Mix caustic wash/ Safe Surf pill in pits. 16:30 16:45 0.25 7,866 7,866 COMPZ WELLPF SFTY P Hold PJSM on displacing to filtered brine. Discussed safety issues while working around caustic wash and good communication with rig/truck drivers. Spill champs were given tasks for the job. 16:45 18:45 2.00 7,866 7,866 COMPZ WELLPF DISP P Displace well t/ 9.0 ppg filtered NaCl. Spacer train as follows; Pumped 35 bbls HiVis H2O pill, 100 bbls Caustic/Safe-Surf O pill, 35 bbls HiVis H2O and 550 bbls of filtered 9.0 ppg NaCl. Shut down when NTUs of returns reached 49 NTUs. Pumped 6 BP =600 PSI. 18:45 19:00 0.25 7,866 7,833 COMPZ RIGMNT SFTY P Hold PJSM, fill out HRC and HRW on slip & cut drilling line. 19:00 20:00 1.00 7,833 7,833 COMPZ RIGMNT SLPC P Slip and cut drilling line. Cut 14 wraps for a total of 91'. 20:00 20:30 0.50 7,833 7,833 COMPZ RIGMNT SVRG P Service top drive. 20:30 20:45 0.25 7,833 7,833 COMPZ WELLPF SFTY P Hold PJSM on tripping out of the hole. 20:45 23:15 2.50 7,833 2,850 COMPZ WELLPFTRIP P POOH f/ 7860' t/2850' MD. 23:15 00:00 0.75 2,850 2,800 COMPZ WELLPFTRIP P UD 9 -5/8 "Well Patroller casing clean out tool and Razor back casing scraper. 2/16/2012 Cont t/ POOH w/ clean out BHA. UD BHA. N/U shooting flange. R/U E -Line and RIH w/ CAST tools. Log up f/ 7830't/ 5150'w/ 1500 PSI on well, good cement job. POOH w/ E -Line and R/D E -Line. N/D shooting flange and R/U to test BOPE. Start test BOPE t/ 250/3500 PSI. Bob Noble of AOGCC waived witness of the test. 00:00 00:45 0.75 2,800 67 COMPZ WELLPFTRIP P PJSM, POOH f/ 2800' MD t/ 67' MD. 00.45 01:45 1.00 67 0 COMPZ WELLPF PULD P UD MISWACO clean out BHA. 01:45 02:00 0.25 0 0 COMPZ WELLPF OTHR P Clean and clear rig floor. 02:00 02:15 0.25 0 0 COMPZ WELLPFSFTY P PJSM on N/U shooting flange. 02:15 05:00 2.75 0 0 COMPZ WELLPF NUND P N/U Shooting flange. SIMOPS: clean pits. 05:00 05:30 0.50 0 0 COMPZ WELLPF PULD P P/U and break pup joint off cement head and lay back down. Clean and clear rig floor. 05:30 06:00 0.50 0 0 COMPZ WELLPF SVRG P Service Rig. 06:00 08:15 2.25 0 0 COMPZ WELLPF RURD P Spot Halliburton Trucks and off load tools. Prep tools to be picked up 0815 08:30 0.25 0 0 COMPZ WELLPF SFTY P PJSM on R/U E -line. 0830 11:00 2.50 0 0 COMPZ WELLPF RURD P P/U and R/U E -line as per Halliburton Rep. Page 16 of 22 Lo 4tA• CAST 90P Time Logs Date From To Dur S. Depth E. De th Phase Code Subcode T Comment 11:00 12:00 1.00 0 0 COMPZ WELLPF PRTS T Test Lubricator pack off t/ 2000 psi on surface, good. RIH t/ 1000' down and perform dummy logging test. At this point a leak was detected in the pack -off and decision made to come out of hole and replace part with head. 12:00 12:45 0.75 0 0 COMPZ WELLPF SFTY -grease T Hold PJSM, HRW and HRW on L/D E -Line tools and pack -off. 12:45 14:15 1.50 0 0 COMPZ WELLPF RURD T Rig down HES pack -off assy and rig up HES rease head assy. 14:15 14:30 0.25 0 0 COMPZ WELLPF PRTS P Pressure test grease head to 2000 PSI, good test. 14:30 16 00 1.50 0 0 COMPZ WELLPF ELOG P RIH w/ HES E -Line to 7830' MD 16:00 17:15 1.25 0 0 COMPZ WELLPF ELOG P Pressure up casing to 1500 PSI. Log well with HES CAST tool f/ 7830' MD t/ 5150' MD. CAST tool confirmed good cement 'ob. 17:15 18:15 1.00 0 0 COMPZ WELLPF ELOG P Bled pressure off casing and POOH w/ HES E -Line. 18:15 19:15 1.00 0 0 COMPZ WELLPF RURD P Rig down HES E -Line. 19:15 19:30 0.25 0 0 COMPZ WELLPFSFTY P Hold PJSM on rigging down shooting flange. 19:30 20:45 1.25 0 0 COMPZ WHDBO NUND P Rig down shooting flange and install riser boot/riser. 20:45 21:00 0.25 0 0 COMPZ WHDBO SEQP P Pull wear ring and install test plug. 21:00 22:00 1.00 0 0 COMPZ WHDBO RURD P PJSM, rig up to test BOPE. 22:00 00:00 2.00 0 0 COMPZ WHDBO BOPE P Test BOPE w/ 5" test joint to 250/3500 PSI for 5 min, record on chart. Test#1: Top pipe rams, CV 1,12,13,14 and manual kill. Test#2: Upper IBOP, HCR kill, CV 9 and 11. Test#3: Lower IBOP, CV 5,8, and 10. Witness of the test was waived by Bob Noble of the AOGCC. 12/17/2012 Continue testing BOPE t/ 250/3500 PSI. One failure, the Annular failed and was replaced and successfully tested. Bob Noble of AOGCC waived witness of test. M/U HES TCP guns and RIH to perforate. Obtain slow pump rates before perforating. 00:00 07:00 7.00 0 0 COMPZ WHDBO BOPE P Continue testing BOP's. Test with 3 1/2", 4", and 5" test joints. test to 250 / 3500 PSI. Test upper & lower rams. Test kill and choke line valves. Perform Koomey test. Observed initial 200 PSI increase in 36 seconds, and full 300 PSI obtained in 221 Seconds. Observed 5 nitrogen bottle avg PSI = 2000 PSI. Witness of test waived by AOGCC rep Bob Noble. Observed Annular on BOP stack and failed. 07:00 07:15 0.25 0 0 COMPZ WHDBO SFTY T Held PJSM with crew. Discuss saefty & hazard recognition issues. Discuss procedure to change out Annular on BOP stack. Page 17 of 22 Lo 4tA• CAST 90P Time Logs Date From To Dur S. DeDth E. De th Phase Code Subco e T Comment 07:15 11:00 3.75 0 0 COMPZ WHDBO RGRP T Remove Annular cap, and old element. Install new element and replace cap. Recharge system. 11:00 13:30 2.50 0 0 COMPZ WHDBO BOPE P Rig up, and install test joint. Continue with and complete BOP test. Test Annular U 250/3500 PSI with 3-1/2", 4" and 5" test joint, good test. 13:30 13:45 0.25 0 0 COMPZ WHDBO RURD P Rig down testing equipment. 13:45 14:00 0.25 0 0 COMPZ WHDBOOTHR P Set wear bushing. 14:00 16:15 2.25 0 0 COMPZ PERF PULD P Pick up tools from the beaver slide and rig up to run HES TCP gun assy. 16:15 16:30 0.25 0 0 COMPZ PERF SFTY P Hold PJSM on picking up TCP pert guns. Discussed safe handling measures of TCP pref guns and good communication with all hands involved. 16:30 18:00 1.50 0 297 COMPZ PERF PULD P Pick up HES TCP perf guns Picked up a total of 7 TCP guns. 18:00 20:00 2.00 297 3,035 COMPZ PERF TRIP P RIH with 4" DP f/ 297' MD t/ 3035' MD. C/O to 5" handling tools. 20:00 22:45 2.75 3,035 7,663 COMPZ PERF TRIP P Cont. to RIH with TCP guns of 5" DP t/ 7663' MD. P/U=167, S/O= 111 K. Pulled up t/ 167K and set slips with pipe in tention. Get slow pump rates @ 7663' MD 6180-TVD, 9.0 ppg fluid, 23:15 hrs. Pump 1: 30 SPM=90 PSI, 40 SPM= 130 PSI. Pump 2: 30 SPM=80 PSI, 40 SPM= 150 PSI. 22:45 00:00 1.25 7,663 7,663 COMPZ PERF RURD P PJSM, R/U HES E-line to make correlation run. 2/18/2012 R/U Eline, RIH corelate pert depth, POOH R/D Eline, Pressure up on IA U 2000 psi bleed off slow fire pert guns, Perf. f/ 7602't/ 7731' Observe well for flow 3.5 BPH loss, Circ & cond. brine, POOH w/ pert guns UD, M/U clean out BHA t/ 7740' circ 9.0 ppg filtered brine 00:00 00:15 0.25 7,663 7,663 COMPZ PERF SFTY P Pre Job safety Meeting 00:15 00:45 0.50 7,663 7,663 COMPZ PERF ELNE P R/U Halliburton Eline. 00:45 0230 1.75 7,663 7,663 COMPZ PERF ELNE P Corelate Perf. guns through drill pipe. POOH 02:30 0300 0.50 7,663 7,663 COMPZ PERF ELNE P R/D Eline 03:00 03:30 0.50 7,663 7,663 COMPZ PERF RURD P R/U t/ circ. down IA 03:30 03:45 0.25 7,663 7,731 COMPZ PERF PERF P Pressure up on IA t/ 2000 psi, bleed off slowly, Drill pipe jumped indicating guns fired. Shot perfs f/ 7602'V 7731', slight loss observed. 03:45 04:00 0.25 7,731 7,665 COMPZ PERF OTHR P POOH UD pup jts. 04:00 04:30 0.50 7,665 7,665 COMPZ PERF OWFF P Observe well for flow static losses 3.5 bbls per hour. 04:30 06:45 2.25 7,665 7,665 COMPZ PERF CIRC P Circ. & cond. 9.0 ppg brine @ 210 pm 200 psi 06:45 07:15 0.50 7,665 7,665 COMPZ PERF OWFF P Observe well for flow 3 bbl an hour loss 07:15 10:45 3.50 7,665 299 COMPZ PERF TRIP P POOH on elevators f/ 7665't/ 299' Page 18 of 22 Time Logs Date From To Dur S. De th E. DeDth Phase Code Subc de T Comment 10:45 11:00 0.25 299 299 COMPZ PERF OWFF I P Observe well for flow slight loss 11:00 11:15 0.25 299 299 COMPZ PERF RURD P Change out handling tools & P/U tubing tongs. 11:15 11:30 0.25 299 299 COMPZ PERF SFTY P Pre job safety meeting on laying down guns. 11:30 13:15 1.75 299 0 COMPZ PERF PULD P UD perf guns. All guns are fired and in ali nment. 13:15 15:15 2.00 0 0 COMPZ WELLPFOTHR P Clean & Clear rig floor. 15:15 15:30 0.25 0 0 COMPZ WELLPF PULD P P/U tools f/ slide f/ clean out BHA. 15:30 15:45 0.25 0 0 COMPZ WELLPFSVRG P Service Rig Components 15:45 17:00 1.25 0 2,800 COMPZ WELLPF PULD P P/U Clean Out BHA 17:00 20:30 3.50 2,800 7,595 COMPZ WELLPF TRIP P Trip in hole f/ 2800' t/ 7595' 20:30 21:15 0.75 7,595 7,740 COMPZ WELLPF REAM P Wash & ream through perfs f/ 7595' t/ 7740'w/ 126 gpm 200psi 60 rpm 6.5 - 8 k torque reciprocate through perfs. 21:15 00:00 2.75 7,740 7,550 COMPZ WELLPF CIRC P Pull up U 7550' circ. 9.0 ppg filtered brine @ 252 gpm 750 psi. 2/19/2012 Clean trip tank, POOH, UD magnets R/U & run 3.5 completion t/ 7746' spot eline unit, R/U eline, RIH correlate packer depth. 00:00 01:00 1.00 7,550 7,550 COMPZ WELLPFOTHR P Wait on filtered brine. Decision made to POOH and circulate filtered fluid when on bottom the 3-1/2" tubing string. 01:00 02:30 1.50 7,550 7,550 COMPZ WELLPFOTHR P Empty trip tank, clean trip tank fill w/ clean filtered 9.0 ppg brine. 02:30 05:30 3.00 7,550 72 COMPZ WELLPFTRIP P POOH f/ 7550't/ 72' 05:30 06:45 1.25 72 0 COMPZ WELLPF PULD P Clean magnets UD magnets & BHA. 06:45 07:15 0.50 0 0 COMPZ WELLPFOTHR P Drain stack, pull wear bushing, clean & clear rig floor. 07:15 08:15 1.00 0 0 COMPZ RPCOM RURD P P/U tools R/U t/ run 3.5 completion. 08:15 08:30 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on running tubing. 08:30 09:45 1.25 0 0 COMPZ RPCOM RCST P P/U 3.5 completion jewelry. 09:45 17:45 8.00 0 7,746 COMPZ RPCOM RCST P Run 3.5 completion as per detail. 17:45 22:45 5.00 7,746 7,746 COMPZ RPCOM ELNE P Spot E -line truck PJSM, R/U ELINE, Pressure test lubricator t/ 1500 psi. 22:45 00:00 1.25 7,746 7,746 COMPZ RPCOM ELNE P RIH w/ CCL & GR on E -line to correlate packer setting depth. 2/20/2012 RIH correlate packer, POOH, R/D eline, C/O jts. & pups. R/U eline, RIH & correlate, POOH, Circ clean fluid, drop ball & rod set packers, shear out PBR, spot inhibitted fluid, space out, land on hanger, pressure test tubing t/ 4000 psi -- bled off 400 si in 30 minutes, R/D equip. Wait on slick line, R/U & L/D DP 00:00 01:30 1.50 7,746 7,746 �COMPZ�RPCOMIELNE IP RIH w/ eline and corelate setting depth POOH. Page 19 of 22 Time Logs Date From To Dur S. De th E. DeDth Phas Code Subcode T Comment 01:30 06:15 4.75 7,746 7,746 COMPZ RPCOM RURD T R/D Eline, corelation run showed that a 28' correction had to be made. Make 28' correction by laying down and joint and picking up a pup joint. Set on depth. Eline crew timed out Wait on change out 06:15 06:30 0.25 7,746 7,746 COMPZ RPCOM SFTY T Pre Job Safety meeting on rigging up Eline 06:30 07:30 1.00 7,746 7,746 COMPZ RPCOM ELNE T R/U Eline 07.30 09:15 1.75 7,746 7,746 COMPZ RPCOM ELNE T RIH w/ GR & CCL corelate packer setting depth, POOH. 09:15 10:15 1.00 7,746 7,746 COMPZ RPCOM ELNE T R/D Eline tools 10:15 10:30 0.25 7,746 7,746 COMPZ RPCOM SFTY P Pre Job Safety Meeting on circ. 10:30 10:45 0.25 7,746 7,746 COMPZ RPCOM RURD P R/U U circ. 9.0 ppg brine 10:45 14:15 3.50 7,746 7,746 COMPZ RPCOM CIRC P Circ. 9.0 ppg filtered brine @ 126 gpm 260 psi, Until less than 50 NTUs returns observed. 14:15 14:45 0.50 7,746 7,406 COMPZ RPCOM PACK P Drop ball & rod set packers @ 7658' & 7433' shear out PBR Top of PBR 7406'. P/U=83K, S/0=74K 14:45 15:45 1.00 7,406 7,406 COMPZ RPCOM CIRC P P/U out of PBR spot 13 bbls or corrosion inhibited brine in annulus around seals @ 126 gpm 200 psi 15:45 17:00 1.25 7,406 7,406 COMPZ RPCOM RCST P Locate on NO-GO for space out, P/U and space out. 17:00 17:45 0.75 7,406 0 COMPZ RPCOM RCST P Land tubing on hanger, spaced out 5' off PBR, RILDS. 17:45 19:00 1.25 0 0 COMPZ RPCOM PRTS T Pressure test tubing t/ 4000 psi observe leaking off bled off 700 psi in 30 min. No surface leaks observed, bleed off tubing t/ 2000 psi pressure up on ann. U 3500 psi, hold psi f/ 5 min, observe tubing still bleeding down, hold test f/ 5 min. bleed off both sides. Didn't shear SOV. Wait on slickline crews timed out. 19:00 20:45 1.75 0 0 COMPZ RPCOM RURD P R/U test equip. blow down lines, R/D tubing Equip. R/U t/ L/D DP. 20:45 21:00 0.25 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on laying down DP. 21:00 00:00 3.00 0 0 COMPZ RPCOM PULD P Lay down DP from derrick via mouse hole. 12/21/2012 L/D DP from Derrick, R/U & run slickline, make sure sliding sleeve was closed and ball and rod was on seat. Test tubing to 4000 psi. Test annulus to 3500 psi. Shear SOV. Set TWC and test in direction of flow for 30 min to 2500 psi. N/D stack and N/U tree. Test void to 5000 PSI. 00:00 05:30 5.50 0 0 COMPZ RPCOM PULD P L/D DP from derrick via mouse hole while waiting on timed out slick line crew. 05:30 09:45 4.25 0 0 COMPZ RPCOM RURD P R/U slickline as per haliburton. 09:45 11:30 1.75 0 0 COMPZ RPCOM SLKL P RIH on slickline check sliding sleave, ball and rod on bottom, tap down on ball & rod, pressure up on tubing t/ 500 psi, no leaks, POOH w/ slick line. Page 20 of 22 Time Logs Date From To Dur S. De th E. De th Phase Code Subc de T Comment 11:30 13:15 1.75 0 0 COMPZ RPCOM SLKL P Break lubricator off set aside, change landing jts, break off XO's R/U t/ test tubing. 13:15 14:45 1.50 0 0 COMPZ RPCOM PRTS P Pressure test tubing t/ 4000 psi f/ 30 min, bleed off t/ 2000 psi pressure test Ann t/ 3500 f/ 30 min. bleed off tubing pressure t/ 1200 psi observe SOV shear communication w/ ann. Bleed tubing pressure to 0, monitor well static. 14:45 15:00 0.25 0 0 COMPZ WHDBO SFTY P Pre Job Safety Meeting on rigging down slickline. 15:00 16:00 1.00 0 0 COMPZ WHDBO RURD P R/D slickline & test equipment, blow down lines 16:00 16:30 0.50 0 0 COMPZ WHDBO OTHR P Clear floor, suck out stack. 16:30 17:15 0.75 0 0 COMPZ WHDBO OTHR P Set TWC and test in direction of flow to 2500 PSI f/ 30 min. 17:15 17:45 0.50 0 0 COMPZ WHDBO OWFF P Observe well for flow f/ 30 min static. 17.45 18:00 0.25 0 0 COMPZ WHDBO SFTY P Pre Job Safety Meeting on N/D stack & N/U tree. 18:00 19.00 1.00 0 0 COMPZ WHDBO NUND P Nipple down stack 19:00 21:30 2.50 0 0 COMPZ WHDBO NUND P N/U adaptor flange & tree as per FMC. 21:30 22:45 1.25 0 0 COMPZ WHDBO PRTS P Test adapter void to 5000 PSI f/ 10 min., good test. 22:45 00:00 1.25 0 0 COMPZ WHDBO RURD P Rig up scaffolding around tree. 2/22/2012 Tested tree to 5000 PSI. Pumped 260 bbls of 9.0 brine with 2% CRW-132 and 154 bbls of freeze protect diesel. Laid down 5" DP and secured well Released ig @ 15:00 hours to move to 3K-105 00:00 02:00 2.00 COMPZ WHDBO RURD P Continue to rig up scaffolding in cellar. 02:00 03:15 1.25 COMPZ WHDBO PRTS P Rig up test equipment on tree and fill tree with diesel. Test tree to 5000 PSI for 15 minutes, good. 03:15 04:15 1.00 COMPZ WHDBO SEQP P Rig up lubricator and test to 1000 PSI. Pull TWC and rig down lubricator. 04:15 07:00 2.75 COMPZ WHDBO CIRC P Hold PJSM, rig up circulating lines. Pump 260 bbls of 9.0 ppg filtered brine with 2 % CRW-132, pump down IA @ 1.5 BPM= 150 PSI taking returns up the tubing. 07:00 12:00 5.00 COMPZ WHDBO PULD P PJSM, Install mouse hole, lay down 5" drill pipe. SIMOPS, Freeze protect well using LRS to pump 154 bbls of diesel down IA. 12:00 13:00 1.00 COMPZ WHDBO PULD P PJSM, Line up IA and tubing, allow well to U-tube. SIMOPS, lay down the last 10 stands of 5" drill pipe in derrick. 13:00 13:30 0.50 COMPZ WHDBOOTHR P Shut in well and blow down lines. 13:30 14:00 0.50 COMPZ WHDBO OTHR P Install lubricator and set BPV as per FMC. Page 21 of 22 Time 14:00 14:30 0.50 COM PZ WHDBOOTHR P Remove circulating equipment and install gauges on tree, secure well. Tubing pressure= 100 PSI, IA pressure= 145 PSI. 14:30 15:00 0.50 COMPZ MOVE IRURD P Rig down scafolding. Released rig @ 15:00 hours. Page 22 of 22 ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2A Pad 2A -27A 501032060401 Sperry Drilling Definitive Survey Report 14 December, 2012 ON W;I; im Sperry Drilling Company:, ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: 2A -27A Design: 2A -27A ConocoPhillips (Alaska) Inc. Definitive Survey Repoli Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Well 2A-27 Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) True Minimum Curvature CPAI EDM Production Project Kuparuk River Unit Hap System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Seo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Nap Zone: Alaska Zone 04 Using geodetic scale factor Well 2A-27 From Well Position +N/ -S 0.00 It Northing: 5,959,898.03 ft Latitude: 70° 18'6.005 N (ft) Survey (Wellbore) +E/ -W 0.00 It Easting: 498,620.85 ft Longitude: 150° 0'40.214 W Position Uncertainty 0.00 It Wellhead Elevation: ft Ground Level: 92.00ft 312.15 3,331.19 2A-27 MWD (2A-27) MWD+IFR-AK-CAZ-SC Wellbore d914i!NI�'P�- t.i'Nf „� � 2A -27A ��'. ,b' ......�ti'x tv MdiF'�tYnW18i�iiP ' JiSL "IflTswmps�m.s. LI�ft(itHN&f!9`�&it@ Magnetics Model Name Sample Date Declination rc Dip Angle Field Strength 4,977.58 2A-27 RR4 (2A-27) GYD-CT-CMS Gyrodata cont.casing m/s V) V) (nT) Design 2A -27A Audit Notes: Version: 1.0 Vertical Section: BGGM2011 12/4/2012 20.10 Phase: ACTUAL Depth From (TVD) +N/ -S (ft) (ft) 27.38 0.00 80.91 57,616 Tie On Depth: 5,444.58 +E/ -W Direction (ft) (') 0.00 266.95 Survey Program Date From To Map Map (ft) (ft) Survey (Wellbore) Tool Name Description Survey Date 94.58 254.58 2A-27 (2A-27) CB -GYRO -SS Camera based gyro single shot 10/24/2009 12: 312.15 3,331.19 2A-27 MWD (2A-27) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10/27/2009 12: 3,419.28 4,348.91 2A-27 MWD (2A-27) MWD MWD - Standard 11/2/2009 12:C 4,394.58 4,977.58 2A-27 RR4 (2A-27) GYD-CT-CMS Gyrodata cont.casing m/s 11/8/2009 12:C 4,994.58 5,444.58 2A-27 RR5 (2A-27) GYD-CT-DMS Gyrodata cont.drillpipe m/s 11/9/2009 12:C 5,454.00 7,987.11 2A -27A (2A -27A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 12/8/2012 12:C Survey 12/14/2012 10:37:27AM Page 2 COMPASS 2003.16 Build 69 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) V) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.38 0.00 0.00 27.38 -92.00 0.00 0.00 5,959,898.03 498,620.85 0.00 0.00 UNDEFINED 94.58 0.19 8.34 94.58 -24.80 0.11 0.02 5,959,898.14 498,620.86 0.28 -0.02 CB -GYRO -SS (1) 194.58 0.34 325.63 194.58 75.20 0.52 -0.13 5,959,898.55 498,620.72 0.24 0.10 CB -GYRO -SS (1) 254.58 0.11 315.10 254.58 135.20 0.71 -0.27 5,959,898.74 498,620.58 0.39 0.23 CB -GYRO -SS (1) 312.15 0.57 345.63 312.15 192.77 1.02 -0.38 5,959,899.05 498,620.47 0.83 0.32 MWD+IFR-AK-CAZ-SC (2) 406.59 0.68 348.53 406.58 287.20 2.03 -0.61 5,959,900.06 498,620.24 0.12 0.50 MWD+IFR-AK-CAZ-SC (2) 494.19 1.07 349.69 494.17 374.79 3.34 -0.86 5,959,901.37 498,619.99 0.45 0.68 MWD+IFR-AK-CAZ-SC (2) 588.49 1.66 293.07 588.45 469.07 4.74 -2.27 5,959,902.77 498,618.58 1.48 2.01 MWD+IFR-AK-CAZ-SC (2) 682.53 4.92 251.46 682.33 562.95 3.99 -7.35 5,959,902.02 498,613.50 4.08 7.13 MWD+IFR-AK-CAZ-SC (2) 776.58 7.41 249.83 775.83 656.45 0.62 -16.87 5,959,898.65 498,603.98 2.65 16.81 MWD+IFR-AK-CAZ-SC (2) 12/14/2012 10:37:27AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 2A-27 Project: Kuparuk River Unit TVD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Site: Kuparuk 2A Pad MD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Well: 2A-27 North Reference: True Wellbore: 2A -27A Survey Calculation Method: Minimum Curvature Design: 2A -27A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +Nl-S +E/ -W Northing Easting DLS Section (ft) V) V) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 867.45 9.72 253.07 865.68 746.30 -3.63 -29.71 5,959,894.40 498,591.14 2.60 29.86 MWD+IFR-AK-CAZ-SC (2) 960.78 10.39 253.51957.58 838.20 -8.32 -45.31 5,959,889.72 498,575.53 0.72 45.69 MWD+IFR-AK-CAZ-SC (2) 1,053.38 12.29 247.92 1,048.37 928.99 -14.39 -62.46 5,959,883.65 498,558.39 2.37 63.13 MWD+IFR-AK-CAZ-SC (2) 1,146.79 13.64 244.44 1,139.39 1,020.01 -22.88 -81.61 5,959,875.16 498,539.24 1.67 82.71 MWD+IFR-AK-CAZ-SC (2) 1,239.73 15.06 244.43 1,229.43 1,110.05 -32.82 -102.38 5,959,865.23 498,518.46 1.53 103.99 MWD+IFR-AK-CAZ-SC (2) 1,332.53 17.21 245.92 1,318.57 1,199.19 -43.63 -125.80 5,959,854.43 498,495.05 2.36 127.94 MWD+IFR-AK-CAZ-SC (2) 1,425.31 19.08 248.18 1,406.74 1,287.36 -54.87 -152.41 5,959,843.20 498,468.44 2.15 155.11 MWD+IFR-AK-CAZ-SC 2 1,518.43 23.00 248.71 1,493.63 1,374.25 -67.13 -183.50 5,959,830.94 498,437.35 4.21 186.81 MWD+IFR-AK-CAZ-SC (2) 1,610.71 25.98 250.73 1,577.60 1,458.22 -80.35 -219.39 5,959,817.72 498,401.47 3.35 223.35 MWD+IFR-AK-CAZ-SC (2) 1,702.06 29.48 249.87 1,658.45 1,539.07 -94.70 -259.39 5,959,803.39 498,361.46 3.86 264.06 MWD+IFR-AK-CAZ-SC (2) 1,794.03 32.49 250.88 1,737.28 1,617.90 -110.58 -303.99 5,959,787.52 498,316.87 3.32 309.44 MWD+IFR-AK-CAZ-SC (2) 1,887.99 33.39 251.31 1,816.14 1,696.76 -127.13 -352.32 5,959,770.98 498,268.53 0.99 358.59 MWD+IFR-AK-CAZ-SC (2) 1,978.98 35.67 251.35 1,891.09 1,771.71 -143.64 -401.18 5,959,754.48 498,219.68 2.51 408.26 MWD+IFR-AK-CAZ-SC (2) 2,070.86 37.50 251.30 1,964.87 1,845.49 -161.17 -453.06 5,959,736.95 498,167.80 1.99 460.99 MWD+IFR-AK-CAZ-SC (2) 2,166.60 39.55 250.29 2,039.77 1,920.39 -180.80 -509.37 5,959,717.34 498,111.50 2.24 518.26 MWD+IFR-AK-CAZ-SC (2) 2,259.03 40.35 248.80 2,110.62 1,991.24 -201.55 -564.97 5,959,696.61 498,055.90 1.35 574.89 MWD+IFR-AK-CAZ-SC (2) 2,351.78 42.50 248.06 2,180.17 2,060.79 -224.11 -622.03 5,959,674.05 497,998.84 2.38 633.07 MWD+IFR-AK-CAZ-SC (2) 2,443.43 43.73 248.86 2,247.07 2,127.69 -247.11 -680.29 5,959,651.07 497,940.57 1.47 692.48 MWD+IFR-AK-CAZ-SC (2) 2,536.39 43.76 249.91 2,314.23 2,194.85 -269.74 -740.45 5,959,628.46 497,880.42 0.78 753.76 MWD+IFR-AK-CAZ-SC (2) 2,629.46 44.48 248.52 2,381.04 2,261.66 -292.73 -801.02 5,959,605.47 497,819.85 1.30 815.47 MWD+IFR-AK-CAZ-SC (2) 2,722.47 42.72 247.48 2,448.39 2,329.01 -316.75 -860.49 5,959,581.47 497,760.38 2.04 876.13 MWD+IFR-AK-CAZ-SC (2) 2,815.13 42.05 247.53 2,516.84 2,397.46 -340.65 -918.20 5,959,557.58 497,702.67 0.72 935.03 MWD+IFR-AK-CAZ-SC (2) 2,907.75 41.80 249.23 2,585.75 2,466.37 -363.45 -975.73 5,959,534.80 497,645.15 1.26 993.69 MWD+IFR-AK-CAZ-SC (2) 3,000.62 41.07 251.10 2,655.38 2,536.00 -384.31 -1,033.53 5,959,513.95 497,587.34 1.55 1,052.52 MWD+IFR-AK-CAZ-SC (2) 3,092.54 42.52 251.21 2,723.90 2,604.52 -404.09 -1,091.51 5,959,494.18 497,529.37 1.58 1,111.47 MWD+IFR-AK-CAZ-SC (2) 3,184.67 43.11 249.04 2,791.49 2,672.11 -425.39 -1,150.39 5,959,472.90 497,470.50 1.72 1,171.39 MWD+IFR-AK-CAZ-SC (2) 3,277.31 43.25 246.39 2,859.05 2,739.67 -449.42 -1,209.03 5,959,448.87 497,411.85 1.96 1,231.23 MWD+IFR-AK-CAZ-SC (2) 3,331.19 43.79 247.86 2,898.12 2,778.74 -463.84 -1,243.22 5,959,434.46 497,377.67 2.13 1,266.13 MWD+IFR-AK-CAZ-SC (2) 3,419.28 44.16 249.98 2,961.52 2,842.14 -485.83 -1,300.28 5,959,412.48 497,320.60 1.72 1,324.29 MWD (3) 3,463.55 44.11 250.29 2,993.29 2,873.91 -496.31 -1,329.28 5,959,402.01 497,291.61 0.50 1,353.80 MWD (3) 3,511.10 43.36 249.11 3,027.65 2,908.27 -507.71 -1,360.11 5,959,390.62 497,260.78 2.33 1,385.19 MWD (3) 3,554.42 42.72 249.42 3,059.31 2,939.93 -518.18 -1,387.76 5,959,380.16 497,233.13 1.56 1,413.36 MWD (3) 3,601.37 42.93 249.51 3,093.74 2,974.36 -529.37 -1,417.64 5,959,368.97 497,203.25 0.47 1,443.80 MWD (3) 3,648.66 43.04 249.08 3,128.34 3,008.96 -540.77 -1,447.80 5,959,357.57 497,173.09 0.66 1,474.53 MWD (3) 3,706.14 43.45 249.93 3,170.21 3,050.83 -554.56 -1,484.69 5,959,343.80 497,136.20 1.24 1,512.09 MWD (3) 3,749.24 43.86 250.58 3,201.39 3,082.01 -564.61 -1,512.69 5,959,333.75 497,108.20 1.41 1,540.59 MWD (3) 3,796.65 44.22 250.90 3,235.47 3,116.09 -575.48 -1,543.81 5,959,322.89 497,077.09 0.89 1,572.24 MWD (3) 3,833.49 46.05 250.23 3,261.46 3,142.08 -584.17 -1,568.43 5,959,314.20 497,052.47 5.13 1,597.29 MWD (3) 3,884.27 48.34 250.43 3,295.96 3,176.58 -596.71 -1,603.51 5,959,301.67 497,017.39 4.52 1,632.99 MWD (3) 3,926.04 49.00 250.21 3,323.55 3,204.17 -607.27 -1,633.04 5,959,291.12 496,987.86 1.63 1,663.04 MWD (3) 12/1412012 10.37:27AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: Conoco Phi IIips(Alaska) Inc. Local Co-ordinate Reference: Well 2A-27 Project: Kuparuk River Unit TVD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Site: Kuparuk 2A Pad MD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Well: 2A-27 North Reference: True Wellbore: 2A -27A Survey Calculation Method: Minimum Curvature Design: 2A -27A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) V) V) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 3,969.35 48.73 249.78 3,352.04 3,232.66 -618.43 -1,663.69 5,959,279.96 496,957.21 0.97 1,694.24 MWD (3) 4,019.37 48.54 249.15 3,385.09 3,265.71 -631.60 -1,698.85 5,959,266.80 496,922.05 1.02 1,730.05 MWD (3) 4,070.83 48.26 248.25 3,419.26 3,299.88 -645.58 -1,734.70 5,959,252.83 496,886.20 1.42 1,766.59 MWD (3) 4,109.42 47.81 246.35 3,445.07 3,325.69 -656.65 -1,761.17 5,959,241.77 496,859.73 3.84 1,793.61 MWD (3) 4,159.11 47.53 243.87 3,478.53 3,359.15 -672.11 -1,794.49 5,959,226.32 496,826.41 3.73 1,827.71 MWD (3) 4,203.81 47.22 244.04 3,508.80 3,389.42 -686.55 -1,824.04 5,959,211.88 496,796.86 0.75 1,857.98 MWD (3) 4,254.03 46.93 244.94 3,543.00 3,423.62 -702.39 -1,857.23 5,959,196.05 496,763.68 1.43 1,891.97 MWD (3) 4,295.54 46.99 245.66 3,571.33 3,451.95 -715.06 -1,884.79 5,959,183.38 496,736.11 1.28 1,920.16 MWD (3) 4,348.91 47.32 245.20 3,607.63 3,488.25 -731.33 -1,920.38 5,959,167.12 496,700.53 0.88 1,956.57 MWD (3) 4,394.58 47.47 245.68 3,638.54 3,519.16 -745.31 -1,950.95 5,959,153.16 496,669.96 0.84 1,987.84 GYD-CT-CMS (4) 4,404.58 47.62 245.85 3,645.29 3,525.91 -748.33 -1,957.68 5,959,150.13 496,663.23 1.96 1,994.72 GYD-CT-CMS (4) 4,414.58 47.61 245.83 3,652.03 3,532.65 -751.36 -1,964.42 5,959,147.11 496,656.49 0.18 2,001.61 GYD-CT-CMS (4) 4,424.58 47.81 245.84 3,658.76 3,539.38 -754.39 -1,971.16 5,959,144.08 496,649.74 2.00 2,008.51 GYD-CT-CMS (4) 4,434.58 48.42 245.81 3,665.44 3,546.06 -757.43 -1,977.96 5,959,141.03 496,642.95 6.10 2,015.46 GYD-CT-CMS (4) 4,444.58 47.99 245.42 3,672.10 3,552.72 -760.51 -1,984.75 5,959,137.96 496,636.16 5.19 2,022.40 GYD-CT-CMS (4) 4,454.58 47.72 245.79 3,678.81 3,559.43 -763.57 -1,991.50 5,959,134.90 496,629.41 3.85 2,029.31 GYD-CT-CMS (4) 4,464.58 47.92 245.59 3,685.53 3,566.15 -766.63 -1,998.25 5,959,131.85 496,622.65 2.49 2,036.21 GYD-CT-CMS (4) 4,474.58 47.65 245.13 3,692.25 3,572.87 -769.71 -2,004.98 5,959,128.76 496,615.92 4.35 2,043.10 GYD-CT-CMS (4) 4,484.58 47.75 245.29 3,698.98 3,579.60 -772.81 -2,011.70 5,959,125.66 496,609.21 1.55 2,049.97 GYD-CT-CMS (4) 4,494.58 47.70 244.91 3,705.70 3,586.32 -775.93 -2,018.41 5,959,122.55 496,602.49 2.86 2,056.84 GYD-CT-CMS (4) 4,504.58 47.43 244.61 3,712.45 3,593.07 -779.08 -2,025.09 5,959,119.40 496,595.82 3.49 2,063.67 GYD-CT-CMS (4) 4,514.58 47.26 244.75 3,719.23 3,599.85 -782.22 -2,031.73 5,959,116.26 496,589.17 1.99 2,070.48 GYD-CT-CMS (4) 4,524.58 46.97 244.51 3,726.03 3,606.65 -785.36 -2,038.36 5,959,113.12 496,582.55 3.39 2,077.25 GYD-CT-CMS (4) 4,534.58 46.89 244.46 3,732.86 3,613.48 -788.51 -2,044.95 5,959,109.98 496,575.96 0.88 2,084.01 GYD-CT-CMS (4) 41544.58 46.84 244.46 3,739.70 3,620.32 -791.65 -2,051.53 5,959,106.83 496,569.37 0.50 2,090.75 GYD-CT-CMS (4) 4,554.58 46.79 244.49 3,746.54 3,627.16 -794.80 -2,058.11 5,959,103.69 496,562.79 0.55 2,097.49 GYD-CT-CMS (4) 4,564.58 46.83 244.67 3,753.39 3,634.01 -797.93 -2,064.70 5,959,100.56 496,556.21 1.37 2,104.23 GYD-CT-CMS (4) 4,574.58 46.71 244.48 3,760.24 3,640.86 -801.05 -2,071.28 5,959,097.44 496,549.63 1.83 2,110.97 GYD-CT-CMS (4) 4,584.58 46.52 244.65 3,767.10 3,647.72 -804.18 -2,077.84 5,959,094.32 496,543.07 2.27 2,117.69 GYD-CT-CMS (4) 4,594.58 46.62 245.50 3,773.98 3,654.60 -807.24 -2,084.43 5,959,091.26 496,536.48 6.25 2,124.42 GYD-CT-CMS (4) 4,604.58 46.65 245.59 3,780.85 3,661.47 -810.25 -2,091.04 5,959,088.25 496,529.86 0.72 2,131.19 GYD-CT-CMS (4) 4,614.58 46.85 246.04 3,787.70 3,668.32 -813.23 -2,097.69 5,959,085.27 496,523.22 3.84 2,137.99 GYD-CT-CMS (4) 4,624.58 47.40 246.46 3,794.50 3,675.12 -816.18 -2,104.40 5,959,082.32 496,516.51 6.30 2,144.84 GYD-CT-CMS (4) 4,634.58 47.65 246.42 3,801.25 3,681.87 -819.13 -2,111.16 5,959,079.37 496,509.75 2.52 2,151.75 GYD-CT-CMS (4) 4,644.58 47.59 246.57 3,807.99 3,688.61 -822.07 -2,117.93 5,959,076.43 496,502.98 1.26 2,158.67 GYD-CT-CMS (4) 4,654.58 48.14 246.07 3,814.70 3,695.32 -825.05 -2,124.72 5,959,073.45 496,496.18 6.63 2,165.61 GYD-CT-CMS (4) 4,664.58 47.89 246.19 3,821.39 3,702.01 -828.06 -2,131.52 5,959,070.44 496,489.39 2.65 2,172.56 GYD-CT-CMS (4) 4,674.58 47.87 246.44 3,828.10 3,708.72 -831.04 -2,138.31 5,959,067.46 496,482.59 1.87 2,179.50 GYD-CT-CMS (4) 4,684.58 48.12 246.45 3,834.79 3,715.41 -834.01 -2,145.12 5,959,064.50 496,475.78 2.50 2,186.46 GYD-CT-CMS (4) 4,694.58 48.10 246.50 3,841.47 3,722.09 -836.98 -2,151.95 5,959,061.53 496,468.96 0.42 2,193.43 GYD-CT-CMS (4) 121141201210:37:27AM Page 4 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: Conoco Phi IIips(Alaska) Inc. Local Co-ordinate Reference: Well 2A-27 Project: Kuparuk River Unit TVD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Site: Kuparuk 2A Pad MD Reference: Rig: 2A -27A @ 119.38ft (13141 (27.38+92)) Well: 2A-27 North Reference: True Wellbore: 2A -27A Survey Calculation Method: Minimum Curvature Design: 2A -27A Database: CPAI EDM Production Survey 12/14/2012 10:37:27AM Page 5 COMPASS 2003.16 Build 69 Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) V) V) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,704.58 48.09 246.50 3,848.15 3,728.77 -839.95 -2,158.77 5,959,058.56 496,462.13 0.10 2,200.41 GYD-CT-CMS (4) 4,714.58 48.10 246.46 3,854.83 3,735.45 -842.92 -2,165.60 5,959,055.59 496,455.31 0.31 2,207.38 GYD-CT-CMS (4) 4,724.58 48.02 246.35 3,861.51 3,742.13 -845.90 -2,172.42 5,959,052.62 496,448.49 1.14 2,214.35 GYD-CT-CMS (4) 4,734.58 47.83 246.23 3,868.21 3,748.83 -848.88 -2,179.21 5,959,049.63 496,441.70 2.10 2,221.29 GYD-CT-CMS (4) 4,744.58 47.61 246.33 3,874.94 3,755.56 -851.86 -2,185.99 5,959,046.66 496,434.92 2.32 2,228.21 GYD-CT-CMS (4) 4,754.58 47.58 246.47 3,881.68 3,762.30 -854.81 -2,192.75 5,959,043.70 496,428.16 1.08 2,235.13 GYD-CT-CMS (4) 4,764.58 47.59 246.64 3,888.43 3,769.05 -857.75 -2,199.53 5,959,040.77 496,421.38 1.26 2,242.05 GYD-CT-CMS (4) 4,774.58 47.62 246.60 3,895.17 3,775.79 -860.68 -2,206.30 5,959,037.84 496,414.60 0.42 2,248.97 GYD-CT-CMS (4) 4,784.58 47.59 246.54 3,901.91 3,782.53 -863.62 -2,213.08 5,959,034.90 496,407.83 0.54 2,255.90 GYD-CT-CMS (4) 4,794.58 47.53 246.50 3,908.66 3,789.28 -866.56 -2,219.85 5,959,031.96 496,401.06 0.67 2,262.81 GYD-CT-CMS (4) 4,804.58 47.75 246.03 3,915.40 3,796.02 -869.53 -2,226.61 5,959,028.99 496,394.30 4.11 2,269.72 GYD-CT-CMS (4) 4,814.58 47.63 245.68 3,922.13 3,802.75 -872.56 -2,233.36 5,959,025.97 496,387.55 2.85 2,276.62 GYD-CT-CMS (4) 4,824.58 47.47 245.88 3,928.88 3,809.50 -875.59 -2,240.09 5,959,022.94 496,380.82 2.18 2,283.50 GYD-CT-CMS (4) 4,834.58 47.72 245.85 3,935.62 3,816.24 -878.60 -2,246.83 5,959,019.92 496,374.08 2.51 2,290.39 GYD-CT-CMS (4) 4,844.58 48.00 245.95 3,942.33 3,822.95 -881.63 -2,253.60 5,959,016.90 496,367.31 2.90 2,297.31 GYD-CT-CMS (4) 4,854.58 47.97 245.91 3,949.03 3,829.65 -884.66 -2,260.38 5,959,013.87 496,360.53 0.42 2,304.25 GYD-CT-CMS (4) 4,864.58 48.18 245.67 3,955.71 3,836.33 -887.71 -2,267.17 5,959,010.82 496,353.74 2.76 2,311.19 GYD-CT-CMS (4) 4,874.58 49.46 244.90 3,962.29 3,842.91 -890.86 -2,274.00 5,959,007.67 496,346.91 14.05 2,318.18 GYD-CT-CMS (4) 4,884.58 49.57 244.74 3,968.78 3,849.40 -894.10 -2,280.89 5,959,004.44 496,340.02 1.64 2,325.23 GYD-CT-CMS (4) 4,894.58 48.88 244.66 3,975.31 3,855.93 -897.33 -2,287.73 5,959,001.21 496,333.18 6.93 2,332.24 GYD-CT-CMS (4) 4,904.58 48.27 244.74 3,981.93 3,862.55 -900.54 -2,294.51 5,958,998.00 496,326.40 6.13 2,339.18 GYD-CT-CMS (4) 4,914.58 48.35 244.86 3,988.58 3,869.20 -903.72 -2,301.27 5,958,994.82 496,319.64 1.20 2,346.09 GYD-CT-CMS (4) 4,924.58 48.38 244.89 3,995.23 3,875.85 -906.89 -2,308.04 5,958,991.65 496,312.87 0.37 2,353.02 GYD-CT-CMS (4) 4,934.58 48.83 244.65 4,001.84 3,882.46 -910.09 -2,314.82 5,958,988.46 496,306.09 4.85 2,359.97 GYD-CT-CMS (4) 4,944.58 48.56 243.88 4,008.44 3,889.06 -913.35 -2,321.59 5,958,985.20 496,299.32 6.38 2,366.90 GYD-CT-CMS (4) 4,954.58 48.39 244.72 4,015.07 3,895.69 -916.60 -2,328.33 5,958,981.95 496,292.58 6.51 2,373.81 GYD-CT-CMS (4) 4,964.58 48.65 245.70 4,021.69 3,902.31 -919.74 -2,335.14 5,958,978.81 496,285.77 7.79 2,380.76 GYD-CT-CMS (4) 4,974.58 48.58 245.23 4,028.30 3,908.92 -922.85 -2,341.96 5,958,975.70 496,278.95 3.60 2,387.75 GYD-CT-CMS (4) 4,977.58 48.51 245.06 4,030.29 3,910.91 -923.80 -2,344.00 5,958,974.75 496,276.91 4.85 2,389.83 GYD-CT-CMS (4) 4,994.58 48.46 244.87 4,041.56 3,922.18 -929.18 -2,355.53 5,958,969.37 496,265.38 0.89 2,401.64 GYD-CT-DMS (5) 5,019.58 49.00 244.95 4,058.05 3,938.67 -937.15 -2,372.55 5,958,961.41 496,248.36 2.17 2,419.05 GYD-CT-DMS (5) 5,044.58 49.01 244.84 4,074.45 3,955.07 -945.16 -2,389.64 5,958,953.40 496,231.27 0.33 2,436.54 GYD-CT-DMS (5) 51069.58 48.85 244.96 4,090.87 3,971.49 -953.15 -2,406.71 5,958,945.41 496,214.20 0.74 2,454.01 GYD-CT-DMS (5) 5,094.58 48.81 244.88 4,107.33 3,987.95 -961.13 -2,423.75 5,958,937.44 496,197.16 0.29 2,471.46 GYD-CT-DMS (5) 5,119.58 48.58 245.06 4,123.83 4,004.45 -969.08 -2,440.77 5,958,929.50 496,180.14 1.07 2,488.87 GYD-CT-DMS (5) 5,144.58 48.51 245.02 4,140.38 4,021.00 -976.98 -2,457.75 5,958,921.60 496,163.16 0.30 2,506.26 GYD-CT-DMS (5) 5,169.58 48.69 244.97 4,156.91 4,037.53 -984.91 -2,474.75 5,958,913.67 496,146.16 0.74 2,523.65 GYD-CT-DMS (5) 5,194.58 49.17 244.67 4,173.34 4,053.96 -992.93 -2,491.81 5,958,905.66 496,129.11 2.12 2,541.11 GYD-CT-DMS (5) 5,219.58 49.27 244.37 4,189.67 4,070.29 -1,001.07 -2,508.90 5,958,897.52 496,112.02 0.99 2,558.61 GYD-CT-DMS (5) 5,244.58 49.54 244.19 4,205.94 4,086.56 -1,009.31 -2,526.00 5,958,889.28 496,094.92 1.21 2,576.12 GYD-CT-DMS (5) 12/14/2012 10:37:27AM Page 5 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: 2A -27A Design: 2A -27A Survey MD Inc Azi TVD TVDSS +N/ -S (ft) (I (°I (ft) (ft) (ft) 5,269.58 49.77 244.19 4,222.12 4,102.74 -1,017.61 5,294.58 50.27 244.21 4,238.18 4,118.80 -1,025.94 5,319.58 50.68 244.54 4,254.09 4,134.71 -1,034.28 5,344.58 51.16 244.85 4,269.85 4,150.47 -1,042.58 5,369.58 51.98 245.17 4,285.39 4,166.01 -1,050.85 5,394.58 52.09 245.06 4,300.77 4,181.39 -1,059.15 5,419.58 52.41 245.17 4,316.08 4,196.70 -1,067.46 5,444.58 52.48 245.06 4,331.32 4,211.94 -1,075.80 5,454.00 52.37 245.03 4,337.06 4,217.68 -1,078.95 5,530.87 53.08 251.52 4,383.65 4,264.27 -1,101.56 5,575.62 50.13 255.42 4,411.44 4,292.06 -1,111.56 5,622.60 49.98 255.99 4,441.61 4,322.23 -1,120.45 5,717.23 49.70 257.48 4,502.64 4,383.26 -1,137.05 5,809.54 48.43 255.25 4,563.12 4,443.74 -1,153.47 5,901.60 48.23 254.81 4,624.33 4,504.95 -1,171.23 5,994.15 45.27 256.56 4,687.74 4,568.36 -1,187.92 6,086.04 42.27 262.08 4,754.11 4,634.73 -1,199.77 6,134.21 41.38 263.64 4,790.01 4,670.63 -1,203.77 6,178.26 39.16 266.74 4,823.62 4,704.24 -1,206.17 6,229.85 38.38 269.24 4,863.84 4,744.46 -1,207.31 6,270.60 37.78 271.10 4,895.92 4,776.54 -1,207.24 6,363.13 37.10 275.13 4,969.40 4,850.02 -1,204.20 6,456.32 37.50 281.78 5,043.56 4,924.18 -1,195.89 6,547.16 38.19 287.76 5,115.32 4,995.94 -1,181.68 6,639.73 38.61 289.46 5,187.87 5,068.49 -1,163.33 6,733.15 39.23 293.52 5,260.56 5,141.18 -1,141.82 6,823.86 39.75 296.89 5,330.57 5,211.19 -1,117.26 6,915.15 41.41 300.55 5,399.92 5,280.54 -1,088.70 7,012.31 41.55 305.14 5,472.72 5,353.34 -1,053.82 7,105.01 42.13 306.95 5,541.79 5,422.41 -1,017.43 7,197.62 42.78 311.54 5,610.13 5,490.75 -977.89 7,290.75 44.82 314.86 5,677.36 5,557.98 -933.76 7,383.42 45.39 319.42 5,742.78 5,623.40 -885.65 7,476.07 44.82 318.84 5,808.17 5,688.79 -836.02 7,565.75 46.14 320.04 5,871.05 5,751.67 -787.44 7,660.89 45.98 320.45 5,937.07 5,817.69 -734.77 7,753.71 45.41 320.15 6,001.90 5,882.52 -683.66 7,846.30 44.63 319.76 6,067.35 5,947.97 -633.53 7,938.97 43.84 319.25 6,133.75 6,014.37 -584.36 7,987.11 43.68 318.89 6,168.52 6,049.14 -559.21 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Map +E/ -W Northing (ft) (ft) -2,543.15 5,958,880.99 -2,560.40 5,958,872.66 -2,577.78 5,958,864.32 -2,595.33 5,958,856.03 -2,613.08 5,958,847.76 -2,630.96 5,958,839.47 -2,648.89 5,958,831.16 -2,666.87 5,958,822.82 -2,673.64 5,958,819.67 -2,730.42 5,958,797.08 -2,764.02 5,958,787.09 -2,798.92 5,958,778.20 -2,869.31 5,958, 761.62 -2,937.07 5,958,745.21 -3,003.50 5,958,727.46 -3,068.80 5,958,710.79 -3,131.20 5,958,698.95 -3,163.07 5,958,694.96 -3,191.43 5,958,692.56 -3,223.71 5,958,691.43 -3,248.84 5,958,691.51 -3,304.98 5,958,694.56 -3,360.77 5,958,702.87 -3,414.60 5,958,717.10 -3,469.08 5,958,735.46 -3,523.66 5,958,756.97 -3,575.84 5,958,781.54 -3,627.88 5,958,810.10 -3,681.91 5, 958, 844.99 -3,731.90 5,958,881.39 -3,780.28 5,958,920.93 -3,827.23 5,958,965.07 -3,871.85 5,959,013.18 -3,914.80 5,959,062.81 -3,956.37 5,959,111.40 -4,000.18 5,959,164.07 -4,042.61 5,959,215.18 -4,084.74 5,959,265.32 -4,126.72 5,959,314.48 -4,148.53 5,959,339.64 Well 2A-27 Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) True Minimum Curvature CPAI EDM Production Map Easting DLS (ft) (°/100') 496,077.76 0.92 496,060.52 2.00 496, 043.13 1.93 496,025.58 2.15 496,007.83 3.43 495, 989.95 495,972.02 495,954.04 495,947.28 495,890.50 495,856.90 495,822.00 495,751.62 495,683.86 495,617.43 495,552.13 495,489.74 495,457.87 495,429.51 495,397.24 495,372.11 495,315.97 495,260.19 495,206.37 495,151.89 495,097.32 495,045.16 494,993.13 494,939.11 494,889.13 494,840.76 494,793.83 494,749.22 494,706.29 494,664.73 494,620.93 494,578.52 494,536.40 494,494.43 494,472.62 0.56 1.33 0.45 1.19 6.78 9.49 0.98 1.24 2.29 0.42 3.48 5.28 2.84 6.79 3.39 3.18 2.75 4.34 4.11 1.23 2.81 2.43 3.18 3.13 1.44 3.42 3.30 3.54 0.76 1.75 0.35 0.66 0.89 0.93 0.61 Vertical Section (ft) Survey Tool Name 2,593.69 GYD-CT-DMS (5) 2,611.36 GYD-CT-DMS (5) 2,629.17 GYD-CT-DMS (5) 2,647.13 GYD-CT-DMS (5) 2,665.29 GYD-CT-DMS (5) 2,683.59 GYD-CT-DMS (5) 2,701.94 GYD-CT-DMS (5) 2,720.33 GYD-CT-DMS (5) 2,727.26 MWD+IFR-AK-CAZ-SC (6) 2,785.16 MWD+IFR-AK-CAZ-SC (6) 2,819.25 MWD+IFR-AK-CAZ-SC (6) 2,854.57 MWD+IFR-AK-CAZ-SC (6) 2,925.74 MWD+IFR-AK-CAZ-SC (6) 2,994.28 MWD+IFR-AK-CAZ-SC (6) 3,061.57 MWD+IFR-AK-CAZ-SC (6) 3,127.66 MWD+IFR-AK-CAZ-SC (6) 3,190.60 MWD+IFR-AK-CAZ-SC (6) 3,222.64 MWD+IFR-AK-CAZ-SC (6) 3,251.09 MWD+IFR-AK-CAZ-SC (6) 3,283.38 MWD+IFR-AK-CAZ-SC (6) 3,308.47 MWD+IFR-AK-CAZ-SC (6) 3,364.37 MWD+IFR-AK-CAZ-SC (6) 3,419.64 MWD+IFR-AK-CAZ-SC (6) 3,472.63 MWD+IFR-AK-CAZ-SC (6) 3,526.07 MWD+IFR-AK-CAZ-SC (6) 3,579.43 MWD+IFR-AK-CAZ-SC (6) 3,630.22 MWD+IFR-AK-CAZ-SC (6) 3,680.67 MWD+IFR-AK-CAZ-SC (6) 3,732.77 MWD+IFR-AK-CAZ-SC (6) 3,780.75 MWD+IFR-AK-CAZ-SC (6) 3,826.96 MWD+IFR-AK-CAZ-SC (6) 3,871.49 MWD+IFR-AK-CAZ-SC (6) 3,913.49 MWD+IFR-AK-CAZ-SC (6) 3,953.73 MWD+IFR-AK-CAZ-SC (6) 3,992.66 MWD+IFR-AK-CAZ-SC (6) 4,033.61 MWD+IFR-AK-CAZ-SC (6) 4,073.26 MWD+IFR-AK-CAZ-SC (6) 4,112.66 MWD+IFR-AK-CAZ-SC (6) 4,151.97 MWD+IFR-AK-CAZ-SC (6) 4,172.41 MWD+IFR-AK-CAZ-SC (6) 12/142012 10:37:27AM Page 6 COMPASS 2003.16 Build 69 Company: Project: Site: Well: Wellbore: Design: Survey ConocoPhillips (Alaska) Inc. Definitive Survey Report Conoco Phi Ilips(Alaska) Inc. Local Co-ordinate Reference: Well 2A-27 Kuparuk River Unit TVD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) Kuparuk 2A Pad MD Reference: Rig: 2A -27A @ 119.38ft (D141 (27.38+92)) 2A-27 North Reference: True 2A -27A Survey Calculation Method: Minimum Curvature 2A -27A Database: CPAI EDM Production Map Map Vertical MD Inc Azi TVD TVDSS +N/ -S +E/ -W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100-) :, (ft) Survey Tool Name 8,028.00 43.68 318.89 6,198.09 6,078.71 -537.93 -4,167.10 5,959,360.92 494,454.06 0.00 4,189.82 PROJECTED to TD 12/14/2012 10:37:27AM Page 7 COMPASS 2003.16 Build 69 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Commission Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 2A -27A 2A -27A 50-103-20604-01 2" x 5" MD TRIPLE COMBO Logs: 2" x 5" TVD TRIPLE COMBO Logs: Digital Log Images, LAS Data, & DLIS Data w/verification listing January 10, 2013 AK -MW -0009646426 1 Color Log 1 Color Log 1 CD ROM 112A -Z--k 22 X33 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Brvant@halliburton.com Benjamin.Schulze0halliburton.com Date: k za Signed: 1aa- WELL LOG TRANSMITTAL Zk2'Itno To: Alaska Oil and Gas Conservation Comm. January 3, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 f Anchorage, Alaska 99501 RE: Correlation Logs: 2A -27A Run Date: 12/19/2012 & 12/20/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -27A Digital Data in LAS format, Digital Log Image file 50-103-20604-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: WELL LOG TRANSMITTAL Z\2' SOC) To: Alaska Oil and Gas Conservation Comm. December 19, 2012 Attn.: Makana Bender 2 •Zq 25 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Correlation Log: 2A -27A Run Date: 12/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -27A Digital Data in LAS format, Digital Log Image file 50-103-20604-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Minton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: WELL LOG TRANSMITTAL z\'Z,- \O00 To: Alaska Oil and Gas Conservation Comm. December 17, 2012 Attn.: Makana Bender 2Z 9 2-7 333 West 7th Avenue, Suite 100 3 Anchorage, Alaska 99501 `f RE: CASTM/ACE : 2A -27A Run Date: 12/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -27A Data in LAS or DLIS format, Digital Log Image files 50-103-20604-01 ACE Log 50-103-20604-01 CAST -M Field print 50-103-20604-01 1 CD Rom 1 Color Log 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: Signed: 21Z-la'0 z �\\D WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 2A -27A Run Date: 12/6/2012 December 11, 2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -27A Digital Data in LAS format, Digital Log Image file 50-103-20604-01 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: 1 3 Signed: Nju,- !� 001� SEAN PARNELL, GOVERNOR ALASKA OIL AATD GAS 333 W 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Haibin Guo Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -27A ConocoPhillips Alaska, Inc. Permit No: 212-100 Surface Location: 476' FSL, 227' FWL, SEC. 13, T11N, R08E, UM Bottomhole Location: 74' FNL, 1336' FWL, SEC. 23, T11N, R08E, UM Dear Mr. Guo: Enclosed is the approved application for permit to redrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, A/1464d /_r� Cathj P. Foerster Chair DATED this 7, 4day of August, 2012. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 RECEIVED JUL 2 4 niz AOGCC 1a Type of Work Drill ❑ Re-dnll ❑✓ Re-entry ❑ lb Proposed Well Class: Development - Oil ❑ Service - Win) ❑✓ Single Zone ❑ Stratigraphic Test ❑ Development - Gas ❑ Service - Supply ❑ Multiple Zone ❑✓ Exploratory ❑ Service - WAG ❑ Service - Disp ❑ 1 c Specify if well is proposed for: Coalbed Gas ❑ Gas Hydrates ❑ Shale Gas ❑ 2 Operator Name: ConocoPhillips Alaska, Inc. 5 Bond ✓ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 2A -27A 3 Address P.O. Box 100360 Anchorage, AK 99510-0360 6 Proposed Depth: MD: 8017' • TVD: 6180' ' 12. Field/Pool(s): Kuparuk River Field Kuparuk River Oil Pool 4a Location of Well (Governmental Section): Surface: 476' FSL, 227' FWL, Sec. 13, T11 N, R08E, UM Top of Productive Horizon 364' FNL, 1605' FWL, Sec 23, T11 N, R08E, UM Total Depth: 74' FNL, 1336' FWL, Sec. 23, T1IN, R08E, UM 7. Property Designation (Lease Number) ADL 25570 - 8. Land Use Permit 2668 13. Approximate Spud Date 9/17/2012 9. Acres in Property 2560 14. Distance to Nearest Property > 1 mile 4b. Location of Well (State Base Plane Coordinates - NAD 27) Surface: x- 498621 • y- 5959898 ' Zone- 4 10. KB Elevation above MSL 120 feet GL Elevation above MSL: r29 et D7'�• 15. Distance to Nearest Well Open Same Pool: 2A-06, 5500' 16 Deviated wells Kickoff depth 5450 ft. Maximum Hole Angle: 54' deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25 035) Downhole: 2500 psig Surface: 1906 psig 18 Casing Program Specifications Top - Setting Depth - Bottom Cement Quantity, c.f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD(including stage data 8.75" 7" 26# L-80 BCTM 2768' 5250' 4211' 8017' 6180' 278 sx LiteCRETE, 195 sx Class G 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re -Entry Operations) Total Depth MD (ft) Total Depth TVD (ft), Plugs (measured) 7271' 5434' 6692 Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) 6692' 5075 Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 12 cu yds AS 1 154' 154' Surface 3340' 13.375" 530 sx AS Lite, 390 sx LiteCRETE 3374' 2931' Intermediate 6816' 9.625" 678 sx Class G 6849' 5172' Production Liner 553' 7" 26 bbls Class G 7248' 5433' Perforation Depth MD (ft):Perforation 7244'-7259', 7241'-7256' Depth TVD (ft): 5415'-5425', 5412'-5421' 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 Date 22. 1 hereby certify that the foregoing is true and correct. Contact Haibin Guo @ 265-1487 (� U� Jain/ �I Printed Name G. L. Alvord r✓o2 Title Manager, Alaska Drilling Date 7//F,//2— Signature ICtt1 p A L�/>Y= O Phon 26&6120/2(,5 ,2 Commission Use Only Permit to Drill pay Number. Z/ 2- `CX i API Number: / l/ / ✓ ^ Permit Approval Date See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coal beim�lhane, gas hydrates, or gas contained in shales * 3S0 o SOS.% B61' /,s t Samples req'd: Yes ❑ N( 2 Mud log req'd: Yes ❑ No [✓� Other: 1 H22S measures: Yes [/No ❑ Directional svy req'd: Yes [r No El MI1A € C -L r� u w • APPR VED BY THE COMMISSION DATE: I COMMISSIONER Form 10 401 (Revised 7/2009) This permit is valid for-niprith4,fjofr jh;•d�tepU. proval (20 qAC 25.005(g)) Sub in upli to ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 July 02, 2011 Alaska Oil and Gas Conservation Commission 333 West 7t' Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill Rotary Sidetrack 2A -27A Water Injector Dear Commissioner: CO ocoPhilfi S p RECEIVED JUL 2 0 2W AOGCC ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill/Sidetrack an onshore water injection well from the 2A pad. The expected spud date for this well is September 17, 2012 conducting operations with Rig Doyon 141. The 2A-27 well was drilled as an intervention well to P&A 2A-06. 2A-06 was successfully plugged and permanently abandoned in 2009.2A-27 wellbore has been cemented and suspended since December 10, 2009. The proposed plan is to pull the 4-1/2" tubing and set a 9-5/8" retainer at 5,471' MD with a permanent whipstock on top at 5,450 MD / 4,337' - TVD. Next, an 8-3/4" window will be cut plus 20' of new formation. A formation integrity test will be performed to 16.0 ppg EMW, with a required minimum leak -off of 12.5 ppg EMW. The open hole section will then be drilled with an 8-3/4" PDC bit to +/- 8,017' MD / 6,180' TVD. It will be lined from 8,018' MD to 5,250' MD with 7" 26# L-80 casing. The 7" liner will be cemented to top of liner packer at +/- 5,250'MD. A CBL will be conducted to ensure good cement setting. TCP guns will be run to perforate the A and C sands. A 3-1/2" tubing selective injection string will be run with two packers at +/- 7,425' MD and +/- 7,645' MD. Doyon 141 will then rig down and move off. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Haibin Guo at 265-1487 or Chip Alvord at 265-6120. Sincerely, �/� �'��xla LIQ �OLI-E`�-P �1�2�LL�►J4� ENGING-�Z1Nli �5'��(�E-{1.U�Sc�t2) Chip Alvord Drilling Manager Application for Permit to Drill Document Kuparuk Well 2A -27A Well Name Requirements of 20 AAC 25.005 (f) The well for which this application is submitted will be designated as 2A -27A 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, Location at Surface 476' FSL, 227' FWL, Sec 13, T 11N, R08E, UM NGS Coordinates Northings: 5,959,897.8' Eastings: 498,620.8' RKB Elevation 120.0' AMSL Pad Elevation 92.0' AMSL Location at Top of Productive Interval Ku aruk C Sand NGS Coordinates Northings: 5,959,349.7' Eastings: 494,450.1' 364' FNL, 1,605' FWL, Sec 23, TI IN, R08E, UM NGS Coordinates Northings: 5,959,081.0' Eastings: 494,669.5' Measured Depth, RKB: 7,458' Total Vertical Depth, RKB: 5,786' Total Vertical De th, SS: 5,666' Location at Total Depth 74' FNL, 1,336' FWL, Sec 23, T11N, R08E, UM NGS Coordinates Northings: 5,959,349.7' Eastings: 494,450.1' Measured Depth, RKB: 8,017' Total Vertical Depth, RKB: 6,180' Total Vertical Depth, SS: 6,060' 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: Directional Plan Well 2A-27 was drilled as an intervention well to P&A 2A-06. 2A-06 was successfully plugged and permanently abandoned in 2009. Well 2A -27A, the new sidetrack well, will be kicked off from 2A-27 at +/- 5,450' MD/ 4,337' TVD which is close to 2A -06.2A-06 is at the left of kick off point and 2A-27 will turn right from the kick off. So the possibility of collision is low. 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 shoir 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. GINAL Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill insist be accompanied by each of the following items, except for an item already on file x•dh the commission and identified in the application (3) a diagram and description of the blowout prevention equipment (BOPS) 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 141. 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 alreadv on file with the commission and identified in the application: (?) information on drilling ha=ards, including (A) the maximum downhole pressure that may be encountered, criteria used to determine it, and maximums potential surface pressure based on a methane gradient, The maximum potential surface pressure (MPSP) while drilling 2A -27A is calculated using a maximum reservoir pressure of 2,500 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 5,937' TVD (WP 16): A Sand SIBHP = 2,500 psi A Sand estimated depth (WP06) = 5,937' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = (5,937' TVD * 0.10 psi/ft) MPSP = SIBHP — gas column T 1,906 psi (2,500 psi — 594 psi) (B) data on potential gas =ones, 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 =ones. and zones that have a propensity for differential sticking. See attached 2A -27A Drilling Hazards Summary 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 tinder 20 AAC 25 0300, i ,/ A procedure is on file with the commission for performing LOT's. For 2A -27A the formation integrity test of the intermediate hole will occur after milling the window and 20' of new formation. The formation at the window depth will be pressured until leak -off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 12.5 ppg EMW must be obtained. On1p, j JA 1A 1 t 't � � 1. 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 thefollowing 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 Program Single Stage Cement Program Cement will be placed from the TD to 100' above the top of liner. The liner shoe will be at 8,017' MD and the top of liner set at 5,250' MD (approximately 200'of overlap inside the existing 9-5/8" casing). The slurry consists of 278 sacks of 12.5 ppg LiteCRETE lead slurry and 195 sacks of Class G 15.8 ppg tail slurry with 40% excess. Cement System Spacer: 50 bbls MudPush II / Slurry: 7 acks 12.5 ppg LiteCRETE cement slurry + additives Yield = 1.54 ft3/sx� 95 sacks ✓ 15.8 ppg Class G cement slurry + additives Yield = 1.17 ft3/sx --- Lead Slurry Volumes Casing OD Hole Size weight (lb/ft) Grade Connection Length Top MD/TVD Btm MD/TVD --------------------------------- -------- - - 9.5/8" x 7" L-------------------------1---------------------------1 20" Conduct 94.0 H-40 Weld 120' Surface = 34' 154' / 154' 40% 33 338 or -Open -- 7" ---- 195 i Original 200 58 0% j 58 ; 37.7 --------------- - 9-5/8" x 5"1 --------------------------------------------------------------------------- ------------------------- - ' Wellbore 13-3/8" 16" 68 L-80 BTC/TII 2,341' Surface 33' 3,374' / 2,931' 9-5/8" 12-1/4" 40 1180 BTC/TI1 6,662' Surface 32' 6,849' / 5,171' Sidetrack Out of 7" Liner 8-3/4" 26 L-80 BCTM 2,768' 5,250' / 4,21 1' 8,017 / 6180' 9-5/8" Casing' 3-1/2" Tubing 9.3 L-80 EUE 7,397' Surface z 28' 7,425' / 5,763' Single Stage Cement Program Cement will be placed from the TD to 100' above the top of liner. The liner shoe will be at 8,017' MD and the top of liner set at 5,250' MD (approximately 200'of overlap inside the existing 9-5/8" casing). The slurry consists of 278 sacks of 12.5 ppg LiteCRETE lead slurry and 195 sacks of Class G 15.8 ppg tail slurry with 40% excess. Cement System Spacer: 50 bbls MudPush II / Slurry: 7 acks 12.5 ppg LiteCRETE cement slurry + additives Yield = 1.54 ft3/sx� 95 sacks ✓ 15.8 ppg Class G cement slurry + additives Yield = 1.17 ft3/sx --- Lead Slurry Volumes Length ft Capacity ft Excess Total (ft3) Total (sacks) Liner Lap 1 200--------- 32i --------------------------------- -------- - - 9.5/8" x 7" L-------------------------1---------------------------1 -150 -T ---%--------�----------32---------- i -��=g--------- ------------------------------ Hole x Liner OD 1,568 241 40% 33 338 219.5 -Open -- 7" ---- 195 i -------------------------------8-3/4" To of liner ca � p p• 200 58 0% j 58 ; 37.7 --------------- - 9-5/8" x 5"1 --------------------------------------------------------------------------- ------------------------- - ' - + ; Total 428 278 Lead Slurry Volumes Length Capacity ------------------------------------------(ft)---------- (ft )----------•--------------------- Excess Total (ft3) Total (sacks) -------- Hole x Liner OD > --------------------------- ------------------------------ 40°(� 21o_s ' lso ----Open „ 8-3/4 x 7" -1,000 -150 -T - -� Shoe Track ID 80 ----------------------I---------- 17 '; ------------------------------------ ----------------------------- 0% 17 i 7.5 14 4.5 -------..........----- Total i -- -- 1 227.5 ---- 195 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 lath 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); This rotary sidetrack will exit pre-existing 9-5/8" casing at 5,450' MD. BOPE will be installed prior to exiting the casing, and therefore no diverter is required. 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; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis (cp) PV YP Loss pH Comments (cc/30min) Milling Fluid I 9.6-9.8 j 50-60 15-20 50-60 NC j 10.5-11 Milling fluid can be reconditioned 5,450'_5,521' i i ---✓ i-------------------i----------------1 I i --------------'-------------------------I---------------- for dillin sidetrack ----------------------------- - LSNDI 9.5-10.0 60-80 25-35 I 7-8 <6 ' 9.5-10 i Milling Fluid: A 9.8 ppg viscosified water based milling fluid consisting of pH control and weighting agents will be used to cut the 8-3/4" window and 20' of new formation. This fluid will maintain good rheology to remove metal fragments from the wellbore and prevent their recirculation. The milling fluid can be reconditioned for use in the sidetrack. Sidetrack Fluid: A 9.5 — 10.0 ppg LSND drilling fluid will be used to drill to 8,017' MD / 6,180' TVD. The drilling mud weight is calculated using A/C Sand EMW o8.2 pg plus 0.8 ppg error margin and 0.5 ppg trip margin to result in a 9.5 ppg. Fluid weight will have su ent density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Rea uirements of 20 AAC 25.005 (c1(9) N/A - Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) N/A - Application is not for an exploratory or stratigraphic test well. 0 R I G1 �,, A L Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 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 follow to/� Items, except for an item already on Erle with the commission and identified in the application su�� e �, �Ci� 5��. '+�+ �L 7. z 7 - I -L- 2A-27 2A-27 was temporarily P&A in December 2009: a. Cement plugs were set to the top of 7" liner @6,694' MD / 5,076' TVD. b. 2,067' 4-1/2" tubing was hanging below tubing hanger as kill string. 1. Move Doyon 141 on 2A-27and rig up. 2. Pull BPV. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. k & L-1 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low / 3,500 psi high as per drilling permit. • BOP test cycle is one week until mill window to 20' new foramtion. • Upper pipe ram will be 3-1/2" X 7" VBR. • Lower pipe ram will be 2-7/8" X 6" VBR. • A FOSV is to be kept on the floor at all times with pertinent X/Os for DP or casing thread in rotary table. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 4-1/2" tubing. 1/4 ' 5. Run 9-5/8" casing scraper to tag the top of cement plug. !--_� -7--., � ! cs f `j /4 c-'5; 1.5Z6 P S` • Spot a weighted pill with corrosion inhibitor between cement plug and cement retainer. 6. Rig up E -line, run guns to perforate 9-5/8" casing at +/-5,480' MD (+/- 8' below casing collar) for cement squeeze. 7. Set 9-5/8" cement retainer bottom at +/-5,464' MD (+/- 8' above casing collar). 8. Squeeze 25 bbls cement into perforations. 9. Pick up 9-5/8" whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock. 10. Set whipstock and mill window in 9-5/8" plus 20' of new formation for FIT/LOT. Perform FIT with rig pump as per CPAI procedure up to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. I • BOP test cycle is two weeks from this point. IW 11. Pull out of hole whipstock/milling assembly and gauge mills. �I y„ 12. Pick-up and make up 8-3/4" PDC bit with 6-3/4" LWD/MWD drilling BHA. /I Y 13. Run in hole with drilling BHA to top of window and displace to 9.5 ppg drilling mud. 14. Drill 8-3/4" hole from 5,450' MD to 8,017' MD. 15. At total depth, circulate hole clean and wiper trip to window. Once back on bottom, circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. 16. Run 7", 26 ppf, L-80 liner to TD. Top of liner will be +/-200' above window. 17. Cement liner to top with 12.5pgg lead and 15.8 ppg tail slurry with 40% excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. /j, t 18. Monitor well then pull out of hole laying down drill pipe. 19. R/U Wireline to tun CBL for 7" liner. 20. Run perforate guns with eline and perforate the C and A sands( 7,574'— 7,633'; 7,672'— 7,755' MD) 21. Run selective injection upper completion string as per procedure. 22. MIT tubing and IA and chart for 30 min. 23. N/U X-mas tree. Perform freeze protect. 24. RD and MO Doyon 141. 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 to the application: (1 4) 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 authort_ahon under 20 AAC 25 080 for an annular disposal operation in the well; Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic it*�L�•E.. .3- ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 2A Pad 2A-27 Plan: 2A -27A Plan: 2A -27A (wp16) Standard Proposal Report 29 June, 2012 OR I G I N A L HALLIBURTON Sperry Drilling Services HALLIBURTON Project: Kuparuk River Unit Annotation WELL DETAILS: 2A-27 Ground Level: 92.00 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot al lo4mrm Io.rvla.. Site: Kuparuk 2A Pad Well: 2A-27 Kup C @ 7458' MD, 5786' TVD: 364' FNL, 1605' FWL- Sec23-T11N-R08E Wellbore: Plan: 2A -27A 0.00 0.00 5959898.03 498620.85 70° 18'6,005 N 150° 0'40.214 W Plan: 2A -27A (wp16) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well 2A-27, True North Vertical (TVD) Reference: Plan: 2A-27120.00ft (D141 (28+92)) 500 Measured Depth Reference: Plan: 2A-27 (M 120.00ft (D141 (28+92)) Calculation Method: Minimum Curvature CASING DETAILS: 2A -27A (wpl6) MD TVD TVDSS Name Size Hole Size 148.20 148.20 28.20 20 20 20 250 3367.27 2924.31 2804.31 13 3/8" 13-3/8 16 5450.02 4334.87 4214.87 9 5/8" TOW 9-5/8 12-1/4 8016.98 6180.00 6060.00 7" 7 8-1/2 TD @ 8017' MD, 6180' TVD: 74' FNL, 1336' FWL - Sec23-TI IN-RO8E 2A -27A (wp16) DDI = 5.996 i i Kup A3 @ 7699' MD, 5956' TVD: 239' FNL, 1489' FWL- Sec23-Tl1N-R08E 7" G_ g -750 f 2A -27;A I r DD Polygon L p -1000 y 1500 -1750 -2000 -4250 -4000 -3750 -3500 -3250 West(-YEast(+) (300 Win) -3000 T M Azimuths to True North Magnetic North: 20.22° Magnetic Field Strength: 57618.7snT Dip Angle: 80.90' Date: 9/17/2012 Model: BGGM2011 -2750 -2500 -225 ✓ ConocoMillips Alaska ANNOTATIONS TVD MD Annotation 1334.87 5450.02 TOW @ 5450' MD, 4335' TVD: 601' FNL, 2444' FEL- Sec23-T11N-R08E i786.10 7458.28 Kup C @ 7458' MD, 5786' TVD: 364' FNL, 1605' FWL- Sec23-T11N-R08E i956.00 7699.26 Kup A3 @ 7699' MD, 5956' TVD: 239' FNL, 1489' FWL - Sec23-T11 N -ROSE 5180.00 8016.98 TD @ 8017' MD, 6180' TVD: 74' FNL, 1336' FWL- Sec23-T11N-R08E -4250 -4000 -3750 -3500 -3250 West(-YEast(+) (300 Win) -3000 T M Azimuths to True North Magnetic North: 20.22° Magnetic Field Strength: 57618.7snT Dip Angle: 80.90' Date: 9/17/2012 Model: BGGM2011 -2750 -2500 -225 ✓ ConocoMillips Alaska 0 F- ALLISURTON Sperry Drilling Services 4250- 9 5/8" TO 4500 4750 5000 Ground Level: 9200. +N/ -S +E/.W Northing Easting 0 t5250 0.00 0.00 5959898.03 498620.85 700 I8' 6.005 N 1500 0'40,214 W E FORMATION TOP DETAILS n. N TVDPath TVDssPath 0 m --5500 -Top HRZ------ 5727.42 5607.42 a) H 7458.28 Kuparuk C-4 Base HRZ (Kalubik) 5750--- 5918.10 5798.10 -4B - Kuparuk C -4- -1--------- B-1 - - - - - - - - - -,A-6 - - - - - - - - A-6-------- 6000 6000 MD TVD TVDSS 6250 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: Plan: 2A -27A Design: 2A -27A (wp16) 6500 2250 2500 2750 3000 3250 WELL DETAILS: 2A-27 NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 9200. +N/ -S +E/.W Northing Easting Latittude Longitude Slot 0.00 0.00 5959898.03 498620.85 700 I8' 6.005 N 1500 0'40,214 W FORMATION TOP DETAILS TVDPath TVDssPath MDPath Formation 5473.00 5353.00 7020.20 Top HRZ 5727.42 5607.42 7375.05 Base HRZ (Kalubik) 5786.10 5666.10 7458.28 Kuparuk C-4 5884.40 5764.40 7597.71 B-1 5918.10 5798.10 7645.51 A-6 CASING DETAILS MD TVD TVDSS Name Size Hole Size 148.20 148.20 28.20 20 20 20 3367.27 2924.31 2804.31 13 3/8" 13-3/8 16 5450.02 4334.87 4214.87 9 5/8" TOW 9-5/8 12-1/4 8016.98 6180.00 6060.00 7" 7 8-1/2 Kup C @ 7458' MD, 5786' TVD: 364' FNL, 1605' FWL- Sec23-T11N-R08E Kup A3 @ 7699' MD, 5956' TVD: 239' FNL, 1489' FWL - Sec23-T11N-R08E TD @ 8017 MD, 6180' TVD: 74' FNL, 1336' FWL - Sec23-TI IN-R08E 7- - - - - - - - - - --- - -- 21 P,P i� 3500 3750 4000 4250 4500 4750 5000 5"-, ---- Vertical - "Vertical Section at 266.95° (350 ft/in) ConocoPhillips Alaska HALLIBURTON Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: Plan: 2A -27A Design: 2A -27A (wpl6) Halliburton - Sperry Standard Proposal Report Local Co-ordinate Reference: Well 2A-27 TVD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) MD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) North Reference: True Survey Calculation Method: Minimum Curvature 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 Site Kuparuk 2A Pad Site Position: Northing: 5,960,138.24ft Latitude: 70° 18'8.367 N From: Map Easting: 498,621.00ft Longitude: 150'0'40.211W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.01 ° Well 2A-27 Well Position +N/ -S 0.00 ft Northing: 5,959,898.03 ft Latitude: 70° 18'6.005 N +EI -W 0.00 ft Easting: 498,620.85 ft Longitude: 150° 0'40.214 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: , 92.00 ft Wellbore Plan: 2A -27A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2011 9/17/2012 20.22 80.90 57,619 Design 2A -27A (wp16) Audit Notes: Version: Phase: PLAN Tie On Depth: 5,450.00 Vertical Section: Depth From (TVD) +N/ -S +E/ -W Direction Turn (ft) (ft) (ft) (I Depth 28.00 0.00 0.00 266.95 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/ -S +E/ -W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 5,450.00 52.42 245.04 4,334.86 4,214.86 -1,077.41 -2,670.32 0.00 0.00 0.00 0.00 5,466.50 54.03 247.00 4,344.74 4,224.74 -1,082.78 -2,682.40 13.60 9.72 11.88 45.00 5,496.50 54.03 247.00 4,362.36 4,242.36 -1,092.26 -2,704.75 0.00 0.00 0.00 0.00 5,746.50 49.03 247.00 4,517.85 4,397.85 -1,168.70 -2,884.86 2.00 -2.00 0.00 180.00 6,431.98 39.30 289.76 5,020.00 4,900.00 -1,197.09 -3,338.38 4.50 -1.42 6.24 123.00 6,819.67 39.30 289.76 5,320.00 5,200.00 -1,114.06 -3,569.50 0.00 0.00 0.00 0.00 7,203.10 45.17 317.11 5,606.19 5,486.19 -972.07 -3,778.26 5.00 1.53 7.13 82.86 7,699.26 45.17 317.11 5,956.00 5,836.00 -714.25 -4,017.72 0.00 0.00 0.00 0.00 8,016.98 45.17 317.11 6,180.00 6,060.00 -549.17 -4,171.06 0.00 0.00 0.00 0.00 6/29/2012 5:38:10PM Page 2 COMPASS 2003.16 Build 69 � ? 4��AI Halliburton - Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2A-27 Company: ConocoPhiilips (Alaska) Inc. -Kup2 TVD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Project: Kuparuk River Unit MD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Site: Kuparuk 2A Pad North Reference: True Well: 2A-27 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2A -27A Depth Inclination Design: 2A -27A (wp16) TVDss +N/ -S Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -92.00 28.00 0.00 0.00 28.00 -92.00 0.00 0.00 5,959,898.03 498,620.85 0.00 0.00 95.20 0.19 8.34 95.20 -24.80 0.11 0.02 5,959,898.14 498,620.86 0.28 -0.02 148.20 0.25 339.47 148.20 28.20 0.31 -0.01 5,959,898.34 498,620.83 0.24 0.00 20 195.20 0.34 325.63 195.20 75.20 0.52 -0.13 5,959,898.55 498,620.72 0.24 0.10 255.20 0.11 315.10 255.20 135.20 0.71 -0.27 5,959,898.74 498,620.58 0.39 0.23 312.77 0.57 345.63 312.77 192.77 1.02 -0.38 5,959,899.05 498,620.47 0.83 0.32 407.21 0.68 348.53 407.20 287.20 2.03 -0.61 5,959,900.06 498,620.24 0.12 0.50 494.81 1.07 349.69 494.79 374.79 3.34 -0.86 5,959,901.37 498,619.99 0.45 0.68 589.11 1.66 293.07 589.07 469.07 4.74 -2.27 5,959,902.77 498,618.58 1.48 2.01 683.15 4.92 251.46 682.95 562.95 3.99 -7.35 5,959,902.02 498,613.50 4.08 7.13 777.20 7.41 249.83 776.45 656.45 0.62 -16.87 5,959,898.65 498,603.98 2.65 16.81 868.07 9.72 253.07 866.30 746.30 -3.63 -29.71 5,959,894.40 498,591.14 2.60 29.86 961.40 10.39 253.51 958.20 838.20 -8.32 -45.31 5,959,889.72 498,575.53 0.72 45.69 1,054.00 12.29 247.92 1,048.99 928.99 -14.39 -62.46 5,959,883.65 498,558.39 2.37 63.13 1,147.41 13.64 244.44 1,140.01 1,020.01 -22.88 -81.61 5,959,875.16 498,539.24 1.67 82.71 1,240.35 15.06 244.43 1,230.05 1,110.05 -32.82 -102.38 5,959,865.23 498,518.46 1.53 103.99 1,333.15 17.21 245.92 1,319.19 1,199.19 -43.63 -125.80 5,959,854.43 498,495.05 2.36 127.94 1,425.93 19.08 248.18 1,407.36 1,287.36 -54.87 -152.41 5,959,843.20 498,468.44 2.15 155.11 1,519.05 23.00 248.71 1,494.25 1,374.25 -67.13 -183.50 5,959,830.94 498,437.35 4.21 186.81 1,611.33 25.98 250.73 1,578.22 1,458.22 -80.35 -219.39 5,959,817.72 498,401.47 3.35 223.35 1,702.68 29.48 249.87 1,659.07 1,539.07 -94.70 -259.39 5,959,803.39 498,361.46 3.86 264.06 1,794.65 32.49 250.88 1,737.90 1,617.90 -110.58 -303.99 5,959,787.52 498,316.87 3.32 309.44 1,888.61 33.39 251.31 1,816.76 1,696.76 -127.13 -352.32 5,959,770.98 498,268.53 0.99 358.59 1,979.60 35.67 251.35 1,891.71 1,771.71 -143.64 -401.18 5,959,754.48 498,219.68 2.51 408.26 2,071.48 37.50 251.30 1,965.49 1,845.49 -161.17 -453.06 5,959,736.95 498,167.80 1.99 460.99 2,167.22 39.55 250.29 2,040.39 1,920.39 -180.80 -509.37 5,959,717.34 498,111.50 2.24 518.26 2,259.65 40.35 248.80 2,111.24 1,991.24 -201.55 -564.97 5,959,696.61 498,055.90 1.35 574.89 2,352.40 42.50 248.06 2,180.79 2,060.79 -224.11 -622.03 5,959,674.05 497,998.84 2.38 633.07 2,444.05 43.73 248.86 2,247.69 2,127.69 -247.11 -680.29 5,959,651.07 497,940.57 1.47 692.48 2,537.01 43.76 249.91 2,314.85 2,194.85 -269.74 -740.45 5,959,628.46 497,880.42 0.78 753.76 2,630.08 44.48 248.52 2,381.66 2,261.66 -292.73 -801.02 5,959,605.47 497,819.85 1.30 815.47 2,723.09 42.72 247.48 2,449.01 2,329.01 -316.75 -860.49 5,959,581.47 497,760.38 2.04 876.13 2,815.75 42.05 247.53 2,517.46 2,397.46 -340.65 -918.20 5,959,557.58 497,702.67 0.72 935.03 2,908.37 41.80 249.23 2,586.37 2,466.37 -363.45 -975.73 5,959,534.80 497,645.15 1.26 993.69 3,001.24 41.07 251.10 2,656.00 2,536.00 -384.31 -1,033.53 5,959,513.95 497,587.34 1.55 1,052.52 3,093.16 42.52 251.21 2,724.52 2,604.52 -404.09 -1,091.51 5,959,494.18 497,529.37 1.58 1,111.47 3,185.29 43.11 249.04 2,792.11 2,672.11 -425.39 -1,150.39 5,959,472.90 497,470.50 1.72 1,171.39 3,277.93 43.25 246.39 2,859.67 2,739.67 -449.42 -1,209.03 5,959,448.87 497,411.85 1.96 1,231.23 3,331.81 43.79 247.86 2,898.74 2,778.74 -463.84 -1,243.22 5,959,434.46 497,377.67 2.13 1,266.13 3,367.27 43.93 248.72 2,924.31 2,804.31 -472.93 -1,266.04 5,959,425.38 497,354.84 1.72 1,289.41 13 3/8" 3,419.90 44.16 249.98 2,962.14 2,842.14 -485.83 -1,300.28 5,959,412.48 497,320.60 1.72 1,324.29 3,464.17 44.11 250.29 2,993.91 2,873.91 -496.31 -1,329.28 5,959,402.01 497,291.61 0.50 1,353.80 3,511.72 43.36 249.11 3,028.27 2,908.27 -507.71 -1,360.11 5,959,390.62 497,260.78 2.33 1,385.19 6/29/2012 5:38: 1OPM Page 3 0 �4q COMPASS 2003.16 Build 69 Planned Survey Halliburton - Sperry HALL I B U R TO N Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 2A-27 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Project: Kuparuk River Unit MD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Site: Kuparuk 2A Pad North Reference: True Well: 2A-27 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2A -27A Depth Inclination Design: 2A -27A (wp16) Depth TVDss Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) V) V) (ft) ft (ft) (ft) (ft) (ft) 2,939.93 3,555.04 42.72 249.42 3,059.93 2,939.93 -518.18 -1,387.76 5,959,380.16 497,233.13 1.56 1,413.36 3,601.99 42.93 249.51 3,094.36 2,974.36 -529.37 -1,417.64 5,959,368.97 497,203.25 0.47 1,443.80 3,649.28 43.04 249.08 3,128.96 3,008.96 -540.77 -1,447.80 5,959,357.57 497,173.09 0.66 1,474.53 3,706.76 43.45 249.93 3,170.83 3,050.83 -554.56 -1,484.69 5,959,343.80 497,136.20 1.24 1,512.09 3,749.86 43.86 250.58 3,202.01 3,082.01 -564.61 -1,512.69 5,959,333.75 497,108.20 1.41 1,540.59 3,797.27 44.22 250.90 3,236.09 3,116.09 -575.48 -1,543.81 5,959,322.89 497,077.09 0.89 1,572.24 3,834.11 46.05 250.23 3,262.08 3,142.08 -584.17 -1,568.43 5,959,314.20 497,052.47 5.13 1,597.29 3,884.89 48.34 250.43 3,296.58 3,176.58 -596.71 -1,603.51 5,959,301.67 497,017.39 4.52 1,632.99 3,926.66 49.00 250.21 3,324.17 3,204.17 -607.27 -1,633.04 5,959,291.12 496,987.86 1.63 1,663.04 3,969.97 48.73 249.78 3,352.66 3,232.66 -618.43 -1,663.69 5,959,279.96 496,957.21 0.97 1,694.24 4,019.99 48.54 249.15 3,385.71 3,265.71 -631.60 -1,698.85 5,959,266.80 496,922.05 1.02 1,730.05 4,071.45 48.26 248.25 3,419.88 3,299.88 -645.58 -1,734.70 5,959,252.83 496,886.20 1.42 1,766.59 4,110.04 47.81 246.35 3,445.69 3,325.69 -656.65 -1,761.17 5,959,241.77 496,859.73 3.84 1,793.61 4,159.73 47.53 243.87 3,479.15 3,359.15 -672.11 -1,794.49 5,959,226.32 496,826.41 3.73 1,827.71 4,204.43 47.22 244.04 3,509.42 3,389.42 -686.55 -1,824.04 5,959,211.88 496,796.86 0.75 1,857.98 4,254.65 46.93 244.94 3,543.62 3,423.62 -702.39 -1,857.23 5,959,196.05 496,763.68 1.43 1,891.97 4,296.16 46.99 245.66 3,571.95 3,451.95 -715.06 -1,884.79 5,959,183.38 496,736.11 1.28 1,920.16 4,349.53 47.32 245.20 3,608.25 3,488.25 -731.33 -1,920.38 5,959,167.12 496,700.53 0.88 1,956.57 4,395.20 47.47 245.68 3,639.16 3,519.16 -745.31 -1,950.95 5,959,153.16 496,669.96 0.84 1,987.84 4,405.20 47.62 245.85 3,645.91 3,525.91 -748.33 -1,957.68 5,959,150.13 496,663.23 1.96 1,994.72 4,415.20 47.61 245.83 3,652.65 3,532.65 -751.36 -1,964.42 5,959,147.11 496,656.49 0.18 2,001.61 4,425.20 47.81 245.84 3,659.38 3,539.38 -754.39 -1,971.16 5,959,144.08 496,649.74 2.00 2,008.51 4,435.20 48.42 245.81 3,666.06 3,546.06 -757.43 -1,977.96 5,959,141.03 496,642.95 6.10 2,015.46 4,445.20 47.99 245.42 3,672.72 3,552.72 -760.51 -1,984.75 5,959,137.96 496,636.16 5.19 2,022.40 4,455.20 47.72 245.79 3,679.43 3,559.43 -763.57 -1,991.50 5,959,134.90 496,629.41 3.85 2,029.31 4,465.20 47.92 245.59 3,686.15 3,566.15 -766.63 -1,998.25 5,959,131.85 496,622.65 2.49 2,036.21 4,475.20 47.65 245.13 3,692.87 3,572.87 -769.71 -2,004.98 5,959,128.76 496,615.92 4.35 2,043.10 4,485.20 47.75 245.29 3,699.60 3,579.60 -772.81 -2,011.70 5,959,125.66 496,609.21 1.55 2,049.97 4,495.20 47.70 244.91 3,706.32 3,586.32 -775.93 -2,018.41 5,959,122.55 496,602.49 2.86 2,056.84 4,505.20 47.43 244.61 3,713.07 3,593.07 -779.08 -2,025.09 5,959,119.40 496,595.82 3.49 2,063.67 4,515.20 47.26 244.75 3,719.85 3,599.85 -782.22 -2,031.73 5,959,116.26 496,589.17 1.99 2,070.48 4,525.20 46.97 244.51 3,726.65 3,606.65 -785.36 -2,038.36 5,959,113.12 496,582.55 3.39 2,077.25 4,535.20 46.89 244.46 3,733.48 3,613.48 -788.51 -2,044.95 5,959,109.98 496,575.96 0.88 2,084.01 4,545.20 46.84 244.46 3,740.32 3,620.32 -791.65 -2,051.53 5,959,106.83 496,569.37 0.50 2,090.75 4,555.20 46.79 244.49 3,747.16 3,627.16 -794.80 -2,058.11 5,959,103.69 496,562.79 0.55 2,097.49 4,565.20 46.83 244.67 3,754.01 3,634.01 -797.93 -2,064.70 5,959,100.56 496,556.21 1.37 2,104.23 4,575.20 46.71 244.48 3,760.86 3,640.86 -801.05 -2,071.28 5,959,097.44 496,549.63 1.83 2,110.97 4,585.20 46.52 244.65 3,767.72 3,647.72 -804.18 -2,077.84 5,959,094.32 496,543.07 2.27 2,117.69 4,595.20 46.62 245.50 3,774.60 3,654.60 -807.24 -2,084.43 5,959,091.26 496,536.48 6.25 2,124.42 4,605.20 46.65 245.59 3,781.47 3,661.47 -810.25 -2,091.04 5,959,088.25 496,529.86 0.72 2,131.19 4,615.20 46.85 246.04 3,788.32 3,668.32 -813.23 -2,097.69 5,959,085.27 496,523.22 3.84 2,137.99 4,625.20 47.40 246.46 3,795.12 3,675.12 -816.18 -2,104.40 5,959,082.32 496,516.51 6.30 2,144.84 4,635.20 47.65 246.42 3,801.87 3,681.87 -819.13 -2,111.16 5,959,079.37 496,509.75 2.52 2,151.75 4,645.20 47.59 246.57 3,808.61 3,688.61 -822.07 -2,117.93 5,959,076.43 496,502.98 1.26 2,158.67 4,655.20 48.14 246.07 3,815.32 3,695.32 -825.05 -2,124.72 5,959,073.45 496,496.18 6.63 2,165.61 6/29/2012 5:38:1OPM Page 4 COMPASS 2003.16 Build 69 0 R I G I IN! Planned Survey Halliburton - Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Coordinate Reference: Well 2A-27 Company: ConocoPhillips (Alaska) Inc. -Kup2 TVD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Project: Kuparuk River Unit MD Reference: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Site: Kuparuk 2A Pad North Reference: True Well: 2A-27 Survey Calculation Method: Minimum Curvature Wellbore: Plan: 2A -27A Depth Inclination Design: 2A -27A (wpl6) Depth TVDss Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (1 C) (ft) ft (ft) (ft) (ft) (ft) 3,702.01 4,665.20 47.89 246.19 3,822.01 3,702.01 -828.06 -2,131.52 5,959,070.44 496,489.39 2.65 2,172.56 4,675.20 47.87 246.44 3,828.72 3,708.72 -831.04 -2,138.31 5,959,067.46 496,482.59 1.87 2,179.50 4,685.20 48.12 246.45 3,835.41 3,715.41 -834.01 -2,145.12 5,959,064.50 496,475.78 2.50 2,186.46 4,695.20 48.10 246.50 3,842.09 3,722.09 -836.98 -2,151.95 5,959,061.53 496,468.96 0.42 2,193.43 4,705.20 48.09 246.50 3,848.77 3,728.77 -839.95 -2,158.77 5,959,058.56 496,462.13 0.10 2,200.41 4,715.20 48.10 246.46 3,855.45 3,735.45 -842.92 -2,165.60 5,959,055.59 496,455.31 0.31 2,207.38 4,725.20 48.02 246.35 3,862.13 3,742.13 -845.90 -2,172.42 5,959,052.62 496,448.49 1.14 2,214.35 4,735.20 47.83 246.23 3,868.83 3,748.83 -848.88 -2,179.21 5,959,049.63 496,441.70 2.10 2,221.29 4,745.20 47.61 246.33 3,875.56 3,755.56 -851.86 -2,185.99 5,959,046.66 496,434.92 2.32 2,228.21 4,755.20 47.58 246.47 3,882.30 3,762.30 -854.81 -2,192.75 5,959,043.70 496,428.16 1.08 2,235.13 4,765.20 47.59 246.64 3,889.05 3,769.05 -857.75 -2,199.53 5,959,040.77 496,421.38 1.26 2,242.05 4,775.20 47.62 246.60 3,895.79 3,775.79 -860.68 -2,206.30 5,959,037.84 496,414.60 0.42 2,248.97 4,785.20 47.59 246.54 3,902.53 3,782.53 -863.62 -2,213.08 5,959,034.90 496,407.83 0.54 2,255.90 4,795.20 47.53 246.50 3,909.28 3,789.28 -866.56 -2,219.85 5,959,031.96 496,401.06 0.67 2,262.81 4,805.20 47.75 246.03 3,916.02 3,796.02 -869.53 -2,226.61 5,959,028.99 496,394.30 4.11 2,269.72 4,815.20 47.63 245.68 3,922.75 3,802.75 -872.56 -2,233.36 5,959,025.97 496,387.55 2.85 2,276.62 4,825.20 47.47 245.88 3,929.50 3,809.50 -875.59 -2,240.09 5,959,022.94 496,380.82 2.18 2,283.50 4,835.20 47.72 245.85 3,936.24 3,816.24 -878.60 -2,246.83 5,959,019.92 496,374.08 2.51 2,290.39 4,845.20 48.00 245.95 3,942.95 3,822.95 -881.63 -2,253.60 5,959,016.90 496,367.31 2.90 2,297.31 4,855.20 47.97 245.91 3,949.65 3,829.65 -884.66 -2,260.38 5,959,013.87 496,360.53 0.42 2,304.25 4,865.20 48.18 245.67 3,956.33 3,836.33 -887.71 -2,267.17 5,959,010.82 496,353.74 2.76 2,311.19 4,875.20 49.46 244.90 3,962.91 3,842.91 -890.86 -2,274.00 5,959,007.67 496,346.91 14.05 2,318.18 4,885.20 49.57 244.74 3,969.40 3,849.40 -894.10 -2,280.89 5,959,004.44 496,340.02 1.64 2,325.23 4,895.20 48.88 244.66 3,975.93 3,855.93 -897.33 -2,287.73 5,959,001.21 496,333.18 6.93 2,332.24 4,905.20 48.27 244.74 3,982.55 3,862.55 -900.54 -2,294.51 5,958,998.00 496,326.40 6.13 2,339.18 4,915.20 48.35 244.86 3,989.20 3,869.20 -903.72 -2,301.27 5,958,994.82 496,319.64 1.20 2,346.09 4,925.20 48.38 244.89 3,995.85 3,875.85 -906.89 -2,308.04 5,958,991.65 496,312.87 0.37 2,353.02 4,935.20 48.83 244.65 4,002.46 3,882.46 -910.09 -2,314.82 5,958,988.46 496,306.09 4.85 2,359.97 4,945.20 48.56 243.88 4,009.06 3,889.06 -913.35 -2,321.59 5,958,985.20 496,299.32 6.38 2,366.90 4,955.20 48.39 244.72 4,015.69 3,895.69 -916.60 -2,328.33 5,958,981.95 496,292.58 6.51 2,373.81 4,965.20 48.65 245.70 4,022.31 3,902.31 -919.74 -2,335.14 5,958,978.81 496,285.77 7.79 2,380.76 4,975.20 48.58 245.23 4,028.92 3,908.92 -922.85 -2,341.96 5,958,975.70 496,278.95 3.60 2,387.75 4,978.20 48.51 245.06 4,030.91 3,910.91 -923.80 -2,344.00 5,958,974.75 496,276.91 4.85 2,389.83 4,995.20 48.46 244.87 4,042.18 3,922.18 -929.18 -2,355.53 5,958,969.37 496,265.38 0.89 2,401.64 5,020.20 49.00 244.95 4,058.67 3,938.67 -937.15 -2,372.55 5,958,961.41 496,248.36 2.17 2,419.05 5,045.20 49.01 244.84 4,075.07 3,955.07 -945.16 -2,389.64 5,958,953.40 496,231.27 0.33 2,436.54 5,070.20 48.85 244.96 4,091.49 3,971.49 -953.15 -2,406.71 5,958,945.41 496,214.20 0.74 2,454.01 5,095.20 48.81 244.88 4,107.95 3,987.95 -961.13 -2,423.75 5,958,937.44 496,197.16 0.29 2,471.46 5,120.20 48.58 245.06 4,124.45 4,004.45 -969.08 -2,440.77 5,958,929.50 496,180.14 1.07 2,488.87 5,145.20 48.51 245.02 4,141.00 4,021.00 -976.98 -2,457.75 5,958,921.60 496,163.16 0.30 2,506.26 5,170.20 48.69 244.97 4,157.53 4,037.53 -984.91 -2,474.75 5,958,913.67 496,146.16 0.74 2,523.65 5,195.20 49.17 244.67 4,173.96 4,053.96 -992.93 -2,491.81 5,958,905.66 496,129.11 2.12 2,541.11 5,220.20 49.27 244.37 4,190.29 4,070.29 -1,001.07 -2,508.90 5,958,897.52 496,112.02 0.99 2,558.61 5,245.20 49.54 244.19 4,206.56 4,086.56 -1,009.31 -2,526.00 5,958,889.28 496,094.92 1.21 2,576.12 5,270.20 49.77 244.19 4,222.74 4,102.74 -1,017.61 -2,543.15 5,958,880.99 496,077.76 0.92 2,593.69 6/29/2012 5:38:10PM Page 5 COMPASS 2003.16 Build 69 0 R-,,,.. I G I'i,�, _ HALLIBURTON Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: Plan: 2A -27A Design: 2A -27A (wp16) Planned Survey Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton - Sperry Standard Proposal Report Well 2A-27 Plan: 2A-27 @ 120.00ft (D141 (28+92)) Plan: 2A-27 @ 120.00ft (D141 (28+92)) True Minimum Curvature Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (I V) (ft) ft (ft) (ft) (ft) (ft) 4,118.80 5,295.20 50.27 244.21 4,238.80 4,118.80 -1,025.94 -2,560.40 5,958,872.66 496,060.52 2.00 2,611.36 5,320.20 50.68 244.54 4,254.71 4,134.71 -1,034.28 -2,577.78 5,958,864.32 496,043.13 1.93 2,629.17 5,345.20 51.16 244.85 4,270.47 4,150.47 -1,042.58 -2,595.33 5,958,856.03 496,025.58 2.15 2,647.13 5,370.20 51.98 245.17 4,286.01 4,166.01 -1,050.85 -2,613.08 5,958,847.76 496,007.83 3.43 2,665.29 5,395.20 52.09 245.06 4,301.39 4,181.39 -1,059.15 -2,630.96 5,958,839.47 495,989.95 0.56 2,683.59 5,420.20 52.41 245.17 4,316.70 4,196.70 -1,067.46 -2,648.89 5,958,831.16 495,972.02 1.33 2,701.94 5,445.20 52.48 245.06 4,331.94 4,211.94 -1,075.80 -2,666.87 5,958,822.82 495,954.04 0.45 2,720.33 5,450.00 52.42 245.04 4,334.86 4,214.86 -1,077.41 -2,670.32 5,958,821.22 495,950.59 1.23 2,723.86 5,450.02 • 52.42 245.04 4,334.87 4,214.87 -1,077.42 -2,670.34 5,958,821.21 495,950.58 0.00 2,723.88 TOW @ 5450' MD, 4335' TVD: 601' FNL, 2444' FEL - Sec23-T11 N-R08E - 9 518" TOW 5,466.50 54.03 247.00 4,344.74 4,224.74 -1,082.78 -2,682.40 5,958,815.85 495,938.52 13.62 2,736.21 5,496.50 54.03 247.00 4,362.36 4,242.36 -1,092.26 -2,704.75 5,958,806.37 495,916.17 0.00 2,759.03 5,500.00 53.96 247.00 4,364.42 4,244.42 -1,093.37 -2,707.35 5,958,805.27 495,913.56 2.00 2,761.69 5,600.00 51.96 247.00 4,424.66 4,304.66 -1,124.55 -2,780.82 5,958,774.10 495,840.10 2.00 2,836.72 5,700.00 49.96 247.00 4,487.65 4,367.65 -1,154.89 -2,852.31 5,958,743.78 495,768.61 2.00 2,909.72 5,746.50 49.03 247.00 4,517.85 4,397.85 -1,168.70 -2,884.86 5,958,729.97 495,736.06 2.00 2,942.95 5,800.00 47.75 249.73 4,553.39 4,433.39 -1,183.45 -2,922.03 5,958,715.23 495,698.90 4.50 2,980.85 5,900.00 45.54 255.13 4,622.06 4,502.06 -1,205.44 -2,991.27 5,958,693.25 495,629.65 4.50 3,051.17 6,000.00 43.61 260.92 4,693.33 4,573.33 -1,220.05 -3,059.85 5,958,678.66 495,561.08 4.50 3,120.43 6,100.00 41.99 267.10 4,766.74 4,646.74 -1,227.19 -3,127.34 5,958,671.53 495,493.59 4.50 3,188.21 6,200.00 40.72 273.64 4,841.84 4,721.84 -1,226.81 -3,193.33 5,958,671.93 495,427.61 4.50 3,254.08 6,300.00 39.83 280.47 4,918.17 4,798.17 -1,218.92 -3,257.41 5,958,679.83 495,363.54 4.50 3,317.65 6,400.00 39.36 287.49 4,995.26 4,875.26 -1,203.56 -3,319.18 5,958,695.20 495,301.78 4.50 3,378.51 6,431.98 39.30 289.76 5,020.00 4,900.00 -1,197.09 -3,338.38 5,958,701.67 495,282.58 4.50 3,397.35 6,500.00 39.30 289.76 5,072.63 4,952.63 -1,182.52 -3,378.93 5,958,716.25 495,242.04 0.00 3,437.06 6,600.00 39.30 289.76 5,150.01 5,030.01 -1,161.11 -3,438.54 5,958,737.67 495,182.43 0.00 3,495.45 6,700.00 39.30 289.76 5,227.40 5,107.40 -1,139.69 -3,498.16 5,958,759.09 495,122.83 0.00 3,553.84 6,800.00 39.30 289.76 5,304.78 5,184.78 -1,118.28 -3,557.77 5,958,780.52 495,063.23 0.00 3,612.23 6,819.67 39.30 289.76 5,320.00 5,200.00 -1,114.06 -3,569.50 5,958,784.73 495,051.50 0.00 3,623.72 6,900.00 39.97 295.97 5,381.88 5,261.88 -1,094.16 -3,616.65 5,958,804.65 495,004.36 5.00 3,669.75 7,000.00 41.24 303.40 5,457.85 5,337.85 -1,061.92 -3,673.08 5,958,836.89 494,947.94 5.00 3,724.38 7,020.20 41.56 304.85 5,473.00 5,353.00 -1,054.43 -3,684.14 5,958,844.38 494,936.88 5.00 3,735.02 Top HRZ 7,100.00 42.97 310.40 5,532.07 5,412.07 -1,021.66 -3,726.59 5,958,877.15 494,894.44 5.00 3,775.67 7,203.10 45.17 317.11 5,606.19 5,486.19 -972.07 -3,778.26 5,958,926.75 494,842.79 5.00 3,824.63 7,300.00 45.17 317.11 5,674.51 5,554.51 -921.72 -3,825.02 5,958,977.11 494,796.03 0.00 3,868.65 7,375.05 45.17 317.11 5,727.42 5,607.42 -882.72 -3,861.25 5,959,016.11 494,759.82 0.00 3,902.74 Base HRZ (Kalubik) 7,400.00 45.17 317.11 5,745.01 5,625.01 -869.75 -3,873.29 5,959,029.07 494,747.79 0.00 3,914.08 7,458.28 45.17 317.11 5,786.10 5,666.10 -839.47 -3,901.42 5,959,059.36 494,719.67 0.00 3,940.56 Kup C @ 7458' MD, 5786' TVD: 364' FNL, 1605' FWL - Sec23-T11 N-R08E - Kuparuk C-4 7,500.00 45.17 317.11 5,815.51 5,695.51 -817.79 -3,921.55 5,959,081.04 494,699.54 0.00 3,959.51 7,597.71 45.17 317.11 5,884.40 5,764.40 -767.02 -3,968.71 5,959,131.81 494,652.39 0.00 4,003.90 B-1 7,600.00 45.17 317.11 5,886.02 5,766.02 -765.83 -3,969.81 5,959,133.00 494,651.29 0.00 4,004.94 612912012 5:38:10PM Page 6 COMPASS 2003.16 Build 69 R y, HALLIBURTON Database: EDM 2003.16 Single User Db Company: ConocoPhillips (Alaska) Inc. -Kup2 Project: Kuparuk River Unit Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: Plan: 2A -27A Design: 2A -27A (wp16) Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Halliburton - Sperry Standard Proposal Report Well 2A-27 Plan: 2A-27 @ 120.00ft (D141 (28+92)) Plan: 2A-27 @ 120.00ft (D141 (28+92)) True Minimum Curvature Planned Survey Vertical Depth Depth (ft) (ft) 5,450.02 Measured Vertical 7,458.28 5,786.10 Map Map 8,016.98 6,180.00 Depth Inclination Azimuth Depth TVDss +N/ -S +E/ -W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 5,798.10 7,645.51 45.17 317.11 5,918.10 5,798.10 -742.19 -3,991.78 5,959,156.65 494,629.33 0.00 4,025.61 A-6 7,699.26 45.17 317.11 5,956.00 5,836.00 -714.25 -4,017.72 5,959,184.58 494,603.40 0.00 4,050.03 Kup A3 @ 7699' MD, 5956' TVD: 239' FNL, 1489' FWL - Sec23-T11 N-R08E - 2A -27A A3 (wpl5) 7,800.00 45.17 317.11 6,027.02 5,907.02 -661.91 -4,066.34 5,959,236.93 494,554.79 0.00 4,095.80 7,900.00 45.17 317.11 6,097.53 5,977.53 -609.95 -4,114.60 5,959,288.90 494,506.54 0.00 4,141.23 8,000.00 45.17 317.11 6,168.03 6,048.03 -557.99 4,162.87 5,959,340.86 494,458.29 0.00 4,186.66 8,016.98 45.17 317.11 6,180.00 • 6,060.00 -549.17 -4,171.06 5,959,349.68 494,450.10 0.00 4,194.37 Targets Target Name hlVmiss target Dip Angle Dip Dir. TVD +N/ -S +E/ -W Northing Easting Shape (°) (I (ft) (ft) (ft) (ft) (ft) 2A -27A A3 (wp15) 0.00 5,956.00 -714.25 -4,017.72 5,959,184.58 494,603.40 plan hits target center Circle (radius 150.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (11) 3,367.27 2,924.31 13 3/8" 13-3/8 16 8,016.98 6,180.00 7" 7 8-1/2 148.20 148.20 20 20 20 5,450.02 4,334.87 9 5/8" TOW 9-5/8 12-1/4 Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Llthology (°) (°) 7,458.28 5,786.10 Kuparuk C-4 0.00 7,597.71 5,884.40 B-1 0.00 7,645.51 5,918.10 A-6 0.00 7,375.05 5,727.42 Base HRZ (Kalubik) 0.00 7,020.20 5,473.00 Top HRZ 0.00 Plan Annotations Measured Vertical Depth Depth (ft) (ft) 5,450.02 4,334.87 7,458.28 5,786.10 7,699.26 5,956.00 8,016.98 6,180.00 6/29/2012 5:38:10PM Local Coordinates +N/ -S +E/ -W (ft) (ft) -1,077.42 -2,670.34 -839.47 -3,901.42 -714.26 -4,017.72 -549.17 -4,171.06 Comment TOW @ 5450' MD, 4335' TVD: 601' FNL, 2444' FEL - Sec23-T11 N-R08E Kup C @ 7458' MD, 5786' TVD: 364' FNL, 1605' FWL - Sec23-T11 N-R08E Kup A3 @ 7699' MD, 5956' TVD: 239' FNL, 1489' FWL - Sec23-T11 N-R08E TD @ 8017' MD, 6180' TVD: 74' FNL, 1336' FWL - Sec23-T11 N-R08E Page 7 COMPASS 2003.16 Build 69 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2A Pad - 2A-27 - Plan: 2A -27A - 2A -27A (wp16) Well Coordinates: 5,959,648.55 N, 1,638,653.38 E (70° 18'04.91" N, 150° 00'51.42" W) Datum Height: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Scan Range: 5,450.00 to 8,016.65 fL Measured Depth. Scan Radius is 998.86 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HALLIBURTON Sperry Drilling Services SURVEY PROGRAM Date: 2012416-29TI70:00:00 Validated: Yes Version: Depth From Depth To Survey/Plan Tool 95.20 255.20 2A-27 (2A-27) CB -GYRO -SS 312.77 3331.81 2427 MND (2A-27) MWD+IFR-AK-CAZSC 3419.90 4349.53 2A-27 MND (2A-27) MWD 439.5.20 4978.20 2427 RR4 (2A-27) GYD-CT-CMS 4995.20 5450.00 2A-27 RR5 (2A-27) GYD-CT-DMS 5450.00 8016.65 2A -27A (wp16) (Plan: 2A -27A) MWD+IFR-AK-CAZ-SC NO GLOBAL FILTER: Using user defined selection & filtering criteria 2N 0 180 2A-06 Tamil ConocoPhiilips (Alaska) Inc. -Kup2 Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Tray. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 90 'Gravelling Cylinder Azimuth (TFO+AGI)°J vs Centre to Centre Separation 1200 ft/in] Details: 2A-27 North American Datum 1983 Alaska Zone 4 Ground Level: 92.00 +N/ -S +E/ -W Northing Easting Latittude Longitude Slot 0.00 0.00 5959648.55 1638651.38 70' 18'4.913 N 150' 0' 51.416 W From Colour To MD 5450 5500 5500 5750 5750 6000 6000 6500 6500 7000 7000 8500 270 ANTI -COLLISION SETTINGS Interpolation Method: MD, interval: 25.00 Depth Range From: 5450.00 To 8016.65 Centre Distance: 998.86 Reference: Plan: 2A -27A (wp16)(2A-27/Plan: 2A -27A) 2A-2 t1 1i0 2A-0 ' 2A -O6 Targ 90 Travelling Cylinder Azimuth (TFO+A7.I) 1°I vs Centre to Centre Separation 150 ft/inl SECTION DETAILS: 2A -27A (wp16) Sec MD IncAr TVD TVDSS +N/ -S +E/ -W Northing Easting DLeg TFace vs - 1 5450.00 52.42 245.04 4334.86 4214.86 -1077.41 -2670.32 5958571.88 1635983.07 0.00 0.00 2723.86 2 5466.50 54.03 247.00 4344.74 4224.74 -1082.78 -2682.40 5958566.51 1635971.00 13.60 45.00 2736.21 3 5496.50 54.03 247.00 4362.16 4242.36 -1092.26 -2704.75 5958557.03 1635948.65 0.00 0.00 2759.03 4 5746.50 49.03 247.00 4517.85 4397.85 -1168.70 -2884.86 5958480.64 1635768.54 2.00 180.00 2942.95 56431.98 39.30 289.76 5020.00 4900.00 -1197.09 -3338.38 5958452.36 1635315.05 4.50 123.00 3397.35 6 68 19.6 7 39.30 289.76 5320.00 5200.00 -1114.06 -3569.50 5958535.43 1635083.98 0.00 0.00 3623.72 7 7202.60 45.15 317.09 5605.86 5485.86 -972.33 -3777.99 5958677.20 1634875.54 5.00 82.89 3824.37 45.15 317.09 -714.56 -4017.61 _00 0.00 0.00 4049.94 2A -27A A3 (wp15) 9 8016.65 45.15 317.09 8180.00 6060.00 319.08 -4170.91 5959099.92 1634482.78 0.00 0.00 419425 ConocoPhillips (Alaska) Inc. -Kup2 HALLIRURTON Kuparuk River Unit Anticollision Report for 2A-27 - 2A -27A (wpl6) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2A Pad - 2A-27 - Plan: 2A -27A - 2A -27A (wp16) Scan Range: 5,450.00 to 8,016.65 ft. Measured Depth. Scan Radius is 998.86 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name - Design (ft) (ft) (ft) (ft) ft Kuparuk 2A Pad _2A-06 Target - 2A-06 Target - 2A-06 Target — 2A-06 - 2A-06 - 2A-06 — 2A-06 - 2A-06 - 2A-06 5,745.34 20.92 5,745.34 M6,775.01 i Factor W - Major Risk 2A-27 - 2A-27 - 2A-27 5,470.19 0.51 5,470.19 ori �tor ajor Risk �—y Survey tool program ....i From To 95.20 255.20 312.77 3,331.81 3,419.90 4,349.53 4,395.20 4,978.20 4,995.20 5,450.00 5,450.00 8,016.65 2A -27A (wp16) Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool CB -GYRO -SS MWD+IFR-AK-CAZ-S C MWD GYD-CT-CMS GYD-CT-DMS MWD+IFR-AK-CAZ-SC 03 July, 2012 - 16:07 Page 2 of 4 COMPASS HALLIRURTOMI Anticollision Report for 2A-27 - 2A -27A (wp16) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: 2A-27 @ 120.00ft (D141 (28+92)). Northing and Easting are relative to 2A-27. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.01 °. CD -71 0 0 M C O M MI O- N U) N L c N U O O L c N U Ladder 0 1500 3000 4500 6000 7500 Measured Depth (1500 Win) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit :01:01C 2A -06,2A -06,2A -06V1 # _2A-06 Target, 2A-06 Target, 2A-06 Target VO 2A-01, 2A-01, 2A-01 V2 2A -01A, 2A -01A, 2A-01AV2 2A -02,2A -02,2A-02 V1 2A-03, 2A-03, 2A-03 V1 $ 2A -04,2A -04,2A -04V1 - 2A -05,2A -05,2A -05V1 2A -07,2A -07,2A-07\/2 2A -09,2A -09,2A-09\/2 �E- 2A-18, 2A-18, 2A-18 VO 2A -26,2A -26,2A-26 VO 2A-27, 2A-27, 2A-27 VO $ 2A-27A(wp16) 03 July, 2012 - 16.07 Page 3 of 4 COMPASS HALLIBURTON Anticollision Report for 2A-27 - 2A -27A (wpl6) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 10. I I � 8.75— � 7.50--- cI • N - $ o _ $ v m I LL c 5.00- . 0 CU _ Q 3.7 U) 2 1.25 0. 0 750 1500 2250 3000 3750 4500 5250 6000 6750 7500 8250 9000 Measured Depth (1500 ftfi n) ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit LEGEND 2A -06,2A -06,2A-06 V1 2A-06 Target, 2A-06 Target, 2A-06 Target VO 2A -01,2A -01,2A-01 V2 2A -01A, 2A -01A, 2A-01AV2 2A -02,2A -02,2A -02V1 2A -03,2A -03,2A-03 V1 2A -04,2A -04,2A-04 V1 2A -05,2A -05,2A-05 V1 2A -07,2A -07,2A -07V2 2A -09,2A -09,2A-09 V2 2A-18, 2A -18,2A-1 8 VO 2A -26,2A -26,2A-26 VO 2A -27,2A -27,2A-27 VO 2A -27A (wp16) 03 July, 2012 - 16:07 Page 4 of 4 COMPASS c e«.- tw- ConocoPhillips Kuparuk River Unit Kuparuk 2A Pad 2A-27 Plan: 2A -27A 2A -27A (wp16) (Alaska) Inc. -Kup2 Sperry Drilling Services Anticollision Report 03 July, 2012 Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: Kuparuk 2A Pad - 2A-27 - Plan: 2A -27A - 2A -27A (wp16) Well Coordinates: 5,959,648.55 N, 1,638,653.38 E (70° 18' 04.91" N, 150° 00' 51.42" W) Datum Height: Plan: 2A-27 @ 120.00ft (D141 (28+92)) Scan Range: 5,450.00 to 8,016.65 ft. Measured Depth. Scan Radius is 940.27 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 69 Scan Type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Interval: 25.00 HALLIBURTON vW0.1 4,346.88 15.77 5,500.00m 4,361.370 28.38 19.29 166.5E 5,495.13 4,361.56 15.83 5,525.00 4,376.320 28.5 19.60 167.14 5,520.18 4,376.35 15.89 5,550.00 4,391.2 28.71 19.88 167.71 5,545.23 4,391.32 15.94 5,575.00 4,406.21 28.88 20.09 168.2E 5,570.28 4,406.47 16.00 5,600.00 4,421.16 29.05 20.24 168.8E 5,595.33 4,421.79 16.05 5,625.00 4,436.13 29.22 20.34 169.44 5,620.37 4,437.27 16.11 5,650.00 4,451.13 29.38 20.41 170.07 5,645.40 4,452,92 16.17 5,675.00 4,466.18 29.5 20.46 170.6C 5,670.41 4,468.73 16.22 5,700.00 4,481.2 29.72 20.51 171.18 5,695.41 4,484.70 16.28 5,725.00 4,496.3 29.89 20.58 171.76 5,720.39 4,500.82 16.3 5,750.00 4,511.4 30.05 20.70 172.34 5,745.3 4,517.09 16.40 5,775.00 4,526.56 30.22 20.92 172.93 5,769.93 4,533.30 16.45 5,800.00 4,541.66 30.39 21.45 173.51 5,794.45 4,549.66 16.51 5,825.00 4,556.7 30.56 22.57 174.06 5,818.89 4,566.1 16.57 5,850.00 4,571.87 30.73 24.27 174.58 5,843.2 4,582.7 16.62 5,875.00 4,586.990 30.90 26.56 175.06 5,867.49 4,599.43 16.67 5,900.00 4,602.1 31.07 29.41 175.51 5,891.61 4,616.20 16.73 5,925.00 4,617.29 31.2 32.83 175.94 5,915.59 4,633.01 16.78 5,950.00 4,632.4 31.40 36.81 176.33 5,939.41 4,649.86 16.84 5,975.00 4,647.59 31.57 41.33 176.70 5,963.05 4,666.72 16.89 6,000.00 4,662.7 31.7 46.36 177.03 5,986.51 4,683.58 16.95 6,025.00 4,677.88 31.91 51.86 177.33 6.009.77 4,700.41 17.00 6,050.00 4,693.03 32.08 57.81 177.61 6,032.82 4,717.21 17.05 6,075.00 4,708.1 32.2 64.20 177.86 6,055.66 4,733.9 17.10 6,100.00 4,723.33 32.42 71.01 178.08 6,078.26 4,750.61 17.16 6,125.00 4,738.48 32.59 78.24 178.27 6,100.00 4,766.7 17.20 6,150.00 4,753.63 32.76 85.91 178.44 6,122.71 4,783.66 17.26 6,175.00 4,768.78 32.93 93.99 178.58 6,144.55 4,800.01M 17.30M 6,200.00 4,783.93 33.11 102.48 178.70 6,166.10 4,816.22E 17.35M 6,225.00 4,799.0 33.28 111.38 178.80 < 0 `27.28E MR0.27 'W118FAIL major Risk < 0 26.55 139.5 0.119 FAIL - Major Risk < 0 26.11 139.11 0.121 FAIL - Major Risk < 0 26.28 139.28 0.121 FAIL - Major Risk < 0 27.03 140.03 0.122 FAIL - Major Risk < 0 28.30 141.30 0.122 FAIL - Major Risk < 0 30.01 143.011 0.121 FAIL - Major Risk < 0 32.18 145.171 0.121FAIL - Major Risk <0 34.79 147.791 0.120 FAIL - Major Risk < 0 37.93 150.93 0.120 FAIL - Major Risk < 0 41.66 154.6 0.120 FAIL - Major Risk < 0 45.93 158.92 0.121 FAIL - Major Risk < 0 52.26 164.08 0.12 FAIL - Major Risk < 0 58.87 169.43 0.131 FAIL - Major Risk < 0 65.30 174.58 0.141 FAIL - Major Risk < 0 71.31 179.29 0.156 FAIL - Major Risk < 0 76.75 -176.58 0.173 FAIL - Major Risk < 0 81.60 -173.06 0.19 FAIL - Major Risk < 0 85.89 -170.12 0.220 FAIL - Major Risk < 0 89.69 -167.68 0.248 FAIL - Major Risk < 0 93.07 -165.66 0.27 FAIL - Major Risk < 0 96.13 -163.99 0.313 FAIL - Major Risk < 0 98.9 -162.57 0.349 FAIL - Major Risk < 0 101.55 -161.36 0.389 FAIL - Major Risk < 0 103.99 -160.32 0.431 FAIL - Major Risk < 0 106.30 -159.43 0.47 FAIL - Major Risk < 0 108.4 -158.67 0.52 FAIL - Major Risk < 0 110.58 -157.98 0.571 FAIL - Major Risk < 0 112.59 -157.39 0.623 FAIL - Major Risk < 0 114.5 -156.83 0.678 FAIL - Major Risk ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 03 July, 2012 - 16:01 Page 3 of 7 COMPASS Anticollision Report for 2A -27/2A -27A (wpl6) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 2A Pad - 2A-06 - 2A-06 Scan Range: 5,450.00 to 8,016.65 ft. Measured Depth. Scan Radius is 940.27 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No -Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning Warning ii IiQCYJ 6,289.03 4,909.75 17.62 6,375.00 4,888.18 34.31 173.53 179.02 10.17 125.88 -153.82 1.062 Pass - Major Risk 6,308.38 4,924.60 17.66 6,400.00 4,902.77 34.48 185.30 179.01 22.16 127.68 -153.37 1.136 Pass - Major Risk 6,327.39 4,939.23 17.70 6,425.00 4,917.32 34.65 197.45 178.99 34.53 129.42 -152.96 1.212 Pass - Major Risk 6,346.06 4,953.61 17.74 6,450.00 4,931.90 34.83 209.97 178.96 47.27 131.09 -152.60 1.291 Pass - Major Risk 6,364.40 4,967.76 17.78 6,475.00 4,946.50 35.00 222.86 178.92 60.36 132.69 -152.28 1.371 Pass - Major Risk 6,382.39 4,981.65 17.82 6,500.00 4,961.12 35.18 236.10 178.88 73.81 134.24 -152.01 1.455 Pass - Major Risk 6,400.00 4,995.26 17.86 6,525.00 4,975.77 35.35 249.65 178.84 87.57 135.74 -151.75 1.540 Pass - Major Risk �. 6,417.42 5,008.73 17.89 6,550.00 4,990.44 35.52 263.47 178.77 101.60 137.21 -151.52 1.628 Pass - Major Risk -" 6,435.03 5,022.36 17.93 6,575.00 5,005.15 35.70 277.54 178.82 115.80 138.42 -151.34 1.716 Pass - Major Risk 6,455.63 5,038.30 17.96 6,600.00 5,019.88 35.87 291.69 179.33 129.46 138.37 -151.39 1.796 Pass -Major Risk 6,476.26 5,054.26 18.00 6,625.00 5,034.65 36.05 305.82 179.84 143.09 138.31 -151.45 1.879 Pass - Major Risk 6,496.90 5,070.24 18.04 6,650.00 5,049.47 36.22 319.91 180.35 156.69 138.25 -151.51 1.960 Pass - Major Risk 6,517.57 5,086.23 18.08 6,675.00 5,064.35 36.39 333.97 180.86 170.25 138.19 -151.57 2.040 Pass - Major Risk 6,538.26 5,102.24 18.11 6,700.00 5,079.27 36.57 348.00 181.36 183.79 138.12 -151.64 2.119 Pass- Major Risk 6,558.92 5,118.23 18.15 6,725.00 5,094.19 36.74 362.07 181.87 197.36 138.05 -151.71 2.198 Pass - Major Risk 6,579.51 5,134.16 18.18 6,750.00 5,109.07 36.92 376.24 182.37 211.04 137.99 -151.77 2.277 Pass - Major Risk 6,600.03 5,150.03 18.22 6,775.00 5,123.89 37.09 390.52 182.87 224.83 137.92 -151.84 2.357 Pass - Major Risk 6,620.47 5,165.85 18.26 6,800.00 5,138.66 37.27 404.91 183.38 238.72 137.86 -151.90 2.436 Pass - Major Risk 6,640.82 5,181.60 18.29 6,825.00 5,153.35 37.44 419.42 183.89 252.74 137.80 -151.96 2.516 Pass - Major Risk 6,661.08 5,197.28 18.33 6,850.00 5,167.91 37.62 434.06 184.40 266.90 137.75 -152.01 2.597 Pass - Major Risk 6,681.25 5,212.88 18.37 6,875.00 5,182.35 37.80 448.83 184.90 281.20 137.72 -152.04 2.677 Pass - Major Risk 6,701.32 5,228.41 18.40 6,900.00 5,196.66 37.97 463.74 185.41 295.63 137.69 -152.07 2.759 Pass - Major Risk 6,721.32 5,243.89 18.44 6,925.00 5,210.91 38.15 478.74 185.92 310.17 137.67 -152.09 2.840 Pass - Major Risk 6,741.27 5,259.33 18.48 6,950.00 5,225.16 38.33 493.80 186.43 324.76 137.64 -152.12 2.921 Pass - Major Risk 6,761.17 5,274.73 18.52 6,975.00 5,239.40 38.50 508.93 186.94 339.41 137.60 -152.16 3.002 Pass - Major Risk 6,781.02 5,290.09 18.55 7,000.00 5,253.64 38.68 524.12 187.44 354.13 137.56 -152.20 3.083 Pass - Major Risk 03 July, 2012 - 16:01 Page 3 of 7 COMPASS HALLIR _!RTON ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Anticollision Report for 2A -27/2A -27A (wp16) Tray. Cylinder North Proximity Scan on Current Survey Data (North Reference) Offset Design: Kuparuk 2A Pad - 2A-06 - 2A-06 Scan Range: 5,450.00 to 8,016.65 ft. Measured Depth. Scan Radius is 940.27 ft. Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Uncertainty Data for Reference Well Uncertainty Data for Offset Well Separation (Ref. > Comp.) Measured Vertical Ellipse Measured Vertical Ellipse Between No -Go Between Relative Relative Depth Depth Major Depth Depth Major Centres Area Ellipsoids North Highside Clearance (ft) (ft) Axis/2 (ft) (ft) Axis/2 (ft) (ft) (ft) Bearing Bearing Factor Warning 6,800.91 5,305.48 18.59 7,025.00 5,268.02 38.86 539.25 187.95 368.77 137.51 -152.25 3.163 Pass - Major Risk 6,819.67 5,320.00 18.63 7,050.00 5,282.69 39.04 554.20 188.45 383.21 137.43 -152.33 3.241 Pass - Major Risk 6,834.15 5,331.20 18.66 7,075.00 5,297.64 39.21 569.08 188.30 398.32 138.71 -152.18 3.333 Pass - Major Risk 6,847.62 5,341.59 18.68 7,100.00 5,312.87 39.39 584.00 188.15 413.44 139.86 -152.08 3.424 Pass- Major Risk 6,860.93 5,351.86 18.71 7,125.00 5,328.39 39.56 598.97 187.95 428.59 140.97 -152.00 3.516 Pass - Major Risk 6,874.08 5,361.99 18.73 7,150.00 5,344.20 39.74 613.98 187.71 443.79 142.04 -151.95 3.608 Pass - Major Risk 6,900.00 5,381.89 18.79 7,175.00 5,360.31 39.91 629.23 187.23 459.87 144.27 -151.70 3.715 Pass - Major Risk 6,900.00 5,381.89 18.79 7,200.00 5,376.71 40.08 644.12 187.62 474.31 144.03 -151.94 3.793 Pass - Major Risk 6,900.00 5,381.89 18.79 7,225.00 5,393.42 40.25 659.41 188.00 489.13 143.78 -152.20 3.873 Pass - Major Risk 6,925.16 5,401.13 18.84 7,250.00 5,410.46 40.42 674.33 187.38 504.87 145.84 -152.03 3.979 Pass - Major Risk 6,937.57 5,410.59 18.86 7,275.00 5,427.82 40.59 689.43 187.20 520.15 146.69 -152.12 4.073 Pass - Major Risk 6,949.83 5,419.92 18.88 7,300.00 5,445.50 40.76 704.52 187.00 535.43 147.50 -152.23 4.167 Pass - Major Risk 6,961.97 5,429.13 18.91 7,325.00 5,463.49 40.93 719.58 186.75 550.68 148.27 -152.35 4.260 Pass - Major Risk 6,973.98 5,438.23 18.93 7,350.00 5,481.79 41.09 734.59 186.62 565.89 149.01 -152.50 4.354 Pass - Major Risk 7,000.00 5,457.85 18.98 7,375.00 5,500.40 41.26 749.77 186.00 582.13 151.01 -152.40 4.472 Pass - Major Risk 7,000.00 5,457.85 18.98 7,400.00 5,519.29 41.42 764.47 186.36 596.33 150.62 -152.78 4.547 Pass - Major Risk 7,000.00 5,457.85 18.98 7,425.00 5,538.48 41.58 779.41 186.70 610.77 150.22 -153.18 4.622 Pass - Major Risk 7,020.89 5,473.52 19.02 7,450.00 5,557.96 41.74 794.13 186.13 626.29 151.69 -153.22 4.731 Pass - Major Risk 7,032.32 5,482.06 19.04 7,475.00 5,577.73 41.90 808.90 185.93 641.28 152.29 -153.43 4.826 Pass - Major Risk 7,043.63 5,490.48 19.06 7,500.00 5,597.77 42.05 823.62 185.70 656.24 152.86 -153.66 4.921 Pass - Major Risk 7,054.83 5,498.81 19.08 7,525.00 5,618.07 42.21 838.28 185.47 671.14 153.40 -153.90 5.016 Pass - Major Risk 7,065.94 5,507.04 19.10 7,550.00 5,638.63 42.36 852.85 185.41 685.97 153.93 -154.15 5.111 Pass - Major Risk 7,076.97 5,515.17 19.12 7,575.00 5,659.43 42.51 867.33 185.33 700.72 154.44 -154.40 5.206 Pass - Major Risk 7,100.00 5,532.09 19.16 7,600.00 5,680.47 42.66 881.88 184.72 716.43 155.97 -154.44 5.330 Pass - Major Risk 7,100.00 5,532.09 19.16 7,625.00 5,701.74 42.80 896.06 185.02 730.11 155.51 -154.90 5.399 Pass - Major Risk 7,100.00 5,532.09 19.16 7,650.00 5,723.20 42.95 910.41 185.32 743.96 155.04 -155.37 5.469 Pass - Major Risk 7,100.00 5,532.09 19.16 7,675.00 5,744.87 43.09 924.92 185.62 757.96 154.58 -155.83 5.540 Pass - Major Risk 7,130.82 5,554.53 19.21 7,700.00 5,766.72 43.24 938.65 184.48 773.52 156.73 -155.74 5.685 Pass - Major Risk 03 July, 2012 - 16:01 Page 4 of 7 COMPASS HALLIBURTQF*-a Anticollision Report for 2A -27/2A -27A (wpl6) Survey tool program From To (ft) (ft) 95.20 255.20 312.77 3,331.81 3,419.90 4,349.53 4,395.20 4,978.20 4,995.20 5,450.00 5,450.00 8,016.65 2A -27A (wp16) Ellipse error terms are correlated across survey tool tie -on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor = Distance Between Profiles / (Distance Between Profiles - Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. Survey/Plan Survey Tool CB -GYRO -SS MWD+IFR-AK-CAZ-SC MWD GYD-CT-CMS GYD-CT-DMS MWD+IFR-AK-CAZ-SC ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit 03 July, 2012 - 16:01 Page 5 of 7 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALL I RURTON Kuparuk River Unit Anticollision Report for 2A -27/2A -27A (wpl6) Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: 2A-27 @ 120.00ft (D141 (28+92)). Northing and Easting are relative to 2A-27. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.01 °. I I I I I I Ladder I I I I I I I I I I I I I 1 I 1 I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I 1 I I 1 I I 1 I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I C: I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I 4? 150— C c 0 2 L cc 100 LEGEND 2A -06,2A -06,2A -06V1 2A-27A(wp16) Q) U 0 a) 50 c W U 0 0 1500 3000 4500 6000 7500 Measured Depth (1500 Win) I I I I I I I I I I I I I I I I I I I I I I 1 I 1 I I I I I I I I I I 1 I I I I I I I I I I I I I I I I I I I I 1 I I 1 I I 1 I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I 1 I I I 1 I I I I I I I I I i I I I I I I I I I I I I I I I I I I I I I I I I I I I 03 July, 2012 - 16:01 Page 6 of 7 COMPASS ConocoPhillips (Alaska) Inc. -Kup2 HALLIBURTON Kuparuk River Unit Anticollision Report for 2A -27/2A -27A (wpl6) Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor 11.00- 10.00- 9.00- 8.00- 7.00— U? 1. 10.009.8.7• N 6.0G— LL . - — U j LEGEND c 5.00--- 0 N , 2A-06, 2A-06, 2A-06 V1 fl 4.00- 3.00 .00 3. - I 200-11 1.00 0.00 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 72M 7800 8400 9000 Measured Depth (1500 ftfi n) 03 July, 2012 - 16:01 Page 7 0/ 7 COMPASS ConocoPhillips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 2A Pad Plan: 2A -27A (wp16) 1/4 Mile Pool Scan Sperry Drilling Services July 5, 2012 HALLIBURTON Sperry Drilling Closest in POOL Closest Approach: Reference Well: 2A -27A (wp16 i Plan Offset Well: 2A-06 3-D ctrctr Distance. Horizontal Distance Subsea Difference Meas. Depth Incl. Angle TRUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)M/(-) View VS (266.95") Comments Meas. Depth Incl. Angle TRUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (266.95") Comments 1049.49 -1046.35 81 ' 7458.16 45.15 317.09 5667.11 5958810.46 1634752.25 3940.10 POOL Min Distance (1049.49 ft) in POOL (7458 - 8016.65 MD) to 2A-06 (7841 - 8205 MD) 7825.00 25.16 251.41 5748.26 5957820.81 1634412.48 4058.46 PUOT-M-in -stance (1049.49 ft) in POOL (7458 - 8016.65 MD) to 2A -27A (wp16) Plan (7841 - 8205 MD) Closest Approach: Reference Well: 2A -27A w 16 1 Plan Offset Well: 2A-07 3-D ctr-ctr Distance. Meas. Depth Incl. Angle TRUE Azi. Subsea TVD Coords. - ASP N + /S - E(+)/W - View VS 266.95°) Comments Meas. Depth Incl. Angle TRUE Azi. Subsea TVD Coords. - ASP N + /S(-) E(+)/W(-) View VS (266.95° Comments 1386.44 -280.74,1" 8016.65 45.15 317.09 6060.98 5959100.50 1634482.72 4193.86 POOL Min Distance (1414.58 ft) in POOL (7458 - 8016.65 MD) to 2A-07 (7530 - 7956 MD) 7525.00 42.97 280.83 5780.24 5960486.02 1634432.03 3901.16 POOL Min Distance (1414.58 ft) in POOL (7458 - 8016.65 MD) to 2A -27A (wp16) Plan (7530 - 7956 MD) POOL Summary Templatet.xls 7/5/2012 2:57 PM Project: Kuparuk River Unit ' s ConocoPhilli $ p Site: Kuparuk 2A Pad Well: 2A-27 Wellbore: Plan: 2A ' -27A Plan: 2A -27A (wp16) (2A-27/Plan: 2A -27A) HALLIBURTON Ground Level: 92.00 , , • RKB: Plan: 2A-27 @ 120.00R (D141 (28-92)) Northing/ASP V: 5959648.55 Eat ng/ASP X: 1638653.38 1500- I 1250 - - -- - - - 1000 ry _ N 750 500 2A -27A A3 (wp15) 1/4 ml ____ -.9 9 51r 250-- U' I 20 0 9 5!8" c i Lo -250-: + -500 LSP 7" 2A -27A A3 (wp15) - L DD Poly 95% conf. 13 3/8" O 0 , Z -750 _ t -1000 (n _ -1250 - ` 9 5/8" TOW I -' -1500-- 1500 0� 7' 7 9 `" 7" 1750 i I i -2000 ? 0 rn -2250 - -2500 -6000 -5750 -5500 -5250 -5000 -4750 -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -1500 -1250 -1000 -750 -500 -250 -0 250 500 West( -)/East(+) (750 ft/in) CD 2A -27A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 8-3/4" Hole with 7" Liner Event Vel Ri Mitigation Strategy Window / Open Hole leak Low Squeeze cement at 9-5/8" casing window off less than required Tracking along 9-5/8" Perforate 9-5/8" casing and squeeze cement in 9-5/8" X casing during window Moderate 12-1/4" annulus. milling Anti -collision with offset 2A -27A is close to 2A-06 at the KOP. 2A-06 is at the left wells Low of kick off point and 2A-27 will turn right from the kick off. So the possibility of collision is low. Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Moderate Placement of KOP and bottom hole location to allow for 5° DLS. Run liner to bottom Moderate Drill 8-3/4" hole with proper mud weight for hole stability, directional plan with 50 DLS . Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate density (ECD) monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. Abnormal Reservoir BOPE drills, keep mud weight above 9.5 ppg, check for Pressure Low flow during connections and if needed increase mud weight. Reduced pump rates, real time equivalent circulating Lost Circulation Low density (ECD) monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Tracking along 9-5/8" Perforate 9-5/8" casing and squeeze cement in 9-5/8" X casing during window Moderate 12-1/4" annulus. milling Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate duringcirculation and um 40% excess cement. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, and standard well control practices. *See Well Plan for more detailed risk information and offset data. Page 1 of 2 Schwartz, Guy L (DOA) From: Guo, Hai Bin [Hai bin. Guo@conocophillips.com] Sent: Tuesday, July 31, 2012 11:11 AM To: Schwartz, Guy L (DOA) Subject: RE: 2A-27 sidetrack (PTD 209-107) Attachments: Permit to Drill - Verbiage Updated 073112.doc; 2009 2A-27 Drilling reports.pdf; 2011 2A-06 PA reports.pdf; 2A-06 completion report.pdf, Visio-2A-27A ST Proposed Schematic V3.2.pdf Guy, I'll prepare a 10-403 sundry and send to you shortly. Yes, both 2A-06 and 2A-27 had been plugged and the sealed properly. Well 2A-27 is the intervention well to P&A 2A-06. 2A-06 had down hole issues of parted tubing(250') and severely damaged/folded 7" casing. Circulation was established through the two wells when drilled to 7255' MD at 17:00 on Nov 26th, 2009. 50 bbls cement was pumped to 2A-06 through 2A-27. Later, slight flow was observed in 2A-27 while pumping diesel down to 2A-06 tubing. Tried to establish circulation with 2A-27 again, no success. Decided to P&A 2A-06 later. To P&A 2A-27, cement was plug was set in 7" liner to top of liner packer with 25 bbls 15.8 ppg Class G cement at 20:00 on Dec 8th, 2009. The cement plugs was tagged with 10 klbs @ 6692' MD and was pressure tested with 1500 psi / 30 min at 13:00 on Dec 9th, 2009. The 7" liner top packer is at 6694' MD. The top of plug is 2' above the 7" liner top packer and is 549' above the top of perforations(7241') in 7" liner. The formation has been properly sealed with cement. For 2A-06, the well was finally P&A with rig Nordic 3 by milling through restrictions and fishing jobs from Feb 5th, 2011 to Mar 12, 2011. See the operation reports and Complete report. The TOC in 9-5/8" casing is at 6,692' MD, which is 2' above 7" liner packer, was tagged and tested in 2009. We'll tag and test again during P&A and will state in the Sundry. Also the pressure test to 9-5/8" casing / cement plug will be included in the Sundry. Attached is the updated PTD, Schematic, Operation/Complete reports for your reference. If you have any more question, let me know. Haibin Guo Drilling Engineer ConocoPhillips Alaska Office: 907.265.1487 Gell: 907.297M 13 From: Schwartz, Guy L (DOA)[mailto:guy.schwartz@alaska.gov] 7/31/2012 Page 2 of 2 Sent: Friday, July 27, 2012 10:02 AM To: Guo, Hai Bin Cc: Davies, Stephen F (DOA) Subject: [EXTERNAL]2A-27 sidetrack (PTD 209-107) Haibin. Please call me to discuss the proposed sidetrack. You will also need to provide a 10-403 sundry to P &A existing weU 2A-27 (PTD 209-107) before the PTD can be approved for the sidetrack. 2A-27 is currently Susoended. Regarding the required AOR for the new injector 2A -27A a discussion about the plugging of both 2A-06 and 2A- 27 at the Kuparuk zone is very critical. CPAI must state its case that these two wells are properly sealed at the iniection zone to ensure fluids are confined. What is the current TOC in the 9 5/8" intermediate casing? The sqz perfs and retainer setting steps are not clear to me... (step 6-9) The schematic provided doesn't show the perfs or cement sqz details very clearly. Also, pressure test the 9 518" casing / cement plug to 1500 psi before you perforate the casing for the cement squeeze ( Could do that in conjunction with step 5) Reqards, Guy Schwartz Senior Petroleum Engineer AOr,C 793-1226 (office) 444-3433 (ceU) TOC on 9-5/8" casing @ 4,400' MD 7" TOL @ 5,250' MD / 4,211' TVD 9-5/8" Whipstoi 5,450' MD Cement Retainer @5,480' MD Squeeze Perfs @5,464' MD Tagged & Pressure tested plug @ 6,692' MD. 7" TOL @ 6,694' MD / 5 TVD Baker Casing Packer (a� 7,177' MD S Stage Collar @ 7,164' MD Perfs @ 7,241' - 7,256' .A -27A Rotary Sidetracl. 20" conductor casing DRAFT 120' MD 13-3/8" 68# L-80 BTC / TC II surface casing 3374' MD / 2931'T' 3-1/2" Selective Upper Completion String Sidetrack KOP • 2.875" Nipple at 500' MD thru window in 9-5/8" @ • Tubing: 3-'/2", 9.3 ppf, L-80, 8rd EUE 5,450' MD / 4,337' TVD . CMU Sliding Sleeve, 2.813" X Profile • Baker 20' PBR 3-'/Z" 9.3# L-80 EUE Tubing . Baker FHL Packer • Injection Mandrel #1, #2 • CMU Sliding Sleeve, 2.813" X Profile \ • Baker 'F1' Packer with SBE • Shear out sub "FHL" packer +/-7,425' MD / 5,763' TVD SLB Injection Mandrels +/-7,540' MD and 7,470' MD. �c Baker Sliding Sleeve, CMU w/ 2.183" X �� profile +/-7,610' MD of plug @ 6,692' MD "F1" packer +/-7,645' MD / 5,918 TVD C sand Perfs: 7,574'- 7,633' MD 9-5/8" 40# L-80 BTC TC iI intermediate casing 6849' MD / 5171' TVD A sand Perfs: 7,672'- 7,755' MD 7" 26# L-80 cemented liner @ 8,018' MD / 6,184' TVD 15.5# BTCM tail 13" X Profile Nipple Perfs @ 7" 26.4# L-80 Liner Revised by: 7,244'- 7,259' 7,248' MD / 5417' TVD Haibin Guo June 20, 2012 k -27A Rotary Sidetrael 20" conductor casing y 120' MD DRAFT 13-3/8" 68# L-80 BTC / TC II TOC on 9-5/8" surface casing 3374' MD / 2931' TV sing @ 4,400' MD :> 7" TOL @ 3-1/2" Selective Upper Completion String 1 250' MD / 4,211' Sidetrack KOP TVD 2.875 Nipple at 500 MD thru window in 9-5/8" @ • Tubing: 3-Y2", 9.3 ppf, L-80, 8rd EUE 5,450' MD / 4,337' TVD • CMU Sliding Sleeve, 2.813" X Profile • Baker 20' PBR 3-��2" 9.3# L-80 EUE Tubing Baker FHL Packer • Injection Mandrel #1, #2 CMU Sliding Sleeve, 2.813" X Profile • Baker'F1' Packer with SBE Shear out sub egged & Pressure ted plug @ 6,692' MD. 7" TOL @ 6,694' MD / 5,076 TVD Baker Casing Packer (a 7,177' MD H S Stage Collar @7,164'MD Perfs @ 7,241'— 7,256' "FHL" packer +/-7,425' MD / 5,763' TVD SLB Injection Mandrels +/-7,540' MD and 7,470' MD. Baker Sliding Sleeve, CMU w/ 2.183" profile +/-7,610' MD "F1" packer +/-7,645' MD / 5,918' TVD C sand Perfs: 7,574'— 7,633' MD 9-5/8" 40# L-80 BTC TC A sand Perfs: 7,672' — 7,755' MD 11 intermediate casing 6849' MD / 5171' TVD 7" 26# L-80 cemented liner @ 8,018' MD / 6,184' TVD 11 15.5# BTCM tail 13" X Profile Nipple Perfs @ I ' 7" 26.44 L-80 Liner 7,244'— 7,259' u 7,248' MD / 5417' TVD Revised b u NU Haibin Guo RJune 20, 2012 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 16-2--a 2,4 —Z-74 PTD# Development V Service Exploratory Stratigraphic Test Non -Conventional Well FIELD: !`C C , _C_ /�— 1 v�� POOL: Check Box for Appropriate Letter / Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in permit No. API No. 50- - - API number are , between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through tar et zones. Non -Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of welll until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 9/09/2011 1W 1"AWR Field & Pool KUPARUK RIVER, KUPARUK RIV OIL - 490100 PTD#:2121000 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type Well Name: KUPARUK RIV UNIT 2A -27A Program SER Well bore seg SER / PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ❑ Administration 17 Nonconven. gas conforms to AS31.05.030(j.1.A),(j.2.A-D) NA 1 Permit fee attached NA 2 Lease number appropriate Yes Entire well in ADL 25570 3 Unique well name and number - Yes 4 Well located in a defined pool Yes Kuparuk River Oil Pool, governed by Conservation Order No. 432C 5 Well located proper distance from drilling unit boundary Yes Conservation Order No. 432C contains no spacing restrictions with respect to drilling unit 6 Well located proper distance from other wells Yes boundaries. Conservation Order No. 432C has no interwell spacing restrictions. 7 Sufficient acreage available in drilling unit Yes Conservation Order No. 432C has no interwell spacing restrictions. Wellbore will be more than 8 If deviated, is wellbore plat included Yes 500' from an external property line where ownership or landownership changes. 9 Operator only affected party Yes 10 Operator has appropriate bond in force Yes Appr Date 11 Permit can be issued without conservation order Yes 12 Permit can be issued without administrative approval Yes SFD 7/24/2012 13 Can permit be approved before 15 -day wait Yes 14 Well located within area and strata authorized by Injection Order # (put IO# in comments) (For Yes Area Injection Order No. 2B - Kuparuk River Unit 15 All wells within 1/4 mile area of review identified (For service well only) Yes KRU 2A-19, KRU 2A -19A, KRU 2A-20 16 Pre -produced injector: duration of pre -production less than 3 months (For service well only) No 18 Conductor string provided NA Conductor set in 2A-27 Engineering 19 Surface casing protects all known USDWs NA Surface casing set in 2A-27.. 20 CMT vol adequate to circulate on conductor & surf csg NA Surface casing fully cemented. Casing shoe at 3374 ft md. 21 CMT vol adequate to tie-in long string to surf csg No 7 " liner will be cemented back .. TOL at 5240 ft. and 22 CMT will cover all known productive horizons Yes 23 Casing designs adequate for C, T, B & permafrost Yes 24 Adequate tankage or reserve pit Yes rig has steel pits.. All waste to approved disposal wells. 25 If a re -drill, has a 10-403 for abandonment been approved Yes 312-294 Well currently suspending. Setting CIBP and Whipstock to sidetrack. 26 Adequate wellbore separation proposed Yes Proximity analysis performed. No issues with 2A-06 27 If diverter required, does it meet regulations NA Wellhead in place.. BOP will be used. Appr Date 28 Drilling fluid program schematic & equip list adequate Yes Max formation pressure= 2500 psi (8.1 ppg EMW) will drill well with 9.5- 10 ppg mud (LSND) GLS 8/1/2012 29 BOPEs, do they meet regulation Yes 30 BOPE press rating appropriate; test to (put psig in comments) Yes MASP= 1906 psi Will test BOP to 3500 psi . 31 Choke manifold complies w/API RP -53 (May 84) Yes 32 Work will occur without operation shutdown Yes 33 Is presence of H2S gas probable Yes H2S in pad. Rig has sensors and alarms. 34 Mechanical condition of wells within AOR verified (For service well only) Yes 2A-06 and 2A-27 (both P & A) in 1/4 mile AOR. 35 Permit can be issued w/o hydrogen sulfide measures No Wells on 2A -Pad are H2S-bearing. H2S measures required. Geology 36 Data presented on potential overpressure zones Yes Expected reservoir pressure is 8.2 ppg EMW; will be drilled using 9.5 - 10.0 ppg mud. Appr Date 37 Seismic analysis of shallow gas zones NA SFD 7/24/2012 38 Seabed condition survey (if off -shore) NA 39 Contact name/phone for weekly progress reports [exploratory only] NA Geologic Engineering Public Sidtracking well 2A-27 used previously to P &A 2A-06. Well service will be an A/C Kuparuk water injector. GLs Commissioner: Date: Commissioner: Date CoT r Date