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Home My WebLink About207-070Originated: Delivered to:26-Aug-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 1A-23 50-029-22131-00 910219324 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 12 1A-27 50-029-22124-00 910219038 Kuparuk River Plug Setting Record Field- Final 4-Aug-25 0 13 1B-15A 50-029-22465-01 910203865 Kuparuk River Multi Finger Caliper Field & Processed 5-Aug-25 0 14 1C-153 50-029-23549-00 910180480 Kuparuk River Leak Detect Log Field- Final 19-Jul-25 0 15 1C-153 50-029-23549-00 910181004 Kuparuk River Packer Setting Record Field- Final 28-Jul-25 0 16 1G-02 50-029-20813-00 910151017 Kuparuk River Packer Setting Record Field- Final 9-Jul-25 0 17 1J-122 50-029-23359-00 910180477 Kuparuk River Plug Setting Record Field- Final 18-Jul-25 0 18 1L-09 50-029-22025-00 910180917 Kuparuk River Leak Detect Log Field- Final 17-Jul-25 0 19 1L-09 50-029-22025-00 910180917 Kuparuk River Multi Finger Caliper Field & Processed 14-Jul-25 0 110 1L-09 50-029-22025-00 910180917 Kuparuk River Packer Setting Record Field- Final 26-Jul-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:T40821T40822T40823T40824T40824T40825T40826T40827T40827T40827191-009190-180204-256215-116182-138207-070190-0348/27/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.08.27 12:29:56 -08'00'1J-12250-029-23359-00 910180477Kuparuk RiverPlug Setting RecordField- Final18-Jul-2501207-070 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1J-122 KUPARUK RIV U WSAK 1J-122 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1J-122 50-029-23359-00-00 207-070-0 W SPT 3684 2070700 1500 931 931 931 931 210 216 215 215 4YRTST P Adam Earl 5/7/2022 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV U WSAK 1J-122 Inspection Date: Tubing OA Packer Depth 490 1980 1895 1880IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509105925 BBL Pumped:5.8 BBL Returned:5.6 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 15:05:27 -08'00' Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 1C-150 50-029-23496-00 906922998 West Sak Multi Finger Caliper Field & Processed 17-Jan-21 0 1 2 1C-150 50-029-23496-00 906922998 West Sak Injection Profile with TMD3D Field & Processed 17-Jan-21 0 1 3 1D-125A 50-029-22904-01 906903184 West Sak Plug Setting Record Field- Final 4-Jan-21 0 1 4 1D-142 50-029-23529-00 906921246 West Sak Multi Finger Caliper Field & Processed 15-Jan-21 0 1 5 1D-142 50-029-23529-00 906921246 West Sak Injection Profile with TMD3D Field & Processed 16-Jan-21 0 1 6 1E-105 50-029-23243-00 906936637 West Sak Injection Profile Field & Processed 25-Jan-21 0 1 7 1E-117 50-029-23251-00 906931006 West Sak Injection Profile Field & Processed 21-Jan-21 0 1 8 1J-118 50-029-23337-00 906941926 West Sak Packer Setting Record Field- Final 26-Jan-21 0 1 9 1J-122 50-029-23359-00 906955932 West Sak Injection Profile with TMD3D Field & Processed 6-Feb-21 0 1 10 1J-127 50-029-23306-00 906953848 West Sak Injection Profile with TMD3D Field & Processed 2-Feb-21 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2070700 E-Set: 34725 MEMORANDUM • • State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,May 14,2018 Jim Regg P.I.Supervisor 1 ��1/i g SUBJECT: Mechanical Integrity Tests G� c l 666 CONOCOPHILLIPS ALASKA,INC. 1J-122 FROM: Lou Laubenstein KUPARUK RIV U WSAK IJ-122 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV U WSAK 1J-122 API Well Number 50-029-23359-00-00 Inspector Name: Lou Laubenstein Permit Number: 207-070-0 Inspection Date: 5/9/2018 Insp Num: mitLOL180510144334 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well IJ-122 iType Inj W TVD 3684 • Tubing 695 695 695 - 695 - PTD 2070700 Type Test SPT Test psi 1500 - IA 1250 2000 • 1940 1930- BBL Pumped: 3.5 BBL Returned: 3 - OA 144 219 195 181 - Interval 4YRTST P/F P Notes: SQ ,JUN Monday,May 14,2018 Page 1 of 1 • S i ,,T zz PrO 7070 70o Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> J Sent: Tuesday, July 19, 2016 1:59 PM " IH Iii To: NSK West Sak Prod Engr; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr; Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M Subject: LPP/SSV's returned to service on CPAI 1J wells Jim, The low pressure pilots(LPP) on the following wells were returned to service toda rj,7/19/16, after injection pressures increased above their pilot settings. J-122 PTD#207-070 07-071, 207-072) — 1J-127 (PTD#206-047,206-048, 206-049) 1J-136 (PTD#206-154, 206-155) 1J-156(PTD#206-067,206-068,206-069) The aforementioned wells have been removed from the "Facility Defeated Safety Device Log." This notification is in accordance with "Administrative Approval No. CO 4066.001." Notification will be sent when the remaining 1J water injector's LPP's are placed back in service. Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers SCANNED r `� ConocoPhillips Alaska, Inc. 7012 Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com From: NSK West Sak Prod Engr Sent: Sunday,July 17, 2016 7:57 AM To: Regg,JamesI3 (DOA)<iim.regg@alaska.gov> Cc:CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067 • conoco•hilli.s.c• >; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael<Michael.Sullivan • conoco•hilli•s.co • ; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>; Targac, G. <Garv.Targac@conocophillips.com>; NSK Optimization Engr<n2046 • conoco•hilli•s '•m>; CPF1 DS Operators <n1275@conocophillips.com>; Stanley, Scott M <Scott.M.Stanle • conocoshill'• om>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI 1J wells Jim, 1 Regg, James B (DOA) .0 7- 070 From: NSK West Sak Prod Engr <n1638@conocophillips.com> � / Sent: Sunday, July 17, 2016 7:57 AM I, 4f if t 2(((C) To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Stanley, Scott M; NSK West Sak Prod Engr Subject: Defeated LPP/SSV on CPAI iJ wells Jim, The low pressure pilots (LPP) on the following wells were defeated today, 7/17/16, after water injection service was restored to drillsite 1J following the CPF-1 facility shut down. 1J-102 (PTD#206-110, 206-111, 206-112) 1J-118(PTD#206-176,206-177, 206-178) �E� JAN 1J-122 (PTD#207-070, 207-071,207-072) SCO MED (PTD#206-047, 206-048,206-049 1J-136(PTD#206-154,206-155) 1J-154 (PTD#205-035, 205-036,205-037) 1J-156 (PTD#206-067, 206-068, 206-069) The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety .� Device Loi." All injectors are on water injection and stable with building wellhead injection pressures. The AOGCC will be notified when each well's LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Regards, David Haakinson / Scott Stanley West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com iSo Ll1C2 WELL LOG TRANSMITTAL# DATA LOGGED %1/So/2015 M.K.BENDER To: Alaska Oil and Gas Conservation Comm. November 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper(MFC): 1J-122 Run Date: 10/13/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1T-122 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23359-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 27, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile / Water Flow Log: 1J -122 Run Date: 6/30/2011 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 1J -122 Digital Data in DLIS /LAS format, Digital Log file, Interpretation Report l 18s—Cf 1 CD Rom 50- 029 - 23359 -00 Water Flow Log 1 Color Log — 50- 029 - 23359 -00 ^��r Injection Profile Log 1 Color Log 50- 029 - 23359 -00 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: /( vj Signed: - l�' /k David P. Jamieson Supervisor, Reservoir Engineering , Greater Kuparuk Area Development ConocoPhiilips Alaska, Inc. ConowPhilfimc A Street Anchorage, AK 99501 phone 907.265.6543 DEf September 23, 2010 t9 SEP 2 3 2010 Daniel T Seamount, Jr., Commission Chair Alaska Oil and Gas Conservation Commission :' ' "' 333 W. 7th Ave #100_> Anchorage, Alaska, 99501 -3539 RE: West Sak Viscosity Reducing Water Alternating Gas Pilot Project Administrative Approval Area Injection Order 213.044 Administrative Approval Conservation Order 4066.009 Dear Mr. Seamount: Enclosed is the West Sak Viscosity Reducing Water Alternating Gas (VRWAG) Pilot Project Status Report for the reporting period of July 1 2009 through June 30 2010. As per conditions described in the pilot approval document, this report was to be submitted to the Commission by September 30, 2010 and contain items specific to the project performance and achievements. Please contact R.Scott Redman (263 - 4514), Mark Hutcherson (265- 1034), or Lubble Jenkins (265 -6912) if you have questions or require additional Information. Sincerely, > f VV GN Si iI Y David Jamies'bn Supervisor, Reservoir Engineering Greater Kuparuk Area Development cc: King, Warwick. Jenkins, Lubble Seitz, Brian Rodgers, James �0q -o* Cono WS -VRWAG PILOT PROJECT STATUS REPORT REPORTING PERIOD 7/l/2009 -- 6/30/2010 Submitted, 9/30/2010 Prepared By: 1440 Marc Hut rson, west Sak Drillsite Petroleum Engineer Reviewed : B Y cott Red , west Sak Reservoir Engineer Approved By: ih, FW 3ti L Iva � David Jamieson, OKA Reservoir Engineering Supervisor WS -VRWAG Pilot Proiect Status Report Executive Summary This document is the annual West Sak Viscosity Reducing Water Alternating Gas (VRWAG) Pilot Project Status Report, submitted to the Alaska Oil and Gas Conservation Commission (AOGC% as required by Area Injection Order 213.044 and Conservation Order 4066.009. The AOGCC, through a letter dated September 9, 2009, requires that the operator Vovide the Commission with a report on the status of the VRWAG pilot project by September 30 of each year, beginning in 2010. The WS -VRWAG Pilot Project entails injecting hydrocarbon enriched gas for 6 WAG (Water Alternating Gas) cycles in 4 patterns In the West Sak Field 1E Drillsite and i J Drillsite. An incremental recovery of 3 -6% of the original oil in place is expected in addition to the -20% waterflood recovery estimate. Four injectors were selected for the pilot (1E -102, 1E -117, 1J -122, and 1J -170) targeting five offset producers on gas lift (1E -121, 1E-170, 1J -168, 1J -166, and 1J -120). To date. none of the 4 targeted patterns is mature enough in the FOR project to show enhanced production. However, t he 1E-102 injector experienced an MBE (Matrix Bypass Event) with the 1 E -121 producer 37 days into the first MI cycle. It is believed that the MBE is unrelated to the pilot project and would have occurred regardless. The other 3 patterns do not show any adverse effects from to the MI and are continuing forward as planned. �oy -a3 I r E - /oa ao5 - o0(- 1 E - 20a -0 - 9 o r5 -idQ Introduction - Pilot Project is an expansion of the current development The WS VRWAG Ian for the West Sak p p p 1 Reservoir with potential to significantly increase the recovery of oil from the pool. The pilot was approved by the AOGCC on 9/10/09 and the first VR -WAG cycle began 11/23109 on two of the four patterns, which effectively started the clock on the 36 month planned pilot. The graphic below shows and field overview with the patterns outlined in red: 1E -1 2 - - Are n 4 J t: - ,nor•- �. �q airw '; fi` t West A I R•_ S1 � l ♦ 1 !! r �)17 � • i�lr 7 { r {s XkJ14 I {s IE /^finn'' n U 122 va t, s 1E -11 / 0es 48 13 -17 D 3 -- 4 Ir a.. � 1.. Are t � r IT f • 0 Proiect Performance and Achievements It is still early in the VR -WAG Pilot to detect any uplift or response from the producers. 1 E -102 Pattern Offset producers: 1 E -121 & 1 B -101 (possible) Dual lateral well selected for D lateral injection only (B lateral was previously isolated due to pre -pilot MBE) • Began first MI cycle 11/23/09 aj • Experienced MBE in D lateral on 12/29/09, 37 days after beginning MI, and was shut -in • Pulled from pilot and remains SI to this date awaiting ` o) MBE remediation • Due to the MBE occurring in 1E-102, replacement candidates are being reviewed. No premature breakthrough events detected No oil production response from FOR detected at ' offset producers 'L w _N � 1 E -117 Pattern W � • Offset producers: 1E -170, 1J -168 & 1E -166 1 (Possible) & + • Tri- Lateral Injection Well (A, B, and D Sands) • Began first MI cycle 11/23/09 • Completed first MI cycle 3/15/10 and was on '" ✓/ .4�, produced water injection through the end reporting period of 6/30/10 f • No premature breakthrough events detected • No oil production response from FOR detected at ' offset producers LU r� r U-170 Pattern ' • Offset producers: 1J -166 & 1J -168 (Possible) • Tri- Lateral injecting to A & D Sands only (B Sand isolated from pre -pilot MBE to 1J -166) j • Began first MI cycle on 4/4/10 { • On first MI cycle through the end of reporting period of 6/30/10 with plans to place back on water injection in July 2010 ' No premature breakthrough events detected • No oil production response from FOR detected at offset producers V a '1v � � I i 1J-122 Pattern Y ; t l • Offset producer: 1J -120 • Tri - Lateral injecting to A, B & D Sands f f • Began first MI cycle on 4/4/10 • On first MI cycle through the end of reporting period of r.,r 6/30/10 with plans to place back on water injection in f July 2010 • No premature breakthrough from detected • No oil producition response from FOR detected at offset producers �a t i • Iniection Performance and FOR Response The VRWAG flood is being managed by injection pressure. Operating rates vary according to geology, well configuration, pore pressure, and injection pressure. Injection rates have been limited to 2.0 MMSCF /d until the maximum operating injection pressure is achieved. At that time, injection rate is controlled by the downhole injection pressure limit. When the wells are converted back to produced water injection (PWI), the downhole pressure remains as the injection rate control limit. The following graphs indicate water /gas injection rates on the 4 pilot injectors and oil production rates and GOR on the 4 primary focus producers and 2 possible response producers. 1 E -102 Water /Gas Iniection Daily Rates . 2100 1100 1960 1 X10 1920 1200 1680 1100 154 1000 1100 900 j 1260 R � � 5 No 1120 s 100 � n 6010 eJO � s0o 200 100 560 700 120 200 790 00 /i 110 0 0 J.01 FA09 01.06 Ap10 My06 M09 No 101906 1001 WN NOV09 0.c09 J.19 TON 11.10 ,yr10 MIg10 0110 1E -117 Water /Gas Infection Daily Rates V00 ■ 0 . _ 0 . - 20% 1600 Iwo ism 1770 1100 1652 1300 1501 i 1700 1416 1100 1298 1000 � / 11900 800 / 1062 r � 900 , 944 yy 700 oa < wo IN 590 IM 472 300 8 711 700 100 '/ 1H r 0 0 J.+O9 406 me 00106 Mir" 0106 0606 Ay# 19006 00101 Nw06 Oa01 0114 1406 0101110 Ap MV18 W 0 i U-170 Water /Gas Infection Daily Rates 1800 lri uataAVw+ 6 uuc_e vwr / o-rro oNOr p urt4ACwt p uaa_o w++ 2181 2700 2346 1600 2208 1500 2070 1400 1432 1300 1794 1200 1G£ 1100 15111 1000 13805 i 900 1242 i 1100 " 1101 , t 700 � Y 6m 12B i 690 542 414 276 l OD 130 0 Jen OD Fs�A9 idr D9 A pr 09 M r704 du+ J 09 Au Sep OS 00109 Nw04 Oft OS Jan10 Feb10 Mar10 $ Ay 10 Mn10 Jw" 1J -122 Water /Gas In ectlon Daily Rate 1100 C un�e vAr O u- rLO`eu p uu>_e nn+ voase 2126 1000 2660 900 2334 2128 700 1862 < p �^ 15% solo rc 1370 Alm K 1064 .100 3w sm 1O0 ° e 4w Fe4 O9 Mr 89 A P OS Ma M Ju+09 Jar OS Aup 09 Sep W Od OS Nw 09 Om OS Jan 10 Feb 1O Ma W Ap 10 Neq 10 Ju�10 A2 1E -170 Oil Production Daily Rates 1300 0 E -110 A OPRI © E -AC B OMI 97 K -ITC O OPRI 1200 1100 1000 900 4 200 C 8 cao d 0 500 I 400 100 0 Ja 09 Fob09 I1a09 Ap09 My09 Ju 09 JJ09 14109 N00! Od09 Nov09 D.CS J-1 Fob10 MM10 Ap10 M4y10 JI 10 U -168 Oil Production Daily Rates 1700 N Y-M "1 13 IJ -pt B OPM ® U-NO O OPRI 1200 1100 1000 900 AL > 807 8 700 400 700 100 100 0 Js 09 Fob 09 Mr 09 Apr D9 My 09 Jun 09 JJ 09 Aup OS Sp 09 Dd 09 Nov 09 Dk 09 Ja 10 Fob 10 Mr 10 Am 10 My 10 An 1 0 0 0 1J -166 Oil Production Daily Rates a000 ® u -Ke Ao PRI ❑ Iisa RoPRi B a.- OoPRI 3000 4 y 7b 2OW 6 O 1000 0 Jan W F609 M. Ap W May 09 Jun 09 Jul W Aup Os Sep W o4 W Nov W Dec W Jan 10 rob l0 M« t0 Apr 10 MN u0 Jun 10 1J -120 Oil Production Daily Rates 1400 ® 11220 A OPRI ❑ 1.-220 a OPRI 93 /J-220 O OPRI I 1300 1200 1100 1000 900 Q G � no O 300 fi 400 30D 100 0 Jan 89 Feb 09 Me 09 A{.v W May 19 Jun 09 JJ 09 Auq W Sep O9 OcI W R-09 Dr_ W Jam IC rab 10 Ma 10 Apr 10 MN 10 J un ifl 1B -101 Oil Production Daily Rates 1600 13 /e I01 B OPRI ❑ IB -101_0 OPR/ 1500 1100 1300 1200 1100 1000 K O 9w h 16 6m 6 700 O 600 S00 100 000 200 100 0 Jan 09 Feb D9 M&09 App 09 May 09 Jm 09 JJ 09 Aug 09 Sep 09 Oct D9 Nov 09 Dec 09 Jen 10 Feb 10 M& 10 Ap 10 May 10 A.10 1E -121 Oil Production Daily Rates 1000 ® IE- 1210OPPI ❑ W- 12LOOPAI 800 000 700 t 600 0 500 0 100 700 100 100 0 Jenl Feb09 Mr 01 APO W/If Amm JJQ3 Au009 Sep 09 Oct09 M-09 0ec09 Jen1O VAN Mrs Ap10 WrIS JIw10 0 0 1E -123 Oil Production Daily Rates N /E- M - 001-RI *422 OOPM 100 A; 1 r S 200 IM " I JrIa1 i@b09 M&,M AWM My09 Jn09 J,109 AWM Sep09 0d 09 14ova9 Dn09 JmIC ►4b10 Me10 Am10 MyiO J-10 FOR Response Plots The FOR Response Plots are shown for the following injector /producer well pairs: I njector /Producer Open Injector Zones Open Producer Zones 1E- 102 /1E -121 D Sand D and B Sands 1E- 11711E -170 D, B and A2 Sands D, B and A2 Sands 1E- 117/1J -168 D, B and A2 Sands D, B and A2 Sands U-170/1 E -166 D and A2 Sands D, B and A2 Sands 1J- 122/1J -120 D, B and A2 Sands D, B and A2 Sands 1E- 102/16 -101 D Sand D and B Sands 1E- 10211E -123 D Sand D and B Sands Each set of FOR Response Plots includes an Oil Production Plot, a GOR and Watercut Plot and a VRWAG Injection Well Plot on the same page. The injection plot shows the timing of water and gas slugs on the same time scale as the offset production well's Oil Rate, GOR and watercut performance. • • 1 E -10211 E -121 VRWAG Response Plots West Sak 1E -121 Oil Production 3000 25W I— oll production �2000 N 1500 1000 500 0 Jan-05 Jai-06 Jen07 Jr►08 Dec-M Dec-09 Dec -1 West Sak 1 E -121 GOR and Watercut 50 — - - -- — 100 4.5 - - 90 4.0 — WaterCUt ...__. ... _..__ _.... 80 3.5 70 A Q 30 60 i . U e� Q 2.5 -._ _. ........_. - - - ... ............... .._- _,..._. .. .. .. _._. _.._ 50 O 20 40 C7 1.5 30 1.0 20 0.5 _._.. 10 0.0 0 Jan-05 Jan-08 Jan-07 Jan-08 Dec-08 Dec-09 Dec-10 West Sak 1 E -102 VRWAG Injection Well 3500 3000 —Gas Injection Rate N —Water Injection Rate 2500 g L) 2000 U 1n 1500 _. W C C 1000 � C 500 0 Jan-05 Jan-06 Jan -07 Jen-08 Dec-08 Dec Dec - 1E- 117/1E -170 VRWAG Response Plots West Sak 1E -170 Oil Production 2500 - - - - - - - - - - -_. -- 2000 --oil production 1 1- 1 00 loco a Sao Jan -05 Jen 06 Jen 07 Jen-08 DK-08 Dec-09 Dec -1 West Sak 1E -170 Watercut and GOR 5.0 --- - -- - -- — — 100 46 gor 90 watercu! � a. o so G 35 70 3.0 .. 60 f LL N 2.5 50 C 2.0 _ 40 $ v C 1.5 30 1.0 20 05 10 0.0 0 Jan -05 J&n m Jan -07 Jan-M Dec-M Dec-09 Dec-10 West Sak 1E -117 VRWAG Injection Well ,oao _ 35M Gas Injection Rate —Water Injection Rate 3000 N O 2500 LL V 2000 1500 1000 __... _ 0 )WI-05 Dec-0e Dec4g Dec -10 1E- 117/1J -168 VRWAG Response Plots West Sak 1J -168 Oil Production 2500 — — 2000 --- 0 production 1500 N O 1000 d 5 500 Jan-05 Jan-00 Jan -07 JanM Dec-M Dec.09 1ec - West Sak 1J -168 GOR and Watercut 5.0 __ —. - -- — 100 4.5 90 40 90f so 3 WaterCUt 70 m 30- w , t N U 2.5 50 iii 0 2.0 40 U' 15 30 1.0 20 05 10 0.0 0 Jan -05 Jan45 Jan -07 Jan-M Dec Dec Dec - West Sak 1E -117 VRWAG Injection Well I M - A 3500 — Gas Injection Rate —Water Injection Rate �3000 N O 2500 e 8 2000 S 1500 K 1000 500 ;; 06 0 Jan_oS Jan-06 Jan -07 Jw-M Dace Decor Oec - 0 0 1J- 122/1J -120 VRWAG Response Plots West Sak 1J -120 Oil Production 3000 2500 1 -011 production d 2000 1500 1000 a 500 0 Jan -05 J" Jan -07 Jane Dec-08 psaoo Dec -1 West Sak 1J -120 GOR and Watercut 5.0 - 100 4.S go 40 gor 80 — watercut 3.5 70 LL 30 60 a ft 25 `'o 2.0 40 b 30 t5 1.0 20 0.5 10 0.0 0 Jan -05 Jar,06 Jan•07 Jen-08 Dec-08 Dec-09 Dec -10 West Sak 1J -122 VRWAG Injection Well 4000 — 3500 Gas Injection Rate 3OW —Water Injection Rate 5 2500 in 2000 1500 rc 1000 € Soo 0 Jan-05 Jan-05 Jara.07 JSrAS Dec-08 Dec-09 Dec -10 • 1J- 17011E -166 VRWAG Response Plots West Sak 1J -166 Oil Production 6000 5000 oil roduction 4 J00 L 300G 2000 1000 Jan-05 Jan-06 Jan -07 Jen-06 Dec-W Dec-09 Dec -1 West Sak 1 J -166 GOR and Watercut 5.0 -- - -- 100 45 90 4.0 — WaterCUt so 35 70 30 60 >f Y. U 2 5 50 O 2.0 40 1, 15 30 10- 20 05 10 0.0 0 Jan -05 Jan-06 Jarr07 Jan08 Dec-0e Dec-05 Dec -10 West Sak 1J -170 VRWAG Injection Well 4500 -- 4000 tv - Gas Injection Rate 9500 `Water Injection Rate to O 9000 ..__,_. _._... LL 2500 2000 ------- .. _ ._.... ai p 1500 O 1000 500 0 Jan -05 Jon-06 Jan-07 Jon-06 Dec-M Dec-09 Dec-1 • 0 1E- 102/1B -101 VRWAG Response Plots West Sak 1B -101 Oil Production 3000 - -- -- - - - - -- - -- - - - - -- - - -- -- 2500 - -' oil production 1500 a 1000 500 0 Jan -03 Jw-04 Dec14 Dec4)5 Dec-06 Dec -07 Dec-08 Dec-09 Dec -10 West Sak 1B -101 GOR and Watercut 20 0 100 180 9or e0 16.0 '— WaterC so 140 70 12.0 ye w 10.0 50 S 0 k0 6.0 - . _ ..... - - 30 4.0 _. _. _.__..._... 20 20 10 00 0 Jen-03 Jan-04 Dec-04 Dec-05 Dec-05 Dec -07 Dec-08 Dec-09 Dec-10 West Sak 1E -102 VRWAG Injection Well 4000 - -- - -- 3501 Gas Injection Rate 2 X00 —Water Injection Rate � S 2501 N 2000 1500 — C 1000 S00 0 Jan03 Jan4)4 Dec-04 Dec45 Dec-06 Dec -07 Dec-0e Dec-09 Dec -10 • 0 1E- 102/1E -123 VRWAG Response Plots West Sak 1E -123 Oil Production 4000 — 3500 -- of production 3000 a: 2500 € 2000 1500 .........__._ __... 5 1000 500 0 Jan -03 Jan-04 Dec-04 Dec -05 Dec-06 Dec -07 Dec-08 Dec-M Dec -10 West Sak 1 E -123 GOR and Watercut 5.0 - - - - - -- - - 100 4.5 i° gor 90 4.0 Watercut 60 35 70 30 60 T LL 0 25 50 Q 2.0 40 3 C7 1 5 _.. ._ _ <_ 30 10 20 0.5 10 o.0 0 Jan-03 Jan-04 Dec-04 Dec 4S Dec-06 Dec -07 Dec-08 Dec-09 Dec -10 West Sak 1E -102 VRWAG Injection Well 4000 - -- — as Injection Rate —Water Injection Rate 3000 p 2500 Q N 2000 1500 _ 1000 b 500 0 Jan-03 Jan-04 Dec-04 Dec-05 Dec-06 Dec -07 Dec-08 Dec-09 Dec -10 Monitoring and Testinn Per the results of gas sample tests from offset producers, no significant gas breakthrough is detected and, therefore, the VR -WAG cycles will continue as planned on the three remaining VR- WAG Injectors. Primary focus for MI producer response monitoring is on wells 1E -170, 1J -168, 1J -166, and 1J- 120. A plot of 1 E -121 produced gas analysis is also included to show the impact of MI breakthrough from the MBE on gas composition. 1E -121 Produced Gas Samples 1 E -121 Gas Analyses 1000 100 10 e v 1 a 0.1 0.01 im CO2 N2 C1 C2 C3 t-C4 N -C4 I-05 N-05 C6 C7 C8 C1IC3 Ratio Component p 514/09 ■ 12/29109 0 12131/09 o 1115110 a 7/2110 1E -170 Produced Gas Samples 1 E -170 Gas Analyses 100 10 -- - a 0.1 0.01 CO2 N2 Cl C2 C3 I-C4 N -C4 I -05 N-05 C6 CT C8 C1 /C3 Ratio Component a 10/17/09 ■ 12/30/09 t7 3/7/10 O 7/6/10 0 # 1J -168 Produced Gas Samples 1J -168 Gas Analyses 100 10 d m 1 - a 0.1 001 CO2 N2 C1 C2 C3 1 -C4 N -C-4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component 010!17/09 ■ 12/30/09 o3/7110u716110 U -166 Produced Gas Samples 1J -166 Gas Analyses 100 10 n. 01 0.01 kil CO2 N2 C1 C2 C3 I -C4 N -C4 I -05 N -05 C6 C7 C8 C1 /C3 Ratio Component u 5/4/09 •5/21/10 0 7114/10 9 0 U -120 Produced Gas Samples U -120 Gas Analyses 100 10 � 1 - a 0.01 CO2 N2 C1 C2 C3 1-C4 W-4 1-05 N-05 C6 C7 C8 Cl/C3 Ratio Component c 4/21/10 ■ 6!27/10 ❑ 7/12/10 1E-121 and 1E-123 will be monitored for VR -WAG Pilot- specific response, but none is expected to be observed since MI was active for such a short period of time on the 1E -102. 113-101 was determined initially to potentially receive support from the 1E -102. The 1B -101 was brought online following a workover on 4/10/10. Following flush production resulting from an extended shut -in period, the well has since gone back to pre- workover rates indicating there is no significant support from the 37 day gas injection period on the 1E -102. However, the 113-1Q1 wi11 continue to be monitored. MBE Development The 1E -102 experienced an MBE shortly after commencing the first VRWAG Pilot gas injection period. It is possible the gas injection cycle accelerated the rate at which the MBE path became fully established, but in all likelihood, the MBE path was nearly developed at the time the VRWAG Pilot began and would have fully developed within a short period of time regardless. The three remaining patterns continue to be monitored closely to determine if the pilot program has affected the likelihood of an MBE to occur. To this date there is no evidence to suggest any change in likelihood. • • ~'~~~a ~; 3: ,. `~ ~~ r n~. ~. ,~~ ~; 5, __ ._ ~ ,,~„~,~: ,x,, ~~ ~ - "~~ ~ ~ ~, ~;~ ~ ° MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc MEMORANDUM To: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May 24, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1J-122 KUPARUK RIV U WSAK 1J-122 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV U WSAK 1J-122 API Well Number: s0-029-23369-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100516134447 Permit Number: 207-070-0 Inspection Date: 5/14/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IJ-122 •,'I'y a n~. I C, ~~7D 3684-~r-IA P.T.D 2070700' 'TypeTCSt SPT Test psi 1690 ~' QA --~~-~ . ~809 141 1690 / 214 1640 174 1620 ]56 Interval aYtzTST p~F P ,~ Tubing 1761 ~ 1761 1761 17so _ Notes: N~ln m ~ d, ,~~ rSL'r7P5; 't ~ ~ ~- f r Monday, May 24, 2010 Page 1 of 1 • L J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska.gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk /KRU / 1J 05/14/10 ~©7_07 I 5 ~ `~ "~ Colee /Phillips - AES Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-102 Type Inj. W TVD 3,566' Tubing 657 656 655 654 Interval 4 P.T.D. 2061100 Type test P Test psi 1500 Casin 990 1,700 1,680 1,680 P/F P Notes: OA 165 205 172 165 Well 1J-105 Type Inj. W TVD 3,639' Tubing 558 558 558 557 Interval 4 P.T.D. 2070270 Type test P Test psi 1500 Casing 1,098 1,800 1,780 1,780 P/F P Notes: OA 155 156 156 156 Well 1J-118 Type Inj. W TVD 3,599' Tubing 657 658 658 658 Interval 4 P.T.D. 2061760 Type test P Test psi 1500 Casing 1,100 1,790 1,780 1,780 P/F P Notes: OA 175 192 177 175 Well 1J-122 Type Inj. G TVD 3,684' Tubing 1,751 1,751 1,751 1,750 Interval 4 P.T.D. 2070700 Type test P Test psi 1500 Casing 809 1,690 1,640 1,620 P/F P Notes: OA 141 214 174 156 Well 1J-127 Type Inj. W TVD 3,482' Tubing 620 620 622 622 Interval 4 P.T.D. 2060470 Type test P Test psi 1500 Casin 1,020 1,700 1,680 1,680 P/F P Notes: OA 206 273 260 253 Well 1J-136 Type Inj. N TVD 3,503' Tubing 600 600 600 600 Interval 4 P.T.D. 2061540 Type test P Test psi 1500 Casing 276 1,700 1,670 1,660 P/F P Notes: OA 173 183 182 180 Well 1J-154 Type Inj. W TVD 3,437' Tubing 624 624 624 624 Interval 4 P.T.D. 2050350 Type test P Test psi 1500 Casing 1,098 1,850 1,840 1,840 P/F P Notes: OA 527 527 527 527 Well 1J-156 Type Inj. W TVD 3,410' Tubing 628 625 623 620 Interval 4 P.T.D. 2060670 Type test P Test psi 1500 Casing 1,147 1,900 1,890 1,890 P/F P Notes: OA 206 206 206 205 Well 1J-160 Type Inj. W TVD 3,212' Tubing 626 626 626 ~~ 625 Interval 4 P.T.D. 2070150 Type test P Test psi 1500 Casing 925 1,680 1,650 1,640 P/F P Notes: OA 332 333 333 334 ~~s MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s V V ~ i Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-164 Type Inj. W TVD 3,424' Tubing 580 578 576 576 Interval 4 P.T.D. 2051440 Type test P Test psi 1500 Casing 140 1,700 1,690 1,690 P/F P Notes: OA 731 731 732 732 Well 1J-170 Type Inj. G TVD 3,392' Tubing 1,863 1,865 1,866 1,866 Interval 4 P.T.D. 2060620 Type test P Test psi 1500 Casing 440 2,600 2,560 2,550 P/F P Notes: OA 155 304 243 217 Well 1J-176 Type Inj. W TVD 3,159' Tubing 665 Interval 4 P.T.D. 2070990 Type test P Test psi 1500 Casing 1,268 P/F Notes: Test inconclusive OA 170 Pumped 10 and pressured up 100 psi. Need to top off and retest. Well 1J-180 Type Inj. W TVD 3,290' Tubing 584 584 585 587 Interval 4 P.T.D. 2061500 Type test P Test psi 1500 Casing 1,050 1,690 1,680 1,680 P/F P Notes: OA 145 226 225 224 Well 1J-184 Type Inj. W TVD 3,337' Tubing 598 598 597 597 Interval 4 P.T.D. 2060440 Type test P Test psi 1500 Casing 925 1,700 1,680 1,680 P/F P Notes: OA 165 220 178 172 TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test V V INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 KRU 1J pad 05-14-10.x1s ~~~ STATE OF ALASKA APR ~ ~~ AND GAS CONSERVATION COMMISSIO _ REP~RT_QF SUNDRY WELL OPERATIONS ~. Operations Performed: '' Repair well ~ Plu F~rforations ; Stimulate WINJ to WAG g ~ (1 Other ~ Conversion ~fl Alter Casing j Pull Tubing ( Pbrforate New Pbol ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdow n ~ Parforate ~ Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: ~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory ~ ~ 207-070 3. Address: Stratigraphic C Service ~ .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-00 7. Property Destignatign: 8. Well Name and Nu}~ber. \ ALK 2 661 & 25650 1 J-122 9. Field/Pool(s): Kuparuk River Field / est Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 15109 feet Plugs (measured) None true vertical 3961 feet Junk (measured) None Effective Depth measured 14616 feet Packer (measured) 10970' , 14542 true vertical 3970 feet (true vertucal) 3788' , 3971 Casing Length Size MD TVD Burst Collapse CONDUCTOR 106 20 106 106 0. 0 SURFACE 3610 14.5 3640 2211.87 0 0 INTERMEDIATE 11902 9.625 11928 3931 0 0 "A" LAT SLOTTEI 3646 8.32 14616 3970 0 0 ~,{a=,; -` ~ . - .. Y C ' `: ~ vn ~ . ~..1. l a Perforation depth: Measured depth: 11032-14616' True Vertical Depth: 3932-3972' Tubing (size, grade, MD, and TVD) 4.5, L-80, 10299 MD, 3684 TVD ~.zz./~ "t° ~~1~ kt R L 1o n F? -k:ar; TCr j3G~l Packers &SSSV (type, MD, and TVD) PACKER - ZXP Liner top packer, A sand swell packer @ 10970 &14542 MD and 3788 & 3971 TVD SSSV =Nipple @ 509 MD and 508 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 284 1188 610 Subsequent to operation 0 1767 0 954 798 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ~ Development ~ Service . Well Status after work: Oil ~ Gas ~ WDSPL [~" Daily Report of Well Operations X WAG ~, GASINJ WINJ ~ SPLUG GSTOR 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 309-058 contact Bob Christensen/Darrell Humphrey Printed Name Ro rt D. Christ sen Title Production Engineering Specialist ~ Signature _ Phone: 659-7535 Date ~~ ~ Form 10-404 Revised 7/2009 RBDMS APR 2 2 201Q~w~ r/ ~ ~. 27. !V ~1 `T~c Submit Original Only • • 1 J-122 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/05/10 Commenced WAG injection. KRU 1 J-122 ~: m" ConocoPhillips Alaska, Inc. ~ • • f ~ ~ 4 "~ ~~ ~ f'~'' i K" F ~ ~ } ~ f "n y ~ ~ f ~ ~ ~ ~~ y, -_ ~ ° L ~~ ~"~ ~~ ~ ~~ ~~. ~~~'~ ~~~ ~~'~~ ~~~~A~ ~~~ ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ~~~~ ~~ ~b~~ r ~'w~ ~_~ ~: ~~~ ~~ ~~ ~ ~ ~,: ~~~~~ ~~ ~ ~ ~~ ~ ~ ~ ~a~c-a~-7t~~ ~I~ 1'~lsa~ a~[v~,7 333 W. 7th AVENUE, SUITE 100 CD~S~i~QA1i0~ CD~IIS'5~0~ ANCHORAGE,ALASKA 99501-3539 ~ PHONE (907) 279-1433 FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 ~ Anchorage, AK 99510 ~ . ... ....'.e _ ,~ ~ ~ Re: Kuparuk River Unit, West Sak Pool, 1J-122 Sundry Number: 309-058 ~'~t~flVE~ N~ ~ ~ ~ 200~ Dear Mr. Loveland: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~ Cathy . Foerster Commissioner DATED this day of October, 2009 Encl. • ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~~~0~ , ~~~ ~,OO~ . ~ ~'~G~ ~ ~ ~.~'0~~ ~~~ .y ,~~r~~ P~~otia~ ~~a~~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sak injection well 1J-122 (207-070), 1J-122L1 (207-071), 1J-122L2 (207-072) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, ,.~~~~ ~~~~. ~ MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ ~ p~ • ~ ~E~E~~'~~ ~ STATE OF ALASKA ~~,~ ALASKA OIL AND GAS CONSERVATION COMMISSION FEB ~ 7 2009 ~° APPLICATION FOR SUNDRY APPRC~IW~.Di1 & c~s Cons. Cammissior~ 20 AAC 25.280 Anchoraae 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ ~ Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, It1C. Development ^ Exploratory ^ 207-070 ' 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ^ NO ~ 1J-122 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK 25661 ~& 25650 • RKB 109' ' Kuparuk River Field/ West Sak Oil Pool , 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15109' ' 3961' • Casing Length Size MD ND Burst Collapse CONDUCTOR 78 20" 106' 106' Surface 3612 13-3/8" 3640 2211' Intermediate 11900 9-5/8" 11928' 3931' Liner A sand 3646 7"x5.5" 14616 3969' Hook Hgr assy (B) 257 5.5" 11079 3696' Hook Hgr assy (D) 250 5.5x4.5" 10557 3612' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted and Blank liner 11032-14616' 3932-3972' L-80 L-80 10303 Packers and SSSV Type: Packers and SSSV MD (ft) ZXP Liner top packer, A sand swell packer 10970', 14542 No SSSV - Nipple 509' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~^ ' 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: ~`~ v/ L'% ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q. GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/Perrv @Itl Title: Well Integrity Project Supervisor Signature ~P'~ ` ~ Phone 659-7043 Date ~ / j t~ ~' Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~~i ~ ~/'~ ~Oi, T /h 4cCc~'X w r ~ Z U. ~t'/`"f' t a~ G.. o~ Subsequent Form Required: ~ ~ "'" ~-~ ~ ~ / APPROVED BY , ~ Approved by: -~~iY! `i'(/' COMMISSIONER ,e~ THE COMMISSION Date: ~D'~ V~ Form 10-403 I~vised 06/2006 • ~~'~ [~j ~~~ Su it in Duplicate ,,~~j.~~~'~~ ~..~-q C~ 6~ ConocoPhillips Alaska, Inc. 1J-122 (PTD 207-070) & 1J-122L1 (PTD 207-071) & 1J-122L2 (PTD 207-072) Sundry Nofiice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in West Sak Injection Well 1J-122 and gain approval to do so. ~ This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1J-122 was drilled as in July 2007 as a trilateral development well and converted to ~ a water only injector in October 2007. The well was drilled with a 20" conductor to 106'. The surFace hole was drilled with a 16" bit and cased with 13-3/8" casing to a TD of 3640'. The casing was cemented in place with 847 bbl of lead cement (Arctic set) and 165 bbl of tail cement (Litecrete). Bumped plug on calculated displacement volume and the floats held. There were good cement returns, 291 bbl recovered. The intermediate hole was drilled with a 12 1/4" bit and cased to 111932' with 9 5/8" casing. The casing was cemented in place with 366 bbl Deepcrete cement plug was not bumped however, good returns were mentioned. The top of cement is confirmed at 5920' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervals. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1 J-122 2. Injection well 1J-122 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 J-122 will be completed (or / recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating / transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. • ~ rl __-~ f ~1~. , , ,~i~ : ~ ~ ~~ ~~. ~~5~$ ~ ~-.~/ r ~ . ' ~ ~ ~ ~ I . - _ ' _ • ` ' ~ ~ y ~ r ~ ,.-~" • ~` _ - 1 ~ 1 E-102 ~ .. . . ' ~ _~ . - ~._. ~ ~ ; ' - .., . , ~ r _ ~ : ~ _-. - a ` --- --___ - j ~ ~ r - ~ ~ ~ r ~ t ~ . 4* 'f ~ r + J ~ ~ ~ ~ +~ ~ ~ ~ ~ ~ 2009 WSAK EOR . ~ . ~' - - ' ~ ' ~ ~ ~C. 'T f n - f'` ~. ~ g Pattern Tar ets ' : ~. - _ - ~ ' ~ ~, • - .. ~ = ~ _ _ . i? ~ ~ '~~' ^ ~ : r --- _ --~- --~ ; ~ ~ • . . ' . ~:~ ~ . . _ ~ r , ~ ,,. j ; r .. ` - - . . ~ r . . r, ~'f .. ~ . . = :~ ~ ~ ' ~ ` 4 ~!~. ~ ~ ~ 1 1-177 ~= 1 J-~ / 0 ' • ~ . • ~ ~ ~ ~ ~ 1 ~ ~ ; _ _ ~ . ~ ~ _• I ~ ' g ~ I i ~ ~ . ~ ' -' ~ ~ ~ ~ ~ . ; ~ i ~ ~ :~ ~ j ~ . ; . ~ ~-~_ _ - - ' ; . , , ~ ~ ~ ~• ~ ~ ~ f ,.,, . . ~ ,_ - '': ~ I _ ~ ~ jS ~ ~ ~ ~ - o ~ ~ , ~.~.++a - ~ ~ _ , ~ EOR .Afiec,le~d 1Metf ~ 1 E-117 ~ r: ~ ~ ~ _ _--,~H~.r~ -,~,~ ~ , ~. , f . ~~ ~` ~ 1 ' ~ ~ ~~ ' ~' ` „~ ~ - Ofher KRU Wra11 I i -- ~ +~ . • ~ ws W~.alor se~arn9 Feuns ~ ~ ~' ` ` ' ~ j~ ~ VV^ Faa~lts .. ~~ ~ j ~` .~ ~ 1 I' i ` ~ ' . ~ ~ ~ ~ ~' ~ • GL PrOtfuGO~ Prod~oer ~ '~ I ` _ : S1 Producwr ~, ~" j ~ I ~~ ~ P arW A ` ~ ~ ~~ ~ ~ I z } " • ~ ~ Y + In1eC~cX . t ~ ' ~ ti . „~ ~_~ _ YE-io2 t~a rn. Bu~ ~ ~ ~` i Raw~ 1!4 m~ Bufbr ~ + ~ ' _ f iV Rov~r t ld rni BufhlE ~ ~ _ ~ C 25 O.5 ~~ J _ ' 2 1A~1si ~ Row 7ia m~ BuMar t7ni~s~t~ Bd~~y4ary yy`~' PA BOUrtdiry ~ • 1 J-122 Cement Log Bottom interval 11,8E Middle interval 9,71 ~ N~ ~ • GASR ~ •Pretty good bond around immediate vicinity of shoe •Persistent poor bond along wellbore uphole but intervals of better cement bond are abundant •Top of cement at 5,920' Tops UG C 7,277 •550' of cumulative bond noted from USIT UG B 8,484 UG A 8,979 K13 9,477 D 10,295 Top interval 3,870-4,090 ~ r in r t d f r ~ ~ ~~~ ~ ~acent capture producers ar~ curr~ntly ~r ~vill b~ ~~~~~~ ~~~~ t L cornpletion~ ~rith pack~r~ before VRI ~ta~ ~~ ~~~~en~e~ ~ ~~~ectors hav~ r~ ary cern~n~ ~~v~r~~ th~ ~~~ ~~~ ~~ nu forrnations ~nd h~v~ I~t~l~ r~~k o~ ~~ein~ p~~~~~r~ ~~ ~~~~~~ ~ ~~paruk rnrelf penetrat~ons withir~ qu~rter mil~ r~d~u~ ~r~l! ~~~~ ~~~t~red annular pressures ,~~t71?9 ~.~l:~ ~UR ~IeR Integrity Review with AOGCC ~~~yi.~~~~, ~~„ ~Qt~~ !> ~ ~ ~~r~~~~~'h~ll~~as 1 J~122 Pattern II, ~ •1Nest Sak Penetration of 1 D434 f~lls within ~/~ mil~ ~f 122 •122 surface job didn't have good circul~tion and plug didn'~ bump for the intermediate jobo However, IJ~IT shows ~~5Q' of good cement bond ~1 D-34 surf~ce casing b~low V~/est ~ak 1 st Stage on 1 D-34 surFace job lost returns but 2nd stage had cement returns to surFace •1 J-120 a ~L completion •1 D-141A a GL completion •V~/ell vvill test both D, B and A2 sand~ ~ ~ bp ~ ~. .~. `~~,~ 2Q09 WS EOR Well Integrity Review with AOGCC January 21, 2009 ~ Cono~oPh i I I i ps •847 bbls of lead cement and 165 bbls tail cement •Burnped plug on calculated displacement •Floats held •291 bbls cement to surFace •Float equipment top @ 3,565 Interrnediate •12'/4" hole size; TD @ 11,932' 1 J-122 Injector Cement Details Surface , •Conductor 20" and TQ @ 80' •Surface hole drified with 16" bit, TD i •13.375" surFace casing TD @ 3,640' •Stuck Gasing off bottorn while runnin ~~ ~: ~y ~ n U 2009 WS EUR Well Integrity Review with AOGCC January 21, 2009 10 _ ~ G Q ~~~~~~~~11I I I ~5 ~~ttorr~ interval Middle inter 11,$60-11.640 9.710-9.490 - GASR P.7DR °F~r~tty ~~od ~and around immediate vicinity of shoe ~I~Cr~ist~~t pc~or bond along wellbore uphole but intervals of better cement bond are abundant ~Tc~p df ~em~nt at 5,92p' Tops UG C 7,277 ~~5d' +~f ~tai~~~~l~tiy~ pond noted from USIT UG B 8,484 UG A 8,979 K13 9,477 L~C?~ ~Jl~~ ~UR Well Integrity Review with AOGCC D 10,295 ;i.,~, ~ ~ . ~ - ! ''~ ;,,~ I January~ 21, 2009 11 1J-122 Cement Log val Top interval ~, 870-4, 090 ~0~9 W~ ~OR Well Integrity Review with AOGCC January 21, 2009 5 ~~~ ~~r~~~~~i~ill~~~ °I J~12~ P~ttern ~V~/est Sak Penetration of 1 D-34 falls vvithin % mile of 122 •122 surface job didn't have good circul~tion and plug dedn't bump for the intermediate job. Hovvever, IJ~IT shows ~~~0' of good cement bond ~1 D-34 surface casing below V~/est ~ak 1 st Stage on 1 D-34 surface job lost returns but 2nd stage had cement returns to surface v1 J-120 a GL completion •1 D-141A a GL completion •VVell will test both D, B and A2 sands ~ s bp :1,~#~ z~~~. ?QQ9 WS EOR Well Integrity Review with AOGCC Januar~ 21, 2009 ~ ~~n~coPhil~ips 1 J-122 Injector Cement Details Surface •Conductor 20"' and TD @ 80' •Surface hole drilled with 16" bit, TD @ •13.375" surFace casing TQ;~,7a 3,640' ' •~tuck casing Qff battam while running •RR7 hhlc nf laarl r.Am~nt anrl 1~,5 hhl~ 1 ~~ ~~~: i ~ ~ 2009 WS EUR Well Integrity Review with AOGCC January 21, 2009 10 = v v ~~1~~~~~~`11I I I ~S ~ottorr~ interva! Middle inter 1 { <F~r~tty ~~od br~nd around immediate vicinity of shoe =t~~r~istent pqor bond along wellbore uphole but intervals of better cement bond ars abundant ~Tc~~ n# cement at ~,92a' Tops UG C 7,277 Y~5C' nf ~tary-~ul~ti~~~ bond noted from USIT UG B 8,484 UG A 8,979 K13 9,477 ~009 ~/VS ~~JR Well Integrity Review with AOGCC D 10,295 c N~ w~ c~ c z ~~ oc January 21, 2009 11 1J-122 Cerrtent Log val Top interval ~ Q~n n n~n ~ / ~,~ ~ ~j ~ g~ DATA SUBMITTAL COMPLIANCE REPORT 7/14/2009 Permit to Drill 2070700 Well Name/No. KUPARUK RIV U WSAK 1J-122 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23359-00-00 MD 15109 ND 3961 Completion Date 7/31/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y REQUIRED INFORMATION Mud Log No Sampies No Directional Survey No DATA INFORMATI~N Types Electric or Other Logs Run: GR/RES, USIT (data taken from Logs Portion of Master We~l Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / ~yp meairrmt numoer Name scaie meaia No start stop cri Receiveci comments og - Cement Evaluation 5 Col 1 5660 11865 Case 7/25/2007 USIT w/Maxtrac Tratctor 5- Ju1-2007 D D Asc Directional Survey 0 15109 Open 9/12/2007 D D Asc Directional Survey 0 4086 Open 9/12/2007 PB 1 pt 15533 LIS Verification 3608 15109 Open 10/12/2007 LIS Veri, GR, FET, RPS, ~ ROP D C Lis 15533~nduction/Resistivity 3608 15109 Open 10/12/2007 lIS Veri, GR, FET, RPS, ROP W/PDF and TIF graphics g Production 2 Blu 1 10200 11100 Case 11/19/2007 MPPL, Spin, GR, CCL, Pres, Temp, 3-Nov-2007 I og Injection Profile 2 Blu 9894 11088 Case 9/8/2008 Mem Injection pro, GR, CCL, Pres, Temp, Spin 18- Aug-2008 C Pds 16863 I~ tion Profile 9894 11088 Case 9/8/2008 Mem Injection pro, GR, CCL, Pres, Temp, Spin 18- Aug-2008 D C 18045 ~Induction/Resistivity 0 0 Open 5/21/2009 EWR logs CGM, EMF, PDS graphics og 18045 Induction/Resistivity 25 Col 108 15109 Open 5/21/2009 ROP EWR-4 DGR ~ 18045 Induction/Resistivity 25 Col 108 3961 Open 5/21/2009 ROP EWR-4 DGR ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 7/14/2009 Permit to Drill 2070700 Well Name/No. KUPARUK RIV U WSAK 1J-122 Operator CONOCOPHILLIPS ALASKA INC MD 15109 ND 3961 Completion Date 7/31/2007 Completion Status 1-OIL CurrentStatus 1WINJ Well Cores/Samples Information: Sample I~terval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y ~I Chips Received? Y / I~ Analysis ~CIAI- Received? Comments: Daily History Received? ~ ',"" Formation Tops ~ N API No. 50-029-23359-00-00 UIC Y Compliance Reviewed By: Date: ~ ~ ~ Packer depth questions ~ • Maunder, Thomas E (DOA) From: Fleckenstein, Robert J (DOA) Sent: Wednesday, May 27, 2009 12:06 PM To: Maunder, Thomas E(DOA) a~~_ b~~ Subject: FW: Packer depth questions Page 1 of ~h Attachments: 1J-122 tvd md.jpg; 1J-102 tvd md.jpg; 1J-102 - BOT - SB TLI Schematic - Rev2.pdf; 1J-122 HBB TLI Schematic As of 06-20-2007 (~th Torquemaster Packer).pdf; 1J-102.pdf; 1J-122.pdf Robert J. Fleckenstein Statistieal Technician II Alaska Oil and Gas Conservation Commission Office: 907-793-1242 Fax: 907-276-7542 *Please note new email address bob.fleckenstein c alaska.gov From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Tuesday, May 26, 2009 ~:41 PM To: Fleckenstein, Robert J(DOA); Noble, Robert C(DOA); NSK Problem Well Supv Cc: NSK Problem Well Supv Subject: Packer depth questions Bob and Bob, Ron passed on to me that there are some discrepancies in the top packer depths for recently tested wells 1 J-102 and 1 J-122. I pulled the drilling fites on both wells and compared the tubing tally to our schematics and found no discrepancy between the twa I believe the schematics to be correct. I've enclosed schematics, tubing tallies, and a screen shot of out ND / MD converter output for both wells. I can provide the survey data if it is needed. I show the top most sealing packer on 1J-102 to be at 4680.8 md and 3525.8 ND. CQ ~`~ ~' I show the top most sealing packer on 1 J-122 to be at 10301 and 3684.6 TVD. ~ ~~ If you have any questions please contact the Problem wells supervisor, Martin Walters at 659-7224, or N1617@ConocoPhillips.com ~~~ Q ~~ ~~° 8/18/2009 J Fil~ ~-av~rites Ton~s r , --- - _-__ __ _ _ _ _.._ _ _ _ ___._. _ _ _ _ __._.. . ~ Back - ;- x~ ~~ ~~ Favorites ~t, ~ Links ,~j Google ,~ j Perry Klein WhitePages Y! My Yahoo! ,~f schematia ~] ATDB :~ Drilling and VJells File Browser .~] ConocoPhillips Well Events Query ~~ , ~ __ _ `-__ _ _ ____ _.._~:_._ _ _ _ I Address P ubtp,JJakapps,~onocophillips.netJwebbertJCalculationsJDepthConversionfDepthConverter,aspx ~~ Go ~'~; - , ConocoPhillips ~ ~oi1n NID/TVDISS DeptL Conversions ~ Select ~~Vell ~ Field KUP ~ Business ~SAK ~ Area: _ Drill Site: 1 J ~ Input Depdi(s) 10301 J Input Deptli Type r.~ r 'I'~JD ~' SS ~ ~ ~ coxx ss Well: 1J-122 ~ ~ i ~ _ Convert ' - - _ _ _ --- - --- --- ---- ~Note s: I . NID,''I'VT depths must be input as positice values; SafC'.~~Rk aS depths must be input as negarive values. . Separate multiple depths with white space (blanks, tabs, new lines). ~e depths may be copied to a spread sheet by hig~litirig them and doing a standard copy and paste. _ _ _ _ _ _ _____ _ __ _- - - - _ ---- ------_ _ _- .. - --- - - - --- ---- - - ; tiUELL_NAIV~ API DPTH_INFUT INPUT_DFTH_TYPE DPTH_CORR_SS DPTH_NID DPTH_SS DPTH_TVD LAST_UPDATE_DATE LAST_UPDATE_ID X_LOC Y_LOC 17-122 500292335900 1~301 NID -3575.60 10301 -3575.60 3684.60 5/26f2009 4:08:41 PM LAEKUPG 566118.94 5946981.~ ~ ~~.~ ~~o~a • ~- ConocoPhillips Alaska, Inc. KRU 1J-122 1J-122 API: 500292335900 Well T e ~ PROD M le TS: de SSSV T : NIPPLE Orig Completion 8/1/2007 An le TD: 89 d 15109 Annular Fluid: , Last W/O: Rev Reason: GLV C/O Reference L:; 28' RKB Ref L Date: Last U ate: 1l28/2008 Last Ta :' TD: 15109 ftK8 Last Ta Date:' Max Hole An le: 92 d 14983 Casin Strin~_ ALL STRINGS Desai tion Slze To Bottom ND Wt Grade Thread CONDUCTOR 20.000 0 80 80 94.00 K-55 WELDED ' ~ SURFACE _ 13.375 0 3640 2212 68.00 L-80 BTC INTERMEDIATE 9.625 0 11928 3931 40.00 L-80 BTCM B-SAND WINDOW 10.000 10332 10333 3689 0.00 D-SAND WINDOW 10.000 10827 10828 3765 0.00 A-SAND SLOTTED LINER 7.5" 7.000 70970 11023 3796 26.00 L-80 BTCM A-SAND SLOTTED LINER 5.5" 5.500 11023 14616 3970 15.50 L-80 BTCM - = - Tubin~Strin - TUBING -- _.______Size 4.500 __ Top___ ____Bottom_ 0 10299 ND 3684 Wt 12.60 Grade L-80 Thread IBT Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 11944 - 12246 3932 - 3939 WS A2 302 32 7/5/2007 SLOTS Alternating slotted/solid pipe,2.5"x.125", 4 circumferential rows/ft, 3"centers sta ered 18d 12504 - 12975 3935 - 3945 WS A2 471 32 7/5/2007 SLOTS Alternating slotted/solid pipe,2.5"x.125", 4 circumferential rows/ft, 3"centers sta ered 18de 13235 - 13711 3951 - 3959 WS A2 476 32 7/5/2007 SIOTS Atternating slottedlsoiid pipe,2.5"x.125", 4 circumferentiai rows/ft, 3"centers sta ered 18d 13969 - 14530 3963 - 3971 WS A2 561 32 7/5/2007 SLOTS Alternating sloried/solid pipe,2.5"x.125", 4 circumferentiai rows/ft, 3"centers sta ered 18de Gas Lift MandrelsNalves ~ St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1' 2074 1702 CAMCO KBMG DMY 1.0 BK-5 0.000 0 12/22/2007 Other lu s e ui . etc. - COMPLETION ~ De h' ND T e Descrlption ID 23 23 HANGER TUBING HANGER 3.900 i 509 508 NIP CAMCO 'DB' NIPPLE w/3.875 PROFILE 3.875 10229 3672 SLEEVE-C BAKER CMD SLIDING SLEEVE - CLOSED 12/30/2007 3.812 10275 3680 LOCATOR SEAL ASSEMBLY LOCATOR 3.880 10276 3680 PBR BAKER 190-47 POLISHED BORE RECEPTACLE 3.880 10297 3684 ANCHOR SEAL BAKER 800-47 ANCHOR SEAL ASSEMBLY 3.860 ~ 10301 3684 PACKER D-SAND LEM BAKER TORQUEMASTER PACKER 813-47 x 38 9.625" 4.750 10313 3686 HANGER D-SAND LEM ABOVE HOOK HANGER 3.960 10327 3688 HANGER D-SAND LEM INSIDE HOOK HANGER 3.688 10422 3702 PACKER B-SAND HRD ZXP LINER TOP PACKER 6.210 10440 3705 XO Bushing_ B-SAND HH CROSSOVER BUSHWG 4.890 10441 - 3705 CSR -- -- B-8AND HH 109-47 CASING SEAL BORE RECEPTACLE - --- - - - -- 4.750 10461 3708 XO Bushin~ : B-SAND HH CROSSOVER BUSHING 3.940 10808 3762 HANGER I B-SAND LEM ABOVE HOOK HANGER 3.960 Other lu s e ui . etc . - A-SAND LINER DETAIL De th ND I T i Oescri tlon ID 10970 3788 ' PACKER A-SAND IWER BAKER HRD ZXP LINER TOP PACKER 6.320 10989 3791 NIP A-SAND LINER RS T PACKOFF SEAL NIPPLE 6.188 10992 3791 HANGER A-SAND FLEX-LOCK LINER HANGER 6.200 11001 3793 XO Bushin A-SAND LINER CROSSOVER BUSHING T x 5.5" 4.880 11002 3793 SBE A-SAND LINER 190-47 SEAL BORE EXTENSION 4.750 14542 3971 PACKER A-SAND LINER SWELL PACKER 4.950 General Notes Date Note 8/1/2007 NOTE: MULTI-LATERA~ WELL: 1J-122 A-SAND iJ-122L1 B-SAND 1J-122L2 D-SAND ~ -o~ ~,~33s~' o c~ ~ ~~ ` V ~ `^``\ (V\~ ^V ` T ~ TO" 94.0# x 14" Insulated Conductor, K-66, set at +l- 60' /~ ~~ Tubing, 4112", 12.6#, IBTM, Speclal Drlft to +~_ 500' `onocoPhi Ili ps 3.875"DBNIpple,forPosalbleSSSV,+~-500~ West Sak 9-5/8~~ HBB Injector GLM, Camco KBMG, 4„Z~. X,~. 1 J~~ LL GLM, Camco KBMG, 4,~z•• x,~• Tri-Lateral Completion - Injector CMD Sliding Sleeve, wl 3.81" DB Nlpple, +~. ~ jt above seals ~P-Q~ 13J/6", 68#, BTC Shoe set ~ 4,100' MD, 2,348' ND TorqueNlaster Packer Latrnl Entry Module(LEM) Tubing String 4112" 12.6#, L-80, IBTM D-sand Wlndow 3.958" ID, 3.833" DriR t 10,347' MD, 3,681' ND ~~' Sand Lateral PBR Seal Assembly wl 4-112" 11.6# l-00 HydHl 'P TorqueMaatef S ~~ Baker ECP 621 and BTC Slotted . ProducHonAnehof ~~ ~ LinerEvery,OtherJoint 4.76" Seal OD ~\~ _ y ~ 1-012" Oulde Shoe ~~ ~~~ ~~~'~ '~ ~ . , .R.,,~„~ ,.- ~. -. -. ~~ ~....,~4•112" Liner Shoe, 71.6#, L-80 Hyddl 621 and BTC ~ 7" Tieback Sleeve Set ~ 18078' MD, 3778' ND 7" X 9~18" Seal Borcs 4-112" bent muleshoe Model'B' HOOK Hanxr 7.8p" ID Seal Assembly 7" X 8~18" 2XP LAner Top 4.T6" Seal OD Paoker wl Hold Downs ~`~_ , Labnl EMry Module(LEM~ ,~_,. Assemblv .._~- 7" X 8~18" ZXP Llner Top Packer wlth Hold Downs Casinp Sealbore Reeepdcle 4.76" ID Orienting Proflle Automatic Alipnrtant of LEM Posltl~e Latehlny Colkt Intlioates Corrcet Location ~ Seal Bore for latenl Isoktlon - 7.68" ID ~ Aeeess Window Positive Latenl Aeeess Via Thru-Tubinq Diverter Seal Bore for Latenl Isolatlon • 3.68" ID ~ Isolatlon Seal Asembly 4.76" Seal OD 9.876' Seal ID Casing Sealborc ReceptacN 20' 4nqth 7" X 9~18" ~ Model'B' HOOK Hanoer Seal Bon ~.68" ID BAK____F~R~_ ~ua~a Baker Oil Tools As Planned With Diverters and Isolation LateralAxeas Diverter Laterallsolation Diverter GS Running Tool Shing Inatalled Instalkd (3.00" Lahral DdR) (~~`~" ID Malnhore D~ttt) ~ 'GS' Proflle for ~ CoilConnectnr i fRunnt~g/Rehkvi~gti~ ~ ' ~t.oo' ~engm~ Snap InfSnap Out ~ ~%' PoaitWe Locati`gti ~8ack Pressure Valve (7.80' Length) ~ Colkt ~ ~ ~ I Lahrellaolaflon~' _ i ~ r Flow•Thru Swivel i I Seels ~ ~7.25' Length) ` Lateral Diverfir ~' ~.. .I ~~ f - ~ Hydraulic . Ramp . r Dlawnnect \ ., IaolatbN Mainbore~ ~ ~ ~ ~1.50' Length) ~ ~ ~ \ Direrter Skeve r ~ -~ GS Spear ~ ~~ ~ ~ ~ (7.50' Length) ~. Leteral Isoletlon 8.85 tt Approx. i '. Seds ~~ OAI.• ~ r B-sand Window at 10,866' MD, 3780' ND ~B' Sand Lateral 4-112" 11.6d L~0 Hydril Baker ECP 627 and BTC Slomd __ ~ Liner Everv Other Jolnt 4112" Oulde Shoe 7 ~-Lr,~'u f--'~~~1 4712" LlnerShoe, 17.8#, L-80 Hydrll521 and BTC 7" Tiebeck Sleeve Set ~ 78086' MD, 3845' ND 4-112" bent mukshoe 3.662" DB Nippk 4112" 12.6# Tubin 3.83~" Dritt 3.968" ID ~ 7" % 9lJ8" ZXP Uner Top Paoker ~ with Hold Downs 7" X 9a18" Flez Loek LJnar Hanper I Packer Aasambly at Liner Hanpe~ +I-10,870' MD, a7l7 ND Cesinq Sealborc Reeepqele, 20' Lenpth Seal Assembly 4.76" Seal OD 'A' Sand Undulating Lateral 6•112" 16.6 # L-BO Hydril 7" X 9-518" HOOK Hanger Mafnborc Drltt: 7.00" Mainbore Drlft, with diverter: 6.26" Latenl Drih, no divertcr or LEM: 6.28" Lateral Drlft, wl diverter, no LEM: 6.12" LaterallMalnbore Diverter OD: 8.60" 4-1/2" Lateral Entry Module Mainborc Orik: J.68" Malnbore Drift, w1 isolation sleeve: 2.50" Latenl DriTt, wl coil diverte~: ~.OD" OD of Diverter and Skeve: ~I• 3.6 521 and BTC Slottetl 6-112" Eccentrlc L~ner Every Other Jolnt Guida Shoe '~^ j'~~ ' 5-7/2" Casing Shoe, 15.5 #, L-80 Hydrll ~ 521 and BTC ~~~°~ '~ Set ~ 76100' MD, 3990' ND 8-618" 40 # Casfng, L-60, BTCM, Set . ...__ „y at 12,220' MD, 3968' TVO 84 de °n'9T'"'~ m e.~r x n~, zooe. m4 aoou~i m.y na e. nprod~~od ar aiam~wka, m wnw. or i~ w~. i~ ny rorm or ey ~ ( 9) w~N s,w esie^ rnart.rr e~pee~ - M~ror anY ~ana Nee~ronlc or mecbnkal, Inclutll~q phofocoPY~~9, ~oNlnp, or Eyanylnbmutlon clanpe ana ._ . _. . . . __ __ __ - _ 21r1evY system iww knewn or hercaRer InventW. wtthout wrMen permissbn Irom Batet HupMS Inc. ~~e: June 74, 200T ~~~ ~Y~ DaNA BforY ~ewbnNe i ~- MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ~~ ~~ DATE: Wednesday, May 27, 2009 To: Jim Regg ~~~ ~ ~ P.I. Supervisor SUBJECT: Mechanical Integrity Tesu CONOCOPHILLIPS ALASKA INC 1J-122 FROM: Bob Noble KUPARUK RIV U WSAK 1J-122 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, '~ NON-CONFIDENTIAL Comm Well Name• KUPARiJK RIV U WSAK 1J-122 Insp Num: mitRCN090526113103 Rel Insp Num: API Well Number: 50-029-23359-00-00 Permit Number: Z0~-070-o Inspector Name: Bob Nobte Inspection Date: s/~a/2oo9 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~J'~22 Type Inj. ~' TVD 3684 Ip ~azo zooo ~sso t9so P.T.D zo~o~oo ypeTest SPT Test psi Z~o OA 186 2~0 195 ~so Interval 4YRTST P~'i P '~ Tubing 680 680 680 680 Notes: . Wednesday, May 27, 2009 Page 1 of 1 ~ ~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-122+L1+L2 May 14, 2009 AK-MW-5034903 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-122+L1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23 3 5 9-00,60,61 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23359-00,60,61 Digital Log Images 3 CD Rom ~ 50-029-23359-00,60,61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273-3535 Bry ~i dt~.com ~.. BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~ - - . ~a~ ~ ~ ZOu~ Date. Signed: ~~~ ~~~ ~ ~~~. ~~-~s~-~~ ~~c~~t~~ ~o~- _ ~ ~ t,~sau~ ~O~ JD~I `~~ L 7~ .~ _o~a t ~~~ ~D O ~ / ~ ~ ~ ,~ ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: b -' ~ `~ ~ ~ ~ `~ ~' ~ `~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl 7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Projects Supervisor , , ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field ~~~.~ Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft a~ 1 F-18A 204167 15' 5" 2.50 44" 10/30/2008 27.2 11 /7/2008 1E-16$ 204200 15" NA 15" NA 3.4 11/7/2008 1 E-17 205-074 13" NA 13" NA 5.53 11/7/2008 1J-12~ 207-070 15" NA 15" NA 3.4 11/7/2008 1J-1+~ 200-200 16" NA 16" NA 1.27 11/7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 1J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1 J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11/7/2008 1J-170 206-062 8" NA 8" NA 1 11/7l2008 1 J-174 207-143 24" NA 24" NA 17 11 /7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 LPP/SSV enabled on 1J-122 ~ ~ Page 1 of 1 Maunder, Thomas E (DOA) From: Rutledge, Kristen S {Kristen.Rutledge@conocophillips.com) Sent: Thursday, Septernber 25, 2008 10:16 AM To: Regg, James B(DO!A); Maunder, Thomas E(DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; CPF1 Prod Engr; NSK Problem Well Supv; NSK West Sak Prad Engr; Targac, Gary; Pierson, Chris R Subject: LPP/SSV enabled on 1J-122 Tom / Jim, The low pressure pilot (~PP) pn 1J-122 (PTD 207-070, 207-071, 207-072) was defeated on 9/2212008 and was returned to service on 9/25/2008. Current wellhead pressure is 557 psig; injection rate is 979 bwpd. The ~PP/SSV functian has returned to normal. Please let me know if you have any questions. Thanks, Kristen Rutledge Production Engineer, EDP ConocoPhillips Alaska, Inc Phone: (907} 659-7061 Email: Kristen.Rutledge~conocophillips.com 9/26/2048 LPP/SSV defeated on 1J-122 ~ Page 1 of 1 ~ Maunder, Thomas E (DOA) From: Rutledge, Kristen S [Kristen.Rutledge@conocophiNips.com) Sent: RAonday, September 22, 2008 10:30 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: GPF1 DS Lead Techs; CPF1 Prod Supt; CPF1 Prod Engr; NSK Problem Well Supv; Jenkins, Lubbie Aifen; NSK West Sak Prod Engr; Targac, Gary Subject: LPPlSSV defeated on 1J-122 Tom / Jim, The low pressure pilot (LPP) on 1J-122 (PTD 207-0~, 207-071, 207-072} was defeated on 9/22/2008 when the well was returned to service after being shut in for reservoir management during the 1 J-120 workover. The well was brought anline to support production. Current welfhead pressure is 447 psig; injection rate is 975 bwpd. The LPP and SSV have been tagged and their status is recorded in the "~acility Qefeated Safety Device Log." The AOGCC will be notifled when the injection pressure has increased to above 500 psi and the LPP/SSV #unction is returned to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know i# you have any questians. Thanks, Kri~ten Rutledge Production Engineer, EDP ConocoPhillips Alaska, Inc Phone: (907) 659-7061 Email; Kristen.Rutledge@conocaphiltips.com 9/22/2008 FW: LPP/SSV defeated on 1J-~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Sunday, September 14, 2008 7:13 AM 70: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Targac, Gary; NSK Probiem WeA Supv; Pierson, Chris R; NSK West Sak Prod Engr Subject: FV1l: LPP/SSV defeated on 1 J-122 Tom / Jim, The low pressure pilot on 1J-122, jPTD 207-07Q, 207-071, 207-072) was returned to service on 9/14/2008. The well is currently injecting 757 bwpd at 520 psi welihead pressure. Please let me know if you have any questions. Eric Hollar / Hai Hunt West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone 907-659-7061 Pager 907-659-7000 x836 From: Rutledge, Kristen 5 Sent: Wednesday, September 10, 2008 3:01 PM To: 'jim.regg@alaska.gov; 'tom.maunder@alaska.gov' Cc: CPFS DS Lead ?echs; CPFl Prod Supt; Targ~c, Gary; N5K Probtem Well Supv; )enkins, Lubbie Allen; NSK West Sak Prod Engr Subjed: LPP/SSV defeated on iJ-122 Tom / Jim, The Iow pressure pilot (I.PP) on 1J-122 (PT'D 207-070, 207-071, 207-072) was defeated on 9l1Q/2008 when the well was returned to service after being shut in for low injectivity. The well was brought online to support production. Current wellhead pressure is 452 psig; injection ~ate is 743 bwpd. The LPP and 5SV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure has increased to above 50~ psi and the LPPISSV function is retumed to normal, in accordance with "Administrative Approval No. CO 406B.001". Please let me know if you have any questions. Thanks, Kristen Rutledge Production Engineer, EDP ConocoPhillips Alaska, Inc Phone: (907) 659-7493 9/15/2008 ~~~I~~~f~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 09/05/08 ~~, `," a., f x ~ ' 3 ''"" ~rr ~.e ~ t . ~ ~' U 2#~.i+i+"% , 1,-: NO. 4861 , ~ . ;. Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Beluga River Unit ~ Well Job # Log Description Date BL Color CD ~ J~ 1~~ ~~~~~- ~ ~ iJ-127 12096529 INJECTION PROFILE ~ • ~- 08/i4/08 1 1 1R-11 12096530 PRODUCTION PROFILE 08/15/08 1 1 1J-118 12066541 MEM INJECTION PROFILE 08/17/08 1 1 iJ-122 12066542 MEM INJECTION PROFILE . / (~ OS/18/08 1 1 2D-09 11978477 PRODUCTION PROFILE ~-[_ (p 08/18/08 1 1 2B-14 119966275 PRODUCTION PROFILE L( - ~ ~p 08/19/OS 1 1 iJ-105 12066543 MEM INJECTION PROFILE o1p~- I(p 08/19/08 1 1 2E-12 11996653 SBHPSURVEY C~$t-(-• 08/21/08 1 1 iJ-156 12080419 INJECTION PROFILE 08/21/08 1 1 1A-26 12080420 SBHP SURVEY ~Q -f OS/22/08 1 1 1A-23 12080421 SBHP SURVEY ~ ` 08/22/08 1 1 2D-05 12080422 INJ PROF/LDL ~ - ,((p - 08/23/08 1 1 1H-11 12080423 PRODUCTION PROFILE 08/24/08 1 1 26-03A 11996656 PRODUCTION PROFILE f 08/24/08 1 1 3C-17 11996658 PERF/SBHP SURVEY ~ p~- ~(D l 08/26/OS 1 1 2M-11 12080427 PRODUCTION PROFILE /~- ~ $'Q 08/28/08 1 1 1Y-21 11996662 PRODUCTION PROFILE '~ O~ ~~q 08/30/08 1 1 2E-13 12080431 SBHP SURVEY ~- G 08/31/08 1 1 2E-14 f208Q432 SBHP SURVEY c.(.- 08/31/08 1 1 1B-13 11996664 PRODUCTION PROFILE ~ 09/01/08 1 1 1H-18 11996666 INJECTION PROFILE - ~/ 09/03/08 1 1 F-10 11996660 PLUG SEITING RECORD 08/28/OS 1 1 1 G-05 11996665 PACKER SETTING RECORD 09/02/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . ~ • ~ ConoCa-Ph~ll~ps May 13, 2008 T. Maunder State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Additional Well Summaries Dear Mr. Maunder: • J. Eggemeyer Engineering Leader Drilling & Wells ,,.~'~S &..r°~C~ ~ v~ ~v~ P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 ~ ~ ~ 0 ~ ~ ~,~ ~ D ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ o ~ ~ ~ ~ ~ ~~ ~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 1A-01, CD4-07, 1J-122, 1J-122L1, 1J-122L2, CD4-322, 1J-162, 1J-162L1 you requested. These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, '~. ~~..,.~~..«-~__._- . Eggemeyer / Engineering Team Leader CPAI Drilling J E/skad 1 J-122, i J-164, 1 J-176 LPP's ~k in service ~ Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Wednesday, March 26, 2008 11:24 AM To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; NSK West Sak Prod Engr; Rodgers, James T Subject: 1J-122, 1J-164, 1J-176 LPP's back in service Tom/Jim, Page 1 of 1 We got behind with reporting the following low pressure pilots (LPP) defeat status changes. The LPP on the following wells were returned to senrice on the indicated dates after injection pressures increased to above 500 psi. ~+ '., ~ .: ;~;~07-071, 207-072). Returned to service 3/12/08. Current injection rate/pressure: 1317 bwpd @ 550 psi. 1J-164 (PTD 205-144, 205-145, 205-146). Returned to service 2/28/08. Current injection rate/pressure: 865 bwpd @ 588 psi. 1J-176 (PTD 207-099, 207-100). Returned to service. Current injection rate/pressure: 1731 bwpd @ 647 psi. This note is in reference to "Administrative Approval No. CO 406B.001." Please iet me know if you have any questions. Regards, Hai Hai Hunt / Eric Hollar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com 3/26/2008 Kuparuk River Unit MITIAs ~ ~ Page 1 of 1 Regg, James B (DOA~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, March 01, 2008 10:34 AM ~~~j ~~` ~` ~~ c. To: Regg, James B(DOA); Maunder, Thomas E(DOA); Fleckenstein, Robert J(DOA); DOA AOGCC Prudhoe Bay Subject: Kuparuk River Unit MITIAs Attachments: MIT KRU 1J-122 02-29-08.x1s; MIT KRU 3K-22A 02-29-08.x1s; MIT KRU 1J-176 02-29-08.xis «MIT KRU 1J-122 02-29-08.x1s» «MIT KRU 3K-22A 02-29-08.x1s» «MIT KRU 1J-176 02-29-08.x1s» All, Attached for your records are the MITIAs conducted on 2/29/08: Please contact myself or Brent Rogers if you have any questions or comments. Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. 907-659-7224 3/3/2008 ~ p°~-~~ ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: .3~~3~D~ ConocoPhillips Alaska Inc 1 %~~~ Kuparuk/ KRU / 1J 02/29/08 Greenwood / Johnson waived by Bob Noble Packer Depth Pretest Initial 15 Min. 30 Min. Well 1J-122 Type In~. W TVD 3,684' Tubing 300 300 300 300 Interval I P.T.D. 2070700 Typetest P Test si 1500 Casin 1,700 3,000 3,000 3,000 P/F P Notes: OA 160 160 160 160 Well T pe Inj. TVD Tubing Interval P.T.D. T e test Test si Casing P/F Notes: OA Well T e In'. TVD Tubin Interval P.T.D. T etest Test si Casing P!F Notes: OA Well Type In'. TVD Tubin Interval P.T.D. T petest Test si Casin P/F Notes: OA Well Ty e In~. TVD Tubin Interval P.T.D. Type test Test si Casing P/F Notes: OA TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R= Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test / INTERVAL Codes I = ~nitial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form BFL 11l27l07 MIT KRU 1J-122 02-29-O8.xis ~ ~ ~~~~i'~9~~ STATE OF ALASKA ~E~ '~ ~ Z~1U~ ALASKA OIL AND GAS CONSERVATION COMMISSION , REPORT OF SUNDRY WELL OPERATf~I~~'~ ~~~~ ~~~~° ~""~~~~~~~ 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ er Q Pre-Prod to Inj ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COr1oCOPhillipS Alaska, InC. Development ^ Exploratory ~ 207-070 . 3. Address: Stratigraphic ^ Service ~^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23359-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 109'. 1 J-122 • 8. Property Designation: 10. Field/Pool(s): ALK 25661 ~& 25650 Kuparuk River Field / West Sak Oil Pool ~ 11. Present Well Condition Summary: Total Depth measured 15109' ' feet true vertical 3961' ~ feet Plugs (measured) Effective Depth measured 14616' feet Junk (measured) true vertical 3970' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 80' 80' SURFACE 3531' 13-3/8" 3640' 2212' B-SAND WINDO\ 1' 9-5/8" 10333' 3690' D-SAND WINDO~ 1' 9-5/8" 10828' 3765' INTERMEDIATE 11819' 9-5/8" 11928' 3961' A-SAND SLOTTED LINER 7.5" rJ3~ 7~~ 11023' 3796~ Perforation depth: Measured depth: Slotted (iner 11944' - 14530' true vertical depth: 3932' - 3972' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 10299 ' MD. Packers & SSSV (type & measured depth) PKR = Baker HRD ZXP LT PKR = 10451' SSSV= NIP SSSV= 509' 12. Stimulation or cement squeeze summary: ~~~~ ~,,,~.~k ~, ~ ~ Ct: ~ k~. ~., ~3 ` , Intervals treated (measured) `lV . 1 a _ V1 ,;}~i~'~ h.rv ~.~ f-~ ~ ~ ~ Treatment descriptions including volumes used and final pressure: )J ~~ ~~-+~+-~y ~~„~ '~~l`'S 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1119 511 60 1000 208 Subsequent to operation 2217 ~ 1569 146 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. exempt: 307-315 Contact Bob Christensen / Bob Buchholz Printed Name Robert W. Buchholz Title Production Engineering Technician Signature ~r~ ,~~~ P one 659-7535 Date Z ~ ~ / Z l~ ~~~,y , ~ ~.Z?.o$ ~~~~,~~n~! ~~~ ~ ~ t; ~ ~ ~~Q~ j~ ~ ~ ~ ;~ Form 10-404 Revised 04/2004 ~ Submit O~(~t~7~~ ~ ~ 1 J-122 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/12/08 Commenced Water Injection LPP/SSV defeated on 1J-122 • ~ Maunder, Thomas E (DOA) From: NSK West Sak Prod Engr [n1638@conocophillips.com] Sent: Tuesday, February 19, 2008 4:23 PM To: Maunder, Thomas E (DOA) Subject: RE: LPP/SSV defeated on 1J-122 Page 1 of 2 Tom, You are correct. Our records show that the well was online from 10/26/07 to 12/11/07 (46 producing days). I went off our targeted production period instead of our actual production period. Thanks, Hai Hai Hunt / Eric Haliar NSK West Sak Production Engineer ConocoPhillips Alaska, inc. Phone: (907) 659-7061 Fax: (907) 659-7749 Email: n1638@ConocoPhillips.com From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 19, 2008 1:16 PM Ta: Hunt, Hai L Subject: RE: LPP/SSV defeated on 1J-122 Hai, I received your message regarding the defeated pilot. When I checked the available production information, it appears that the well was produced for 6 days in October, 29 days in November and 11 days in December, a little "more" than 1 month. Not meaning to be picky, but does your record agree with mine as to the production days? 1 am not sure if January has been received yet, so I don't know if there was any production in that month. Thanks, - Tom Maunder, PE AOGCC From: Hunt, Hai L [mailto:Hai.L.Hunt@conocophillips.com) Sent: Tuesday, February 19, 2008 12:35 PM To: NSK West Sak Prod Engr; Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPFl Prod Supt; Rodgers, )ames T Subject: LPP/SSV defeated on iJ-122 Tom / Jim, The low pressure pilot (LPP) on 07-071, 207-072) was defeated on 2/19/2008 when injection was initiated afte~ a 1-month long pre-production period. Current wellhead pressure is 424 psi; injection rate is 1744 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." 3/21 /2008 LPPJSSV defeated on 1J-122 ~ ~ Page 1 of 1 ~AAaunder, Thomas E (DOA) From: Hunt, Hai L [Hai.L.Hunt@conocophitlips.com] Sent: Tuesday, February 19, 2008 42:35 PM To: NSK West Sak Prod Engr; Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: CPF1 DS Lead Techs; CPF9 Prad Supt; Rodgers, James T Subject: LPP/SSV defieated on 1J-122 Tam / Jim, The low pressure piiot (I.PP) on; ' ~7-071, 207-072) was defeated on 2/19/2008 when injection was initiated after a 1-month long pre-production period. Current wellhead pressure is 42~4 psi; injection rate is 1744 bwpd. The LPP and SSV have been #agged and their status is recorded in the "Facility Defeated Safeiy Device Log." The AOGCC witi be notifred when the injection pressure has increased to above 5Q{3 psi and the LPPISSV function is retumed to normat, in accordance with "Administrative Approval Na. CO 4t~B_001." Please let me know if you have any questions. Regards, Hai Hunt Hai Hunt ! Eric Hoflar NSK West Sak Production Engineer ConocoPhillips Alaska, Inc. Phone: (9a7) 659-7061 Fax: (907} 659-7749 Email: n1638@ConocoPhillips.com 2/19/2008 • • Maunder, Thomas E (DOA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocophillips.com] Sent: Wednesday, January 30, 2008 8:13 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. I am sure we can accommodate. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, ]anuary 30, 2008 8:07 AM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports Page 1 of 1 Thanks Jerome. These aren't urgently needed. Only other request, is send the reports "single sided". When we get double-sided, we have to shoot additional copies in order to scan. Tom From: Eggemeyer, Jerome C. [mailto:Jerome.C.Eggemeyer@conocophillips.com] Sent: Tuesday, January 29, 2008 10:36 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: Operations Reports thanks tom. As soon as Sharon is able to organize the data it will be sent over (hopefully only a few days depending on other activities). Let us know if it is needed more urgently. jce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, January 29, 2008 4:38 PM To: Eggemeyer, Jerome C. Cc: Allsup-Drake, Sharon K Subject: Operations Reports Jerome and Sharon, Thanks for sending the more detailed operations reports. I have further reviewed the Commission's files regarding 407's submitted since about August and found that more complete reports are needed for a few other wells. The wells are: 1J-162, -162L1 207-080, 207-181 ~,ncy-c~'.~~ i ~ `Z.l~ CD4-322 207-101 L~~ 1 J-122, -122L1, -122L2 207-070, 207-071, 207-072 For the multilateral wells, a complete summary is only needed for the main wellbore with only the specific operations needed for the laterals. Your assistance in making the well records complete is appreciated sundry reports shortly and will send another message if necessary. Tom Maunder, PE AOGCC ~ t~ _ _,~ ~ I will be reviewing the recently submitted Call or message with any questions. 8/18/2009 j) U 4~ r.,~~ ~. ~ P~~ t 4.~~~Af 1~ ~! ~ r f d~ ~i t . . y~ A ~ ~~~~~~~'~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~,;~~~k _; ~ ~4~i1n ~ ~~A~~,t~. ~~~~~- ~ '~NO. 4505~~ ~' ' "'~~ ~= ~ ~ ~ R na ~ r~1F f b ilts9f7~ ~ µ~~~~_~ Company: Alaska Oil 8~ Gas Cons Comm ~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD . Log Description 11 /16/07 3J-16 11850468 INJECTION PROFILE ~ "" 11/02107 1 1J-122 11745241 MEM PROD PROFILE _~-p 11/03/07 1 1G26 11745244 MEM INJECTION PROFILE v '1 11/09107 1 2Z-07 11850476 PRODUCTION PROFILE 11/11/07 1 1Y-01 11839683 INJECTION PROFILE 11115/07 1 1Y-24AL1 11837535 LDL p - 11/15/07 1 ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. •~~ ~ ~ ~~ ~ ~~' ~~ ~ ~~ ~F~'~,.~ ;~~ ~~ ~ ~ z :, ${ ~p *~,~y~p ~ j` k k ~ "~ ~.. Ll ~,._.5 ~~ ty ;~ ~.f f ~ ~is~ ~ ~ ~i ALASSI~ ~u ~D G~S CO1~T5ERQA~`IO1~T CO1r1IIrIISSI011T Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-122 Sundry Number: 307-315 Dear Mr. Christensen: SARAH PALIN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-t433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is recei~ed by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~/ day of October, 2007 ~~~~ ~~ Chairman 1. Type of Request: Abandon Alter casing ^' Repair well ~ Plug Perforations ^ Stimulate ^ Time Extension ~ Chan e a roved ro ram ' g pp p g ^ Pufl Tubing ~ Perfo~ate New Pool ^, Producer to Re-enter Suspended Well ~ Injector 2. Operator Name: 4. Current Weil Class: 5. Permit to Drill Number: ConocoPhillipsAlaska, Inc. Development 0` Exploratory ^ 207-070 ` 3. Address: Stratigraphic ~ Service ~ 6. API Number: P. O. Box 100360; Anchorage, Alaska 99510 50-029-23359-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number. ' where ownersnip or landownership changes Spacing Exception Required? Y2S ^ No ~^ f 1J-122 ` 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ALK 25661 & 25650 ` RKB 109' Kuparuk River Field / West Sak Oil Pool ~ 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15109' ~ 3961' ~ 14616' ~ 3970' ' ' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 80' 80' SURFACE . 3531' _., 13-3/8° 3640' 2212' _. D-SAND WINDOW 1' 9-5/8" 10333' _ 3690' B-SAND WINDOW 1' 9-5/8" 10828' 3765' INTERMEDIATE 11819' 9-5/8" 11928' 393T ASAND SLOTTEDLINER 7.5" ~ . ~. S3~ . ~ . . . . . . . 7~~ ~ ~ . ~ ~ OZ3~ ~ ~ ~ : ~ 379F)~ .. ~~ ~ .. . . . Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size:' Tubing Grade: - Tubing MD (ft): Slotted Liner 11944' - 14530' 3932' - 3972' 4=1/2" L-80 10299' - Packers and SSSV Type: - - - - Packers and SSSV MD (ft) ` PKR = Baker HRD ZXP LT - __ _ PKR = 1045T SSSV= N!P SSSV= 509' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ~ Development ^ Service ~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations Nov. 11, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal ApprovaL Date: WAG ~ GINJ ^ WINJ ~ WDSPL ~ Commission Representative: 18. I fie~eby certify that the foregoing is true and correct to thebest of my knowledge. Contact: Bob Christensen / Bob 8uchhoiz Printed Name RO D. C 1'~ t2nSe11 Title: Production Engineering Technician Signature Phone 659-7535 Date /~ j/ ~ Commission Use Only Sundry Number: Conditions of approval' Notify Commission so that a representative may witness '~ ~ ~ Plug Integrity ~ BOP Test ~ Mechanical Integrity Test ~ Location Clearance ^ Other: ~' ~'~~ ~s.'~c Q ~} ~CF~~~\ ~ t~S ~ \ ~,"~ G~ ~LC"~ S-~ / ~ ~~ ~~ ~ ~~~ ~~~ ~ ~ ~~~~ Subsequent Form Required: 1..~~ L,\ APPROVED BY r ~~~ Approvedby: C MMISSIONER THE COMMISSION /~/ 6 / Date: I Form 10-403 Revised 06/2006 ~.r.l ~~}~,J ~ ~ V'", L p~ /o/l ~~~ ~ ~ . . . . ~ . , . R~ ~ ~i ~.+~ ~ ~ .~~b-I~ ~~: _~~~~x,;~~~ STATE OF ALASKA . _, ~ -~, ( ~ ~ T t~/~'~ ~, ; z ,. ' ALASKA OIL AND GAS CONSERVATION COMMISSION 1~ APPLICATION~~FOR~SUNDRY APPROVAL'~~.~:~. ~ . g~.: ~~ a ~ _t, c~ .~ ~ ._~~.~,~ ~~ ~ ~ ~~ 20 AAC 25.280 ; . , . ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other ~ . Submit in Duplicate io • ~7 •°~ ~ ~ 1 J-122 DESCRIPTION SUMMARY OFPROPOSAL r~ ~ d ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-122. This well has been pre-produced for approximately 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1J-122 will provide pressure support for the West Sak A sands. ' The 13-3/8" Surface casing ( 3640' md / 2212' tvd) was cemented with 1031 sx AS Lite followed by 372 sx LiteCRETE. The 9-5/8" Intermediate casing ( 11928' md / 3931' tvd) was cemented with 920 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand LEM Baker Seal Assemb(y located @ 10451' md / 3705' tvd, Upper B sand HRD ZXP 7" x 9-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 10442' md / 3705' tvd, and an Upper A sand HRD ZXP 7" x 9-5/8" Liner Top Packer located @ 10970' md / 3788' tvd. The top of West Sak D sand was found at 10295' md / 3684' tvd. D sand Lateral window top is located @ 10332' md / 3689' tvd. _ The top of West Sak B sand was found at 10828' md / 3765' tvd. ~ B sand Lateral window top is located @ 10827' md / 3765' tvd. The top of West Sak A sand was found at 11880' md / 3927' tvd. ; s, ! ~ ~ ~ ~ # ~ ~ ~ e : ~ ~ . . . ~ ~ . . .. . ~ . . . ~ . . . .. . pG ~ - ~ . ~ . - . . ~ ~ ~ ~ . .. . . . . . . , . . ~ . ~ . . . . & . . ~ . . . . . .. . . . . . . . . . . . ~ . ~. ~ . . ~ ~ ~ . . . . . . ~ . . . ~ . ~ ~ . . . . . . . . . . . . .. . . . . . .. ~ . ~ . .. . ~ . . . . . . . ~ . . ~ . ~ . ~ ~ . . : ... ~ . ~ ~ 6. . . . . . . . . . . . . k . ~ : .. . . . . . .. .. ~ . . .. . ~ . . ~ . . . . ~ . ~~ . ~. . . .. . . ~~ .. . ~p~~:. . . . . .. . . . . . . ~ . . . . ~ . ~ . . .. .5 ~. ~~ • ~ 1 KRU 1 J-122 ConocoPhillips Alaska, inc. 1 J-122 11944 - 12246 3932 - 3939 WS A2 302 32 7/5/2007 SLOTS Alternating slotted/solid pipe,2.5"x.125", 4 circumferential rows/R 3"centers sta ered 18d 12504 - 12975 3935 - 3945 WS A2 471 32 7/5/2007 SLOTS Alternating slotted/solid pipe,2.5"x.125", 4 circumferential rows/ft 3"centers sta ered 1Sd 13235 -13711 3951 - 3959 WS A2 476 32 7/5/2007 SLOTS Alternating slotted/solid pipe,2.5"x.125", 4 circumferential rows/ft 3"centers sta ered 18d 13969 -14530 3963 - 3971 WS A2 561 32 7/5/2007 SLOTS Alternating slotted/sotid pipe,2.5"x.125", 4 circumferential IVCGO JO/L JLCCVC-V DNl~CRI.MV JLIUIIVV JLCCVC~RUIY VrCIY //JI/GW/ 10275 3680 LOCATOR SEAL ASSEMBLY LOCATOR 3.880 10276 3650 PBR BAKER 190-07 POLISHED BORE RECEPTACLE 3.880 10297 3684 ANCHOR BAKER 800-47 ANCHOR SEAL ASSEMBLY 3.860 ~ ~ WELL LOG TRANSMITTAL u To: State of Alaska October 3, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-122 AK-MW-5034903 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23 3 59-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 y~~~~~~~~~~~ Date~~~ ~' ~ ~~~~ :~#~5~~ °a!~ :~ ~£~S : us`:~. 3~a7i ~;i ~'i5,~'st~°~ ,`~~1C~?vC?~~ Signed: . ~6~-d ~D e53~ ~ ~ • ~r ~c~noCC~~'h~ll~~3s September 14, 2007 P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~,.~~.~~.,, Commissioner ~~~' State of Alaska ~~ p~ f~ ,~, YE Alaska Oil & Gas Conservation Commission ~ 333 West 7t" Avenue Suite 100 ~~~1~~~~ ~~~ ~~~~~ ~,~~.,,~ ~~ ~; ,~ Anchorage, Alaska 99501 ~ ~~ A~sg: ,~y.; t, ~~ ~~~ Subject: Well Completion Reports for 1J-122, 1J-122L1, 1J-122L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak multi-lateral 1J-122, 1J-122L1 and 1J-122L2. If you have any questions regarding this matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, ,!~ ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling • Randy Thomas Kuparuk Drilling Team Leader Drilling 8~ WeAs RT/skad ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~vE~ ~EP 2 5 2007 WELL COMPLETION OR RECOMPLETION REPOF~~~~-~II~~~~ Commissian 1a. Well Status: Oil ^/ Gas Plugged Abandoned ~ Suspended 20AAC 25.105 20AAC 25.11 Q GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No.ofCompletions: 1b. Well Class: ~G =~'~~~~ Development a~ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ or,4band.: July 31, 2007 12. Permit to Drill Number: 207-070 / J 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: June 17, 2007 ' 13. API Number: S0-029-23359-00 ' 4a. Location of Well (Governmental Section): Surface: 1837' FSL, 2347' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: July4, 2007 Y 14. Well Name and Number: 1J-122 - Top of Productive Horizon: 612' FNL, 339' FEL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): 28' RKB Ground (ft MSL): 109' AMSL ~ 15. FieldlPool(s): Kuparuk River Field Total Depth: 2616' FSL, 371' FEL, Sec. 25, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): i 14616' MD / 3969' ND ` West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558863 ' y- 5945649 ~ Zone- 4 10. Total Depth (MD +~/D): i15109' MD / 3961' ND ~ 16. Property Designation: ALK 25661 & 25650 ` TPI: x- 566126 y- 5948541 Zone- 4 Total Depth: x- 566065 ~ - 5951768 ~ Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 509' MD / 508' TVD 17. Land Use Permit: 471 & 468 18. Directional Survey: Yes Q No ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2196' ND ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES, USIT 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE Wf. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 28' 106' 28' 106' 42" 335 sx AS 1 13.375" 68# L-80 28' 3640' 28' 2211' 16" 1031 sx AS Lite, 372 sx LiteCRETE 9.625" 40# L-80 28' 11928' 28' 3931' 12.25" 92o sx DeepCRETE 7" x 5.5" 15.5# L-80 10970' 14616' 3785' 3969' 8.5" slotted liner 23. Open to production or injection? Yes No ~ • If Yes, iist each 24. TUBING RECORD Interval open (MD+TND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 10304' 1 os7o', 14542' slotted and blank liner from 11032' - 14616' MD ~ 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNTAND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production waiting on facility hook-up Method of Operation (Flowing, gas lift, etc.) multi-lateral, pre-produced injector Date of Test Hours Tested Production for Test Period --> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIo Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - API (corr) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~/ If Yes to either question, list formations and intervals cored (MD+ND 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. ~ Gii~:~`,t.~:C~ui'tYR ~ ~~.CAT%b NONE ' ! ~ ~~ 4..~-.~* Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE - . ~ ~~~: ~ C a ~ ~ 20D7 ~- ti~ 1'-~ /~ ~; ~'O~ ORiGINAL ,~q~ o ~ ~~ ~ 28. GEOIOGIC MARKERS (List all formations and mar rs encountered): 29. FORMATION TESTS NAME MD ND Well tested? ^ Yes ~/ No If yes, list intervals and formations tested, Permafrost - Top ground surfaCe ground surfaCe briefly summarizing test results. Attach separate sheets to this form, if PermafrOSt - Bottom 3595' 2196' , needed, and submit detailed test information per 20 AAC 25.071. T3 3595' 2196' K15 3595' 2196' Ugnu C 7277' 3052' Ugnu B 8484' 3313' Ungu A gg7g~ 3413' K13 9477' 3516' West Sak D 10295' 3684' West Sak B 10828' 3765' West Sak A2 11880' 3927' N/A '1 J-122P61 TD 4086' ~ 2350' Formation at total depth: West Sak A2 ' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner, cement detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Pat Reilly @ 265-6048 Printed Nam Rand Thomas Title: Drillina Team Leader c~ ! ~~'~'- l ~ ~ y{ ~ ~ Signature .~. Phone ~S- ~ g 3 ~ Date INSTRUCTIONS Sharon Allsup-Drake 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). ltem 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 ND 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 2/2007 ~ Halliburton Company ~ ~ Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:20;21 Page: 1 Field: Kuparuk River Unit Co-orcl~nate(NE) Reference: Well: 1J-122, TrueNorth . Site: Kuparuk 1 J Pad Vertical (TVD) Reference: D141 (28 + 81) 109A Well: tJ-122 Section (VS) Reference: Well (O.OON,O.OOE,O:OOAzi) Wellpath: 1 J-122 Survey Calculation Method: Minimum Curvature ~ Db: Oracle i Field: Kuparuk River Unit j North Slope Alaska United States I Map System:US State Plane Coordinate Syste m 1927 Map Zone: PJaska, Zone 4 ~ Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 , Well: 1J-122 SlotName: Well Position: +N/-S -270.75 ft Northing: 5945649.48 ft Latitude: 70 ~5 43.595 N +E/-W 71.32 ft Easti ng : 558863.37 ft Loagitude: 149 31 26.931 W Position Uncertainty: 0.00 ft Wellpath: 1J-122 Drilled From: 1J-122PB1 ~ API 50-029-23359-00 Tie-on Depth: 3615.17 ft Current Datum: D141 (28 + 81) Height 109.00 ft~ Above System Datum: Mean Sea Level Magnetic Data: 6/16/2007 Declination: 23.31 deg Field Strength: 57613 nT Mag Dip Angl e: 80J9 deg Vertical Section: Depth From (TVD) +N/-S +E/-W IDirection ft ft ft deg 28.00 0.00 0.00 0.00 Survey Program for Definitive Wellpath Date: 6/26/2007 Validated: Yes Version: 6 Actual From To Survey Toolcode Tool Ptame ft ft 50.00 727.00 1J-122 P61 Gyros (50.00-727.00 CB-GYRO-SS Camera based gyro single shot 826.02 3615.17 1J-122 PB1 IIFR+MS+Sag (826.02 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 3643.00 15077.80 1J-122 IIFR+MS+Sag (3643.00-15 MWD+IFR-AK-CAZ-SC MWD~IFR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S FJW MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945649.48 558863.37 T{E LINE ~' S0.00 0.23 ~ 262.51 50.00 -59.00 -0.01 -0.04 5945649.47 558863.33 CB-GYRO-SS 100.00 0.23 207.19 100.00 -9.00 -0:11 -0.19 5945649.37 558863.18 CB-GYRd-SS 168.00 0.10 64.84 168.00 59.00 -0.20 -0.20 5945649.27 558863.17 CB-GYRO-SS 263.00 0.20 43.45 263.00 154.00 -0.05 -0.01 5945649.43 558863.36 CB-GYRO-SS 352.00 2.00 104.21 351.98 242.98 -0.32 1.60 5945649.18 558864.98 CB-GYRO-SS 445.00 5.77 102.92 444.75 335.75 -1.76 7.74 5945647.78 558871.12 CB-GYRO-SS 476.00 6.94 104.70 475.56 366.56 -2.59 11.07 5945646.98 558874.46 CB-GYRO-SS 536.00 8.40 109.85 535.02 426.02 -4.99 18.70 5945644.63 558882.10 CB-GYRO-SS I 631.00 12.22 111.49 628.47 519.47 -11.03 34.58 5945638.72 558898.03 CB-GYRO-SS 727.00 16.18 110.43 721.52 612.52 -19.43 56.58 5945630.50 558920.09 CB-GYRO-SS 826.02 19.43 110.75 815.78 706.78 -30.08 84.92 5945620.06 558948.51 MWD+IFR-AK-CAZ-SC 897.82 21.80 107.95 882.98 773.98 -38.42 10877 5945611.9'1 558972.43 MWD+IFR-AK-CAZ-SC 957.57 24.53 106.48 937.91 828.91 -45.36 '631.22 5945605.15 558994.93 MWD+IFR-AK-CAZ-SC 1053.34 29.27 105.77 1023.29 914.29 -57.37 172.84 5945593.47 559036.64 MWD+IFR-AK-CAZ-SC 1148.67 32.87 106.08 1104.93 995.93 -70.88 220.14 5945580.33 559084.04 MWD+IFR-AK-CAZ-SC 1244.03 37.37 106.69 1182.91 1073.91 -86.36 272.76 5945565.26 559136.77 MWD+IFR-AK-CAZ-SC 1337.57 39.44 104.20 1256.22 1147.22 -101.81 328.76 5945550.26 559192.89 MWD+IFR-AK-CAZ-SC 1432.05 44.32 102.32 1326.54 1217.54 -116.22 390.14 5945536.32 559254.37 MWD+IFR-AK-CAZ-SC 1525.77 47.35 102.29 1391.83 1282.83 -130.55 455.82 5945522.51 559320.15 MWD+IFR-AK-CAZ-SC I j 1619.34 48.76 100.81 1454.38 1345.38 -144.47 524.00 5945509.12 559388.43 MWD+IFR-AK-CAZ-SC I 1714.14 49.71 100.26 1516.28 1407.28 -157.59 594.59 5945496.55 559459.12 MWD+IFR-AK-CAZ-SC 1809.00 55.41 100.64 1573.92 1464.92 -171.26 668.63 5945483.47 559533.25 MWD+~FR-AK-CAZ-SC 1904.38 58.52 99.98 1625.91 1516.91 -185.56 747.29 5945469.78 559612.01 MWD+IFR-AK-CAZ-SC 1998.16 64.25 99.90 1670.81 1561.81 -199.76 828.34 5945456.22 559693.17 MWD+IFR-AK-CAZ-SC 2092.66 67.25 101.49 1709.62 1600.62 -215.76 912.99 5945440.88 559777.93 MWD+IFR-AK-CAZ-SC 2187.56 70.00 101.39 1744.20 1635.20 -233.29 999.60 5945424.03 55986A.67 MWD+IFR-AI~-CAZ-SC 2282.44 71.24 100.27 1775.69 1666.69 -250.10 1087.51 5945407.91 559952.69 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report CJ Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:20:21 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: iJ-122, 7rue ~h Site: Kuparuk 1 J Pad Verti cal (TVD) Reference: D141 (28 + 81 ) 4f?~.~ Well: 1J -122 Section (VS) Reference: Well {O.OON,O. OO~;O:OOAzi) Weilpath: TJ-122 Survey Calculation Method: Minimum CurvaturE Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool i ft deg deg ft ft ft ft ft ft ~ 2377.66 72 .77 100.85 1805.10 1696.10 -266 .70 1176.53 5945392.01 560041.84 MWD+IFR-AK-CAZ-SC i 2475.50 72 .64 901.61 1834.19 1725.19 -284 .89 1268.16 5945374.53 560133.59 MWD+IFR-AK-CAZ-SC 2571.86 70 .40 100.87 1864.73 1755.73 -302 .71 1357.79 5945357.42 560223.35 MWD+IFR-AK-CAZ-SC 2665.79 70 .32 99.86 1896.30 1787.30 -318 .63 1444.81 5945342.19 560310.49 MWD+IFR-AK-CAZ-SC 2760.94 71 .66 100.55 1927.30 1818.30 -334 .57 1533.34 5945326.94 560399.14 MWD+IFR-AK-CAZ-SC 2856.71 71 .49 100.03 1957.56 1848.56 -350 .80 1622.74 5945311.41 560488.65 MWD+IFR-AK-CAZ-SC 2952.84 71 .26 98.74 1988.27 1879.27 -365 .65 1712.62 5945297.26 560578.63 MWD+IFR-AK-CAZ-SC 3048.06 71. 85 98.09 2018.39 1909.39 -378 .87 1801.97 5945284.74 560668.07 MWD+IFR-AK-CAZ-SC 3141.34 71. 49 98.07 2047.73 1938.73 -391 .32 1889.64 5945272.98 560755.83 MWD+IFR-AK-CAZ-SC 3236.18 70. 84 98.20 2078.35 1969.35 -404 .02 1978.50 5945260.98 560844.77 MWD+IFR-AK-CAZ-SC 3331.73 73. 51 98.65 2107.59 1998.59 -417 .35 2068.47 5945248.35 560934.84 MWD+IFR-AK-CAZ-SC 3425.95 72. 56 98.11 2135.09 2026.09 -430 .48 2157.63 5945235.92 561024.09 MWD+IFR-AK-CAZ-SC 3518.01 67. 02 98.46 2166.88 2057.88 -442 .92 2243.08 5945224.15 561109.63 MWD+IFR-AK-CAZ-SC 3615.17 69. 19 100.33 2203.11 2094.11 -457 .65 2332.01 5945210.12 561198.67 MWD+IFR-AK-CAZ-SC 3643.00 69. 41 100.69 2212.95 2103.95 -462 .40 2357.61 5945205.57 561224.30 MWD+IFR-AK-CAZ-SC ~ 3711.25 70. 62 97.13 2236.28 2127.28 -472 .32 2420.96 5945196.14 561287.72 MWD+IFR-AK-CAZ-SC ~ 3806.75 71. 61 99.08 2267.19 2158.19 -485 .06 2510.41 5945184.10 561377.26 MWD+~FR-AK-CAZ-SC 3900.55 72. 85 98.63 2295.82 2186.82 -498 .81 2598.67 5945171.04 561465.61 MWD+IFR-AK-CAZ-SC 3995.33 73. 42 100.00 2323.32 2214.32 -513 .49' 2688.18 5945157.06 561555.22 MWD+IFR-AK-CAZ-SC 4089.15 75. 47 100.58 2348.48 2239.48 -529 .64 2777.10 5945141.61 561644.26 MWD+IFR-AK-CAZ-SC 4186.11 75. 66 100.44 2372.65 2263.65 -546 .77 2869.42 5945125.21 561736.71 MWD+IFR-AK-CAZ-SC 4281.20 74. 77 100.77 2396.91 2287.91 -563 .69 2959.80 5945109.00 561827.20 MWD+IFR-AK-CAZ-SC 4376.04 77. 20 100.45 2419.88 2310.88 -580 .63 3050.23 5945092.77 561917.75 MWD+IFR-AK-CAZ-SC I 4470.83 75. 54 98.97 2442.22 2333.22 -596. 17 3141.03 5945077.94 562008.66 MWD+IFR-AK-CAZ-SC 4565.83 76. 29 99.56 2465.34 2356.34 -611. 00 3231.97 5945063.82 562099.70 MWD+IFR-AK-CAZ-SC 4662.92 77. 76 99.94 2487.13 2378.13 -627. 03 3325.21 5945048.52 562193.06 MWD+~FR-AK-CAZ-SC i 4755.99 78. 07 99.33 2506:62 2397.62 -642. 26 3414.93 5945034.00 562282.89 MWD+IFR-AK-CAZ-SC 4850.72 78. 01 99.19 2526.25 2417.25 -657. 17 3506.40 5945019.80 562374.46 MWD+IFR-AK-CAZ-SC 4945.03 76. 49 99.07 2547.06 2438.06 -671. 77 3597.21 5945005.92 562465.38 MWD+IFR-AK-CAZ-SC 5039.28 77. 69 99.78 2568.12 2459.12 -686. 81 3687.84 5944991.58 562556.11 MWD+IFR-AK-CAZ-SC 5133.03 77. 50 100.50 2588.26 2479.26 -702. 93 3777.97 5944976.17 562646.36 MWD+IFR-AK-CAZ-SC 5228.34 77. 31 100.14 2609.0 2500.04 -719. 59 3869.48 5944960.22 562737.99 MWD+IFR-AK-CAZ-SC 5323.79 77. 12 100.17 2630.1 2521.17 -736. 01 3961.11 5944944.53 562829.73 MWD+IFR-AK-CAZ-SC 5419.10 77. 76 100.67 2650.8 2541.89 -752. 83 4052.60 5944928.42 562921.34 MWD+IFR-AK-CAZ-SC 5513.28 79. 33 100.60 2669.6 2560.60 -769. 87 4143.32 5944912.10 563012.18 MWD+IFR-AK-CAZ-SC 5608.22 78. 07 100.00 2688.2 2579.20 -786. 51 4234.91 5944896.17 563103.89 MWD+IFR-AK-CAZ-SC 5702.95 78. 26 100.39 2707.6 2598.63 -802. 92 4326.16 5944880.47 563195.26 MWD+IFR-AK-CAZ-SC 5798.24 79. 07 100.44 2726.3 2617.36 -819. 81 4418.06 5944864.30 563287.27 MWD+IFR-AK-CAZ-SC 5894.04 77. 56 99.92 2745.7 2636.76 -836. 40 4510.39 5944848.45 563379.73 MWD+IFR-AK-CAZ-SC 5988.48 77. 94 99.90 2765.8 2656.80 -852. 28 4601.30 5944833.28 563470.75 MWD+IFR-AK-CAZ-SC 6083.44 76. 86 99.56 2786.5 2677.51 -867. 94 4692.64 5944818.33 563562.20 MWD+IFR-AK-CAZ-SC 6178.39 77. 37 99.58 2807.6 2698.68 -883. 33 4783.91 5944803.66 563653.58 MWD+IFR-AK-CAZ-SC 6273.69 76. 93 98.90 2828.8 2719.88 -898. 25 4875.62 5944789.46 563745.39 MWD+IFR-AK-CAZ-SC 6369.18 76. 74 99.57 2850.6 2741.63 -913. 17 4967.39 5944775.25 563837.27 MWD+IFR-AK-CAZ-SC 6466.04 75. 60 99.00 2873.7 2764.78 -928. 35 5060.21 5944760.80 563930.20 MWD+IFR-AK-CAZ-SC 65&1.04 76. 42 99.45 2896.7 2787.75 -943. 12 5151.20 5944746.74 564021.29 MWD+IFR-AK-CAZ-SC 6655.80 76. 80 98.13 2918.6 2809.69 -957. 21 5242.30 5944733.37 564112.49 MWD+IFR-AK-CAZ-SC 6749.05 76. 67 96.13 2940.0 2831.09 -968. 48 5332.35 5944722.81 564202.62 MWD+IFR-AK-CAZ-SC 6844.64 77. 25 94.88 2961.6 2852.66 -977. 41 5425.05 5944714.60 564295.37 MWD+IFR-AK-CAZ-SC 6940.21 78. 13 92.82 2982.0 2873.04 -983. 67 5518.20 5944709.06 564388.56 MWD+IFR-AK-CAZ-SC 7034.44 78. 07 89.87 3001.4 2892.47 -985. 84 5610.37 5944707.62 564480.74 MWD+IFR-AK-CAZ-SC 7130.45 78. 32 86.51 3021.i 2912.12 -982. 87 5704.29 5944711.32 564574.62 MWD+IFR-AK-CAZ-SC i I ~ ~ I~alliburton Company Survey Report Company: ConocoPhillips Alaska lnc. Date: 8/16/2007 Time: 09:20:21 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-122, True North Site: Kuparuk 1 J Pad Vertical (TVD) Reference: D441 (28 + 81) 109:0 We1L• 1 J -122 Section (VS) Reference: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J -122 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ( ft deg deg ft ft ft ft ft ft ! 7223.85 77.94 83.36 3040 .34 2931 .34 -974 .80 5795.32 5944720.10 564665.58 MWD+IFR-AK-CAZ-SC ; 7321.06 77.50 79.87 3061 .02 2952 .02 -960 .96 5889.28 5944734.68 564759.41 MWD+IFR-AK-CAZ-SC 7416.89 77.93 76.88 3081 .41 2972 .41 -942 .09 5980.98 5944754.26 564850.96 MWD+IFR-AK-CAZ-SC ~ 7509.94 77.87 73.24 3100 .92 2991 .92 -918 .64 6068.87 b944778.40 564938.65 MWD+IFR-AK-CAZ-SC 7606.20 77.55 69.61 3121 .42 3012 .42 -888 .68 6158.01 5944809.04 565027.55 MWD+IFR-AK-CAZ-SC 7701.51 77.50 66.04 3142 .01 3033 .01 -853 .57 6244.17 5944844.83 565113.42 MWD+iFR-AK-CAZ-SC 7797.32 77.25 63.06 3162 .96 3053 .96 -813 .40 6328.58 5944885.66 565197.51 MWD+IFR-AK-CAZ-SC 7890.97 77.43 59.93 3183 .49 3074 .49 -769 .79 6408.87 5944929.88 565277.44 MWD+IFR-AK-CAZ-SC 7989.13 77.82 56.45 3204 .53 3095 .53 -719 .26 6490.33 5944981.04 565358.50 MWD+IFR-AK-CAZ-SC I 8082.76 77.12 53.16 3224 .85 3115 .85 -666 .59 6565.01 594503429 565432.76 MWD+IFR-AK-CAZ-SC ~ i 8177.99 77.25 50.55 3245 .98 3136 .98 -609 .25 6638.03 5945092.20 565505.33 MWD+IFR-AK-CAZ-SC 8273.83 77.24 47.56 3267 .14 3158. 14 -548 .00 6708.63 5945153.99 565575.43 MWD+IFR-AK-CAZ-SC 8368.99 77.43 44.89 3288 .01 3179 .01 -483 .77 6775.66 5945218.73 565641.96 MWD+IFR-AK-CAZ-SC 8464.35 77.75 41.57 3308 .51 3199 .51 -415 .92 6839.44 5945287.07 565705.20 MWD+IFR-AK-CAZ-SC 8560.45 78.45 37.68 3328 .33 3219. 33 -343 .51 6899.40 5945359.95 565764.58 MWD+IFR-AK-CAZ-SC 8652.81 77.75 35.21 3347 .38 3238 .38 -270 .81 6953.08 5945433.05 565817.69 MWD+IFR-AK-CAZ-SC 8747.98 77.87 32.75 3367 .48 3258 .48 -193 .68 7005.07 5945510.58 565869.06 MWD+IFR-AK-CAZ-SC 8843.49 79.27 30.23 3386 .41 3277 .41 -113 .86 7053.96 5945590.77 565917.32 MWD+IFR-AK-CAZ-SC 8939.65 78.38 26.23 3405 .05 3296. 05 -30 .76 7098.57 5945674.21 565961.29 MWD+IFR-AK-CAZ-SC 9033.80 77.49 23.05 3424 .73 3315. 73 52 .91 7136.96 5945758.17 565999.01 MWD+IFR-AK-CAZ-SC 9129.64 78.20 19.80 3444 .92 3335. 92 140 .11 7171.17 5945845.63 566032.54 MWD+IFR-AK-CAZ-SC 9224.85 78.38 17.20 3464 .25 3355. 25 228 .52 7200.75 5945934.25 566061.42 MWD+IFR-AK-CAZ-SC 9318.79 78.14 13.57 3483 .37 3374. 37 317 .18 7225.15 5946023.10 566085.13 MWD+IFR-AK-CAZ-SC 9413.15 78.01 9.58 3502 .87 3393. 87 407 .61 7243.67 5946113.65 566102.94 MWD+IFR-AK-CAZ-SC 9509.96 78.38 6.02 3522. 68 3413. 68 501 .47 7256.53 5946207.61 566'115.06 MWD+IFR-AK-CAZ-SC 9605.12 77.37 2.87 3542. 68 3433. 68 594 .22 7263.74 5946300.40 566121.55 MWD+IFR-AK-CAZ-SC 9693.66 77.62 2.17 3561. 85 3452. 85 680 .57 7267.54 5946386.77 566124.67 MWD+IFR-AK-CAZ-SC 9788.92 78.01 0.53 3581. 95 3472. 95 773 .66 7269.73 5946479.86 566126.14 MWD+IFR-AK-CAZ-SC 9884.64 77.68 359.63 3602. 11 3493. 11 867 .23 7269.87 5946573.43 566125.54 MWD+IFR-AK-CAZ-SC 9980.13 77.75 359.26 3622. 43 3513. 43 960 .53 7268.96 5946666.71 566123.90 MWD+IFR-AK-CAZ-SC 10074.62 78.13 0.05 3642. 17 3533. 17 1052. 93 7268.41 5946759.09 566122.63 MWD+IFR-AK-CAZ-SC 10169.85 78.76 359.38 3661. 25 3552. 25 1146 .23 7267.94 5946852.37 566121.43 MWD+IFR-AK-CAZ-SC 10263.66 80.15 358.75 3678. 41 3569. 41 1238. 44 7266.44 5946944.56 566119.21 MWD+IFR-AK-CAZ-SC 10360.86 81.71 359.21 3693. 74 3584. 74 1334 .41 7264.73 5947040.50 566116.75 MWD+IFR-AK-CAZ-SC 10455.06 81.96 359.79 3707. 11 3598. 11 1427 .65 7263.91 5947133.72 566115.21 MWD+IFR-AK-CAZ-SC I 10551.25 81.40 0.11 3721. 03 3612. 03 1522 .82 7263.83 5947228.89 566114.38 MWD+IFR-AK-CAZ-SC 10645.91 81.20 0.07 3735. 35 3626. 35 4616. 39 7263.98 5947322.45 566113.79 MWD+IFR-AK-CAZ-SC 1074125 80.39 359.98 3750. 60 3641. 60 1710. 51 7264.02 5947416.55 566113.10 MWD+IFR-AK-CAZ-SC 10835.93 80.52 0.78 3766. 30 3657. 30 1803. 87 7264.64 5947509.91 566112.99 MWD+IFR-AK-CAZ-SC 10929.35 81.02 1.00 3781. 29 3672. 29 1896. 07 7266.07 5947602.11 566113.70 MWD+IFR-AK-CAZ-SC 11024.13 80.84 0.27 3796. 23 3687. 23 1989. 66 7267.11 5947695.69 566114.01 MWD+IFR-AK-CAZ-SC 11119.04 80.51 1.45 3811. 61 3702. 61 2083. 30 7268.51 5947789.33 566114.68 MWD+IFR-AK-CAZ-SC 11214.94 80.59 0.83 3827. 35 3718. 35 2177. 88 7270.40 5947883.92 566115.82 MWD+IFR-AK-CAZ-SC 11310.16 80.70 0.77 3842. 83 3733. 83 2271. 83 7271.71 5947977.86 566116.40 MWD+IFR-AK-CAZ-SC 11404.53 80.64 1.13 3858. 13 3749. 13 2364. 94 7273.25 5948070.97 566117.21 MWD+IFR-AK-CAZ-SC 11498.76 80.83 1.25 3873. 30 3764. 30 2457. 92 7275.18 5948163.95 566118.42 MWD+IFR-AK-CAZ-SC 11593.98 80.77 1.61 3888. 53 3779. 53 2551. 88 7277.53 5948257.92 566120.03 MWD+IFR-AK-CAZ-SC 11688.10 80.46 1.51 3903. 87 3794. 87 2644. 71 7280.06 5948350.76 566121.83 MWD+IFR-AK-CAZ-SC 11783.81 83.33 1.89 3917. 37 3808. 37 2739. 41 7282.87 5948445.47 566123.90 MWD+IFR-AK-CAZ-SC 11877.77 84.94 0.90 3926. 97 3817. 97 2832. 85 7285.14 5948538.91 566125.45 MWD+IFR-AK-CAZ-SC 11900.50 85.25 1.02 3928. 91 3819. 91 2855. 49 7285.52 5948561.56 566125.65 MWD+IFR-AK-CAZ-SC 11978.00 87.22 2.11 3934. 00 3825. 00 2932. 79 7287.63 5948638.86 566127.16 MWD+IFR-AK-CAZ-SC 12072.95 88.92 1.32 3937. 20 3828. 20 3027. 64 7290.47 5948733.72 566129.26 MWD+IFR-AK-CAZ-SC ! Halliburton Company Survey Report C~ Company: ConocoPhillips Alaska Inc. Date: 8/16/2007 Time: 09:20:21 Page: 4 Field: Ku paruk River Unit Co-ordinate(NE) Reference: Well; 1J-122, True North Site: Ku paruk 1J Pad Vertical (TVD) R eference: D141 (28 + 81) 109.0 Well: 1J-122 Section (VS) Reference: Well (d.00N,0.00E,0.00Azi) Wellpath: 1J-122 Survey Calculation Method: Minirnum Curvature Db: OraGe Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ft deg deg ft ft ft ft ft ft 12168.71 89.10 359.80 3938 .85 3829.85 3123.38 7291.41 5948829.45 566129.44 MWD+IFR-AK-CAZ-SC 12262.02 91.27 359.51 3938 .55 3829.55 3216.68 7290.85 5948922.74 566128.15 MWD+IFR-AK-CAZ-SC I 12357.71 91.26 359.89 3936 .44 3827.44 3312.34 7290.35 5949018.39 566126.90 MWD+IFR-AK-CAZ-SC 12452.08 90.71 0.45 3934 .82 3825.82 3406.70 7290.63 5949112.73 566126.45 MWD+IFR-AK-CAZ-SC 12546.94 89.66 0.32 3934 .51 3825.51 3501.55 7291.26 5949207.58 566126.34 MWD+IFR-AK-CAZ-SC 12640.37 88.85 357.94 3935 .72 3826.72 3594.96 7289.85 5949300.96 566124.19 MWD+IFR-AK-CAZ-SC 12735.28 88.11 357.90 3938 .24 3829.24 3689.77 7286.40 5949395.74 566120.01 MWD+IFR-AK-CAZ-S~C 12827.88 88.42 358.52 3941 .05 3832.05 3782.28 7283.51 5949488.22 566116.39 MWD+IFR-AK-CAZ-SC 12924.85 88.36 359.14 3943 .77 3834.77 3879.19 7281.53 5949585.10 566113.66 MWD+IFR-AK-CAZ-SC 13020.38 88.67 359.40 3946. 25 3837.25 3974.68 7280.32 5949680.57 566111.70 MWD+IFR-AK-CAZ-SC 13114.92 88.48 359.85 3948. 60 3839.60 4069.19 7279J0 5949775.06 5fi6110.34 MWD+IFR-AK-CAZ-SC 13209.00 88.73 359.62 3950. 89 3841.89 4163.24 7279.26 5949869.10 5fi6109.17 MWD+IFR-AK-CAZ-SC 13303.90 88.79 359.72 3952. 94 3843.94 4258.12 7278.72 5949963.96 566107.88 MWO+IFR-AK-CAZ-SC 13398.20 89.78 359.74 3954. 12 3845.12 4352.41 7278:27 5950058.23 566106.70 MWD+IFR-AK-CAZ-SC 13490.50 89.35 358.76 3954. 82 3845.82 4444.70 7277.06 5950150.50 566104.77 MWD+IFR-AK-CAZ-SC 13583.79 89.16 358.51 3956. 03 3847.03 4537.95 7274.84 5950243.72 566101.82 MWD+IFR-AK-CAZ-SC 13676.30 88.85 359.24 3957. 64 3848.64 4630.43 7273.03 5950336.18 566099.28 MWD+IFR-AK-CAZ-SC 13769.96 88.30 358.71 3959. 97 3850.97 4724.05 7271.35 5950429.77 566096.87 MWD+IFR-AK-CAZ-SC 13861.11 89.10 358.28 3962. 04 3853.04 4815.14 7268.96 5950520.83 566093.77 MWD+IFR-AK-CAZ-SC 13954.22 89.47 359.28 3963. 20 3854.20 4908.22 7266.97 5950613.88 566091.06 MWD+IFR-AK-CAZ-SC 14046.91 89.41 359.10 3964. 10 3855.10 5000.90 7265.66 5950706.54 566089.02 MWD+IFR-AK-CAZ-SC 14138.89 88.36 359.12 3965. 89 3856.89 5092.85 7264.24 5950798.46 566086.88 MWD+IFR-AK-CAZ-SC 14232.78 88.42 358.35 3968. 53 3859.53 5186.68 7262.16 5950892.27 566084.07 MWD+IFR-AK-CAZ-SC 14325.42 87.93 356.70 3971. 48 3862.48 5279.18 7258.17 5950984.73 566079.35 MWD+IFR-AK-CAZ-SG 14417.97 90.41 357.86 3972. 82 3863.82 5371.61 7253.77 5951077.1T 566074.24 MWQ+IFR-AK-CAZ-SC 14510.49 90.77 358.39 3971. 87 3862.87 5464.07 7250.75 5951169.54 566070.49 MWD+IFR-AK-CAZ-SC 14604.09 91.63 0.09 3969. 91 3860.91 5557.64 7249.51 5951263.08 566068.52 MWD+IFR-AK-CAZ-SC 14696.19 90.71 359.94 3968 A3 3859.03 5649.72 7249.,53 5951355.15 566067.82 MWD+IFR-AK-CAZ=SG 14790.16 90.64 0.16 3966. 92 3857.92 5743.68 7249.61 5951449.10 566067.17 MWD+IFR-AK-CAZ-SC 14887.30 91.88 0.24 3964. 79 3855.79 5840.80 7249.95 5951546.21 566066.75 MWD+IFR-AK-CAZ-SC 14982.63 92.25 0.40 3961. 35 3852.35 5936.06 7250.48 5951641.47 566066.54 MWD+IFR-AK-CAZ-S~ 15077.80 88.67 359:16 3960. 59 3851.59 6031.21 7250.12 5951736.60 566065.43 MWD+IFR-AK-CAZ-SC 15109.00 f 88.67 359.16 3961. 31 ' 3852.31 6062.40 7249.66 5951767.78 ` 566064.73~ PROJECTED to TD ~ ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 8/t6/2007 Time: 09:18:45 Page: 1 Field: Kuparuk River Unit Co-ordinate{NE) Reference: Well: 1 J-122, True North Site: Kuparuk1JPad Vertical(TVD)Reference: D1A1(28+81) 109.0' Well: 1J-122 Section (VS) Reference: Well (O.OON,O.O OE,O.OOAzi) Welipath: 1J-122P61 Su rvey ~alculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit ~ North Slope Alaska United States j Map System:US State Plane Coordin ate Syste m 1927 Map Zone: Alaska, Zone 4 ~ Geo Datum: NAD27 (Clarke 1866) Coardinate System: Well Centre I Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 ~ Well: 1 J-122 Slot Name: Well Position: +N/-S -270.75 ft Northing: 5945649.48 ft Latitude: 70 15 43.595 N +E/-W 71.32 ft Easti ng : 558863.37 ft Longitude: 149 31 26.931 W Position Uncertainty: 0.00 ft Welipath: 1 J-122P61 Drilted From: Well Ref. Point API 50-029-23359-70 Tie-on Depth: 28.00 ft Current Datum: D141 (28 + 81) Height 10 9.00 ft Above System Datum: Mean Sea Level Magnetic Data: 6/16/2007 Declination: 23.31 deg Field Strength: 57613 nT Mag Dip Angle; 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/ W Birection ft ft ft deg Zs.oo o.oo o.oo a.oo Survey Program for Definitive Wellpath Date: 6/26/2007 Validated: Yes Version_ 7 Actual From To Survey Toolcode Tooi Name ft ft 50.00 727.00 1J-122 P6 1 Gyros (50.00-727.00. CB-GYRO-SS Camera based gyro single shot 826.02 4044.53 1J-122 PB 1 IIFR+MS+Sag (826.02 M WD+tFR-AK-CAZ-SC MWD+iFR AK CAZ SC C Survey MD Incl Azim TVD Sys TVD N/S ENV MapN MapE Tool ft deg deg ft ft ft ft ft ft 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 5945649.4& 558863.37 TIE LINE 50.00 0.23 262.51 50.00 -59.00 -0.01 -0.04 5945649.47 558863.33 CB-GYRO-SS 100.00 0.23 207.19 100.00 -9.00 -0.11 -0.19 5945649.37 558863.18 CB-GYRO-SS 168.00 0.10 64.84 168.00 59.00 -0.20 -0.20 5945649.27 558863.17 CB-GYRO-SS 263.00 0.20 43.45 263.00 154.00 -0.05 -0.01 5945649.43 558863.36 CB-GYRO-SS 352.00 2.00 104.21 351.98 242.98 -0.32 1.60 5945649.18 558864.98 CB-GYRO-SS 445.00 5.77 102.92 444.75 335.75 -1.76 7.74 5945647.78 558871.12 CB-GYRO-SS 476.00 6.94 104.70 475.56 366.56 -2.59 11.07 5945646.98 558874.46 CB-GYRO-SS 536.00 8.40 109.85 535.02 426.02 ~:99 98.70 5945644.63 558882.10 CB-GYRO-SS 631.00 12.22 111.49 628.47 519.47 -11.03 34.58 5945638.72 558898.03 CB-GYRO-SS 727.00 16.18 110.43 721.52 612.52 -19.43 56.58 5945630.50 558920.09 CB-GYRO-SS 826.02 19.43 110.75 815.78 706.78 v~0.08 84.92 5945620.06 558948.51 MWD+IFR-AK-CAZ-SC 897.82 21.80 107.95 882.98 773.98 -38.42 10877 5945611.91 558972.43 MWD+IFR-AK-CAZ-SC 957.57 24.53 106.48 937.91 828.91 -45.36 131.22 5945605.15 558994.93 MWD+IFR-AK-CAZ-SC 1053.34 29.27 105.77 1023.29 914.29 -57.37 172.84 5945593.47 559036.64 MWD+IFR-AK-CAZ-SC 1148.67 32.87 106.08 1104.93 995.93 -70.88 22D.14 5945580.33 559084.04 MWD+IFf2-AI(-CAZ-SC 1244.03 37.37 106.69 1182.91 1073.91 -$6.36 272.76 5945565.26 559136.77 MWD+IFR-AK-CAZ-SC 1337.57 39.44 104.20 1256.22 1147.22 -101.81 328.76 5945550.26 559192.89 MWD+IFR-AK-CAZ-SC 1432.05 44.32 102.32 1326.54 1217.54 -1t6.22 390.14 5945536.32 559254.37 MWD+IFR-AK-CAZ-SC 1525.77 47.35 102.29 1391.83 1282.83 -130.55 455.82 5945522.51 559320.15 MWD+IFR-AK-CAZ-SC 1619.34 48.76 100.81 1454.38 1345.38 -144.47 524.00 5945509.12 559388.43 MWD+IFR-AK-CAZ-SC 1714.14 49.71 100.26 1516.28 1407.28 -157.59 594.59 5945496.55 559459.12 MWD+IFR-AK-CAZ-SC 1809.00 55.41 100.64 1573.92 1464.92 -171.26 668.63 5945483.47 559533.25 MWD+IFR-AK-CA2-SC 1904.38 58.52 99.98 1625.91 1516.91 -185.56 747.29 5945469.78 559612.01 MWD+IFR-AK-CAZ-SC 1998.16 64.25 99.90 1670.81 1561.81 -199.76 828.34 5945456.22 559693.17 MWD+IFR-AK-CAZ-SC 2092.66 67.25 101.49 1709.62 1600.62 -215.76 912.99 5945440.88 559777.93 MWD+IFR-AK-CAZ-SC 2187.56 70.00 101.39 1744.20 1635.20 -233.29 999.60 5945424.03 559864.67 MWD+IFR-AK-CAZ-SC 2282.44 71.24 100.27 1775.69 1666.69 -250.10 1087.51 5945407.91 559952.69 MWD+IFR-AK-CAZ-SC 2377.66 72.77 100:85 1805.10 1696.10 -266.70 1176.53 5945392.01 560041.84 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report ~ Company: ConocoPhillips Alaska Ina Date: 8/16/2007 Time: 09:18:45 Page; 2 Field: Kuparuk River Uni t Co-ordinate(NE) Reference: Well: 1 J-122, T rue North Site: Kuparuk 1J Pad Vertical (TVD) Reference: D141 (28 + 81) 109.0 Well: 1J -122 Section (VS) Refe rence: Well (O.OON,O.OOE,O.OOAzi) Wellpath: 1J -122P61 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE Tool ~ ft deg deg ft ft ft ft ft ft 2475.50 72.64 101 .61 1834.19, 1725.19 -284. 89 1268 .16 5945374:53 560133.59 MWD+IFR-AK-CAZ-SC ~ 2571.86 70.40 100 .87 1864.73 1755.73 -302. 71 1357 .79 5945357.42 560223.35 MWD+IFR-AK-CAZ-SC ~ 2665.79 70.32 99 .86 1896.30 1787.30 -318. 63 1444. 81 5945342.19 560310.49 MWD+IFR-AK-CAZ-SC i 2760.94 71.66 100 .55 1927.30 1818.30 -334. 57 1533. 34 5945326.94 560399.14 MWD+IFR-AK-CAZ-SC 2856.71 71.49 100 .03 1957.56 1848.56 -350. 80 1622. 74 5945311.41 560488.65 MWD+IFR-AK-CAZ-SC 2952.84 71.26 98. 74 1988.27 1879.27 -365. 65 1712. 62 5945297.26 560578.63 MWD+IFR-AK-GAZ-SC 3048.06 71.85 98. 09 2018.39 1909.39 -378. 87 1801. 97 5945284J4 560668.07 MWD+IFR-AK-CAZ-SC 3141.34 71.49 98. 07 2047.73 1938.73 -391. 32 1889. 64 5945272.98 560755.83 MWD+IFR-AK-CAZ-SC 3236.18 70.84 98. 20 2078.35 1969.35 -404. 02 1978. 50 5945260.98 560844.77 MWD+IFR-AK-CAZ-SC 3331.73 73.51 98. 65 2107.59 1998.59 -417. 35 2068. ~7 5945248.35 560934.84 MWD+IFR-AK-CAZ-SC 3425.95 72.56 98. 11 2135.09 2026.09 -430. 48 2157. 63 5945235.92 561024.09 MWD+IFR-AK-CAZ-SC 3518.01 67.02 98. 46 2166.88 2057.88 -442. 92 2243. 08 5945224.15 561109.&3 MWD+IFR-AK-CAZ-SC 3615.17 69.19 100. 33 2203.11 2094.11 -457. 65 2332. 01 5945210.12 561198.67 MWD+IFR-AK-CAZ-SC 3706.71 69.90 101. 51 2235.10 2126.10 -473. 90 2416. 23 5945194.53 561282.99 MWD+IFR-AK-CAZ-SC 3804.13 70.11 102. 39 2268.41 2159.41 -492. 85 2505. 79 5945176.28 561372.69 MWD+IFR-AK-CAZ-SC 3900.00 71.79 103. 25 2299.70 2190.70 -512. 96 2594. 14 5945156.86 561461.20 MWD+IFR-AK-CAZ-SG ~ 3995.47 74.54 103. 98 2327.35 2218.35 -534. 47 2682. 95 5945136.05 561550.15 MWD+IFR-AK-CAZ-SC 4044.53 75.49 105. 12 2340.04 2231.04 -546. 38 2728. 82 5945124.50 561596.11 MWD+IFR-AK-CAZ-SC 4086.00 75.49 105. 12 2350.43 2241.43 -556. 85 2767. 57 5945114.33 561634.95 PROJECTED to TD • ~c~nocaPhiliip-s Time Log Summary WeiNlew Web ReAOrftnq Well Name: 1 J-122 Job Type: DRILLING ORIGINAL 06/16/2007 12:00 12:15 025 MIRU MOVE SFTY P PJSM - Doyon 141 Rig Move - Hazard Reco nition 12:15 14:30 2.25 MIRU MOVE DMOB P Move pipe sheds, Rock Washer, Boiler, Power, Pump, and mud tank complexes - Move Doyon 141 rig off 1J-120 - Gather u ri mats. 14:30 16:30 2.00 MIRU MOVE OTHR P Pick well house off 1J-118, Pull BPV, Blade ad, Shoot, & Level the rade. 16:30 18:30 2.00 MIRU MOVE MOB P Lay Herculite - Set rig mats - Move, s ot, and levei ri over 1J-122. 18:30 21:00 2.50 MIRU MOVE MOB P Set mats - Spot mud tank, pumps, power, boiler, rock washer, and pipe shed com lexes. 21:00 22:30 1.50 MIRU MOVE RURD P Rig up stairs & landings - RU Berms - Connect air, water, mud, steam, and power supply lines - Pits ready to tank of fluid. 22:30 00:00 1.50 MIRU MOVE RURD P Doyon 141 RIG ACCEPTED at 22:30 hrs - Simops - NU 20" Riser - Load pipe shed with 5" DP - Take on water to make s ud mud. 06/17/2007 00:00 01:45 1.75 MIRU MOVE RURD P Continue NU Surface stack - Load i e shed with 5" DP and Stra . 01:45 10:00 8.25 MIRU MOVE RURD P PU 270 jts of 5" DP, 14 jts HWDP with 'ars. Rack back in derrick. 10:00 10:45 0.75 MIRU MOVE RURD P Clear rig floor - PU Handling tools and BHA from beaver slide. 10:45 11:15 0.50 MIRU MOVE RURD P MU 1 std NMFDC's - Rack back in derrick. 11:15 12:00 0.75 MIRU MOVE RURD P CO Saver sub on top drive. 12:00 13:30 1.50 MIRU MOVE RURD P PJSM - Continue to CO Saver sub to 4-1/2"IF 13:30 14:30 1.00 SURFA WELCT 07HR P Function tested diverter & performed accumulator test. Initial pressure 3000 psi, drop to 1600 psi after functioning. Took 45 secs to build to 200 psi. Full recovery in 3 min 14 sec. Nitrogen 5 BUs average 2150 psi. Knife vatve opend in 14 sec. Annular closed 35 sec. Test passed. Tested gas detection and alarms. Note: Chuck Sheve with AOGCC waived test. 06/17/2007 14:30 15:00 0.50 0 0 SURFA DRILL PULD P MU BHA #1 - MU 16" Hughes bit on 8" motor with 1.83 deg bend, and float sub. RIH tag @ 106' - Break circulation - Flood riser - Check for leaks - Test mud line with 3500 psi and ck'd ok. 15:00 16:00 1.00 0 127 SURFA DRILL DDRL P Spud well at 1500 hrs and drilled 16" hole from 106' to 127' MD. ADT = 0.6 hrs. Driller noticed mud loss and pit watcher confirmed 80 - 90 bbls. Floorhand discovered cellar had flooded with spud mud - Flow line plugged. Drilling ceased and security notified. 16:00 18:45 2.75 127 127 SURFA DRILL OTHR T Clean up spill - Total of 95 bbl released inside the cellar secondary containment - 3/4 bbl outside containment - Clean out flowline lu ed with cuttin s/ ravel. 18:45 21:30 2.75 127 218 SURFA DRILL DDRL P Drill 16" surface hole from 127' - 218' MD ART = 2.17 hrs Trq 2000 ft-Ibs Drl Wts: PU 45k - SO 42 - Rt 42k 21:30 22:00 0.50 218 35 SURFA DRILL REAM P BROOH from 218' to 125' MD - POOH to 35'. LD Float Sub. 22:00 22:45 0.75 35 35 SURFA DRILL PULD P PU MWD & NM-UBHO Sub - Orient and check bit. 22:45 23:30 0.75 35 35 SURFA DRILL OTHR P Program MWD tools - Simops Mtg with Gyro crew - RU Gyro equipment on ri floor. 23:30 00:00 0.50 35 161 SURFA DRILL TRIP P RIH with NM FDC's to 161' MD. 06/18l2007 00:00 12:00 12.00 161 770 SURFA DRILL DDRL P Wash down to 218' MD with no fill - Record Gyro - Survey MWD Drilled 16" Surface hole w/mud motor from 218' to 770' MD / 763' ND (552') Ran 7 Gyro's ART 2.53 Hrs - AST 5.10 Hrs - ADT 7.63 Hrs Ave MW 9.3 ppg Increased mud wt to 9.8 -10 ppg from 600' to 800'. 12:00 12:15 0.25 770 770 SURFA DRILL SFTY P PJSM Drilling 12:15 00:00 11.75 770 1,606 SURFA DRILL DDRL P Drilled 16" Surface hole w/mud motor from 770' to 1,606' MD ! 1,445' ND (836') ART 2.52 Hrs - AST 5.35 Hrs - ADT 7.87 Hrs Ave MW 9.5 ppg - Max Gas 42 units G ro hand released at 1500 hrs 06/19l2007 00:00 12:00 12.00 1,606 2,476 SURFA DRILL DDRL P Directionally drilled 16" surface hole from 1,606' to 2,467' MD/1,832' ND, (870') ART 3.08 hrs, AST 3.45 hrs, ADT 6.53 hrs. • • 06/21/2007 08:15 09:00 0.75 0 110 SURFA CASINC RNCS P MU 13 3/8" flt shoe, thread lock jt and flt collar RIH to 110', attempted to circ thru fill up tool and was only able to circ at 1.5 bpm at 700 psi, decision was made to chan e out tool. 09:00 12:30 3.50 110 110 SURFA CASIN OTHR T LD Franks fill up too! and waited on GBR to deliver new tool, MU new fill up tool, Sim-Op: greased crown, top drive and blocks. 12:30 16:30 4.00 110 2,670 SURFA CASIN( RNCS P Cont. RIH with 13 3/8" 68#, L-80, BTC csg from 110' to 2,670' when csg sto ed. 16:30 18:45 2.25 2,670 2,670 SURFA CASIN OTHR T Trouble shoot csg stopping at 2,670', appears collar is hanging up in diverter spool, centered csg and used rig tongs to rotate csg and was able to PU and free csg, circ a btms up after pulling free, circ at 4 bpm at 300 psi, st wt up 195K, dn wt 80K. Pipe appeared to become differentially stuck after esg collar came free, took 380K up wt to free csg. Decision was made to run add. centralizers to assist in centerin cs thru diverter. 18:45 22:30 3.75 2,670 3,660 SURFA CASIN RNCS P Cont. RIH with 13 3/8" csg from 2,670', installed centralizers on every other jt while RIH, having to work csg down, down wt running from 45 to 55K down, MU Tam port collar on jt. #76 while RIH, after MU jt. #91 RIH 15' and ta ed u solid at 3,660'. 22:30 00:00 1.50 3,660 3,660 SURFA CASINC OTHR T Attempting to work csg deeper, worked csg with and without circ, st wt up 250-275K, circ at 3.75 bpm at 350 psi, Note: while drilling had 6 deg DL at ~3,500' thru sand section. 90 jts and 15' of 't #91 in hole. 06/22/2007 00:00 01:00 1.00 3,660 3,655 SURFA CASIN( OTHR T Cont to attempt to work csg deeper with and without pump and lost 5' of hole, while working pipe, pipe became differentially stuck and took 400K up wt to ull free. 01:00 02:00 1.00 3,655 3,640 SURFA CASINC OTHR T PU on csg from 3,655' to 3,640' to LD 1 full jt of csg and MU 14' pup to assist in cementin . 02:00 02:15 0.25 3,640 3,640 SURFA CASIN OTHR T Attempted to work csg down to original depth of 3,660' with no success, Pulled on csg up to 475K st wt up and pipe would not move, worked pipe with and without the , pump and no movement, circ at 4.5 bpm at 300 psi. Stuck csg with shoe at 3,640'. 06/22/2007 02:15 05:00 2.75 3,640 3,640 SURFA CEMEn CIRC P Circ hole thru Franks fill up tool while conditioning mud for cementing, staged pump rate up to 55 spm, 5.5 bpm at 300 psi. Cont to attempt to work cs dee er with no success. 05:00 06:00 1.00 3,640 3,640 SURFA CEME RURD P RD Franks fill up tool and MU Dowell cement head. 06:00 10:00 4.00 3,640 3,640 SURFA CEME~ CIRC P Pumped 30 bbl pill with red dye and cont to circ and condition mud for cementing, staged pump rate up to 6 bpm at 350 psi, initial mud was 9.6 ppg, 195 vis, PV 27 and YP of 48, conditioned mud to 9.5 ppg, 42 vis, PV 14 and YP 8. After circulating 1,500 bbls of mud no red dye was seen at surface. Held PJSM with crew, Dowell and ASRC truck drivers on cement ~ob while circ. 10:00 15:00 5.00 3,640 3,640 SURFA CEME~ DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,000 psi, cont to pump 40 add. Bbls of CW 100 at 8.3 ppg. Pumped 50 bbls of 10.5 ppg mudpush with red dye at 4.6 bpm at 220 psi. Dropped bottom plug. Mixed and pumped 847 bbls, 1031 sx of Arctic set lite cement at 10.7 ppg and 4.45 cu ft/sk yield with additives at 6.0 bpm at 400 psi. Continued mixing and pumping 165 bbls, 372 sx of Litecrete cement at 12.0 ppg and 2.49 cu ft/sk yield with additives at 6.0 bpm at 400 psi.. Shut down and dro ed to lu . 15:00 16:30 1.50 3,640 3,640 SURFA CEME~ DISP P Dowell chased plug with 20 bbls of water then turned it over to the rig and rig cont. to displace cement with 9.5 ppg mud at 6.0 bpm, initial pressure was 750 psi, max pressure at 3.5 bpm was 680 psi, bumped plug on calc displacement of 514 bbls, pressured up to 1,500 psi and held for three minutes, bled off and checked floats-OK. CIP at 16:30 hrs, had 291 bbls of good 10.7 ppg cement back at surface. 16:30 19:15 2.75 3,640 3,640 SURFA CEME OTHR P Flushed out diverter and riser, RD cement head. 19:15 20:00 0.75 3,640 3,640 SURFA WELCT NUND T PU on diverter and set 13 3/8" csg sli s with 170K st wt. blk wt 35K . 20:00 22:30 2.50 3,640 3,640 SURFA WELCT NUND T Made rough cut on 13 3/8" csg and LD same, ND diverter and line and set out same. 22:30 00:00 1.50 3,640 3,640 ISURFA WELC OTHR T Made final cut on 13 3/8" csg and began to pre-heating stub for welding • • 06/24/2007 06:00 06:45 0.75 3,660 3,660 SURFA DRILL LOT P RU and attempted to perform FIT to 12.0 and leaked off at 11.5 06:45 09:15 2.50 3,660 3,660 INTRM1 DRILL WOOR NP Discussed LOT with town, decision was made to cont. to attempt to sidetrack well then perForm FIT when sidetrack is confirmed. 09:15 09:45 0.50 3,660 3,700 INTRM1 DRILL DDRL T Oriented geopilot then drilled 40' to 3,700'. ADT .23 hrs. 09:45 10:30 0.75 3,700 3,700 INTRM1 DRILL CIRC T Pulled up into shoe and circ hole and surveyed, could not determine if well was sidetracked. 10:30 10:45 0.25 3,700 3,720 ( INTRM1 DRILL DDRL T Drilled from 3,700' to 3,720', ADT .12 10:45 12:00 1.25 3,720 3,720 INTRM1 DRILL CIRC T Circ hole and cond. mud for survey, had trouble takin surve . 12:00 12:15 0.25 3,720 3,735 INTRM1 DRILL DDRL T Drilled from 3,720' to 3,735' MD/ ???? ND, ADT .09 hrs, PU and slacked off tagging btm, well appears to be sidetracked. 12:15 13:00 0.75 3,735 3,735 INTRM1 DRILL CIRC T Circ btms up and pulled up to 3,635' cs shoe 3,640' 13:00 13:30 0.50 3,735 3,735 INTRM1 DRILL FIT T RU and performed FIT to 11.0 ppg EMW, 172 psi with 9.5 ppg MW at 2,211' ND 13:30 17:15 3.75 3,735 4,086 INTRM1 DRILL DDRL T Cont to sidetrack well from 3,735' to 4,086' (16" hole TD) ADT 2.15 hrs. Displaced hole over from 9.5 ppg spud mud to reconditioned 9.5 ppg LSND while drillin . 17:15 00:00 6.75 4,086 4,847 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole with Geopilot from 4,086' to 4,847' MD/ 2,525' ND (761') ADT 2.48 hrs. 5-15K wob, 120 rpm's, varied flow rates for directional control from 675 gpm to 735 gpm, 1,900 psi to 2,025 psi, 9.5 ppg ave MW, ave ECD 9.95 ppg, ave BGG 35 units, max gas 1,504 units from a rox. 4,050'. 06/25/2007 00:00 09:30 9.50 4,847 5,795 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole with Geopilot from 4,847' to 5,795' MD/ 2,726' ND (948') ADT 5.4 hrs. Pumped 30 bbl hi vis sweep at 5,645' with no increase in cuttings back from swee . 09:30 10:45 1.25 5,795 5,795 INTRM1 DRILL CIRC P Hole began packing off slightly, pumped 40 bbl low vis sweep followed by a 30 bbl high vis sweep and circ out of hole, saw 15% increase in cuttings back from the sweep, circ at, 740 m, 2,450 si. 10:45 12:00 1.25 5,795 5,893 INTRMI DRILL DDRL P Drilled 12 1/4" hole from 5,795' to 5,893' MD/ 2,744' ND (98') ADT .69 hrs., ave BGG 40 units, max gas 81 units, ave MW 9.45 ppg, ave ECD 10.1 ppq • . ~ 06l27/2007 22:45 00:00 1.25 3,544 3,544 INTRM1 DRILL CIRC P Circ btms up at 3,544', circ hole clean, staged pump rate up due to cold mud, staged pump rate up to 740 gpm, 2,150 psi, 75 rpm's, rot wt 77K, up wt 96K, dn wt 55K. 06l28/2007 00:00 00:15 0.25 3,544 3,968 INTRM1 DRILL TRIP P RIH from 3,544' and sat down at 3,968'. 00:15 02:00 1.75 3,968 4,023 INTRM1 DRILL OTHR P POOH from 3,968' to 3,544' then downlinked Geopilot to 100% deflection to 90 deg. left, RIH and sat down again at 3,968', est circ and took survey and determined to be in 12 1/4" hole and not in the original 16" hole. Washed down from 3,968' to 4,023', washed down slow at 300 gpm and 80 m's. 02:00 04:15 2.25 4,023 9,537 INTRM1 DRILL TRIP P RIH with BHA #3 from 4,023' to 9,537'. 04:15 04:30 025 9,537 9,721 INTRMI DRILL REAM P Washed down 184' from 9,537' to btm at 9,721', staged pump rate up to 740 m at 3,300 si while washin down. 04:30 05:30 1.00 9,721 9,721 INTRM1 DRILL CIRC P Circ btms up at 9,721', circ at 740 gpm, 3,300 psi, 120 rpm's with 14-15K off btm tor ue 05:30 12:00 6.50 9,721 10,418 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole from 9,721' to 10,418' MD/3,702' TVD (697') ADT 3.56 hrs. Ave MW 9.5 ppg, ave ECD 10.26, ave BGG 45 units, max as 84 units. 12:00 18:30 6.50 10,418 10,970 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole from 10,418' to 10,970' MD/3,787' ND (552') ADT 4.51 hrs. #2 Mud pump mud cross washed out. 18:30 22:30 4.00 10,970 10,970 INTRM1 RIGMN RGRP T Worked pipe slowly with #1 mud pump while pulling pipe from 10,970' to 10,108' and RIH slow to btm. Repaired mud cross on #2 mud pump, 1st attempt failed then 2nd repair tested ok. 22:30 00:00 1.50 10,970 11,215 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole from 10,970' to 11,215' MD/3,827' ND (245') ADT 1.27 hrs. Ave MW 9.5 ppg, ave ECD 10.20, ave BGG 50 units, max as 267 units. 06/29/2007 00:00 07:30 7.50 11,215 11,932 INTRM1 DRILL DDRL P Directionally drilled 12 1/4" hole from 11,215' to 11,932' MD/3,931' ND (717') ADT 4.03 hrs. (T.D. F/9 5/8" csg) Ave MW 9.5 ppg, ave ECD 10.28, ave BGG 50 units, max gas 262 units, pumped hi vis sweep prior ~ to TD and had 5% increase in cuttings ' back from the swee . 07:30 07:45 0.25 11,932 11,932 ~INTRM1 DRILL OWFF P Monitored well-static 06/29/2007 07:45 19:30 11.75 11,932 3,600 INTRMI DRILL REAM P Backreamed out of hole from 11,932' to 3,600' ( csg shoe @ 3,640'), BROOH at 150 rpm's, 780 gpm, ICP 3,7000 si, FCP 2,500 si. 19:30 20:45 1.25 3,600 3,600 INTRM1 DRILL CIRC P Circ hole clean at 3,600', circ 3 complete hole volumes at 150 rpm's, 780 gpm at 2,500 psi, rot wt 77K, up wt 97K, dn wt 67K. 20:45 21:00 0.25 3,600 3,600 INTRM1 DRILL OWFF P Monitored well-static, pumped dry job and blew down to drive. 21:00 23:15 2.25 3,600 75 INTRM1 DRILL TRIP P POOH on elevators from 3,600' to 75', stood back HWDP, jars and NMFDC's POOH to MWD tool. 23:15 00:00 0.75 75 75 INTRM1 DRILL PULD P Download MWD. 06/30/2007 00:00 01:30 1.50 75 0 INTRM1 DRILL PULD P Fin LD BHA #3, POOH LD MWD and 01:30 02:00 0.50 0 0 INTRM1 DRILL OTHR P Cleared and cleaned rig floor. 02:00 02:30 0.50 0 0 INTRM1 DRILL OTHR P Attempted to pull wear bushing and wou~d not come free, called out Vetco Gra re . 02:30 03:30 1.00 0 0 INTRM1 RIGMN SVRG P Siip and cut 72' of drlg line. 03:30 05:15 1.75 0 0 INTRM1 DRILL OTHR NP Attempted to puil wear bushing again with tugger and blocks with no movement, MU stack washer and circ around wear bushing, Latched wear bushing and pulled 25K and bushing ulled loose, LD same. 05:15 06:15 1.00 0 0 INTRM1 CASIN( RURD P RU to run 9 5/8" csg, changed out elevator bales and MU Franks fill up tool. 06:15 06:30 0.25 0 0 INTRM1 CASIN SFTY P Held PJSM with rig crew and tong operator on csg running details and hazard assessment for the 'ob. 06:30 14:45 8.25 0 3,635 INTRM1 CASIN RNCS P RIH with 9 5/8" csg to 3,635' (csg shoe at 3,640') MU 3 jts 9 5/8" 40#, L-80 BTCM csg and shoe track and thread locked same RIH 85' and checked floats. Cont. RIH with 85 add. Jts of 9 5/8" 47# & 40#, L-80, BTCM csg to 3,635". Installed centralization per well plan. (Note: Jts #4 thru #7 are 47#, L-80, BTCM, remaining csg is 40# 14:45 16:15 1.50 3,635 3,635 INTRM1 CASIN CIRC P Circ btms up at 3,635' then spotted 70 bbl Steel Lube pill in the annulus. Staged pump rate up to 5 bpm at 225 si, st wt u 125K, dn wt 92K 16:15 00:00 7.75 3,635 8,941 INTRMI CASINC RNCS P Cont. RIH from 3,635' to 8,941', no problems RIH (RIH 20 stds and washing down 2) st wt up 226K, dn wt 81 K. 07/01/2007 00:00 03:00 3.00 8,941 11,928 INTRM1 CASIN( RNCS P Cont to RIH with 9 5/8" csg from 8,941' to 11,928'. Ran 286 total jts of csg with 4 pup jts to place csg and window jts on depth, initial string wt up 270K and down wt 75K. Ran 1 tandem rise bowspring centralizer on jt #3 below flt collar on a stop ring, ran 124 EZEE glider cent. from jt # 2 thru 125 floating, ran 6 turbolizer cent 3/2 jts on jts 27 & 28 then #40 & 41 using 6 stop rings, turbolizers placed on jts above window jts, then ran 80 Lo-torque roller cent. floating 1/jt from 't# 202 thru 282 inside the 9 5/8" cs .. 03:00 05:00 2.00 11,928 11,928 INTRM1 CEME CIRC P Began to circ and cond. mud for cementing, circ btms up thru the Franks tool, staged circ rate up to 6.5 bpm at 520 psi. st wt up 265K, dn wt 05:00 05:45 0.75 11,928 11,928 INTRM1 CEME~ RURD P RD Franks fill up tool and MU Dowell cement head. 05:45 07:45 2.00 11,928 11,928 INTRM1 CEME~ CIRC P Cont to circ and condition mud for cementing, staged pump rate up to 7 bpm at 550 psi, initial mud was 9.5 ppg, 42 vis, PV 22 and YP of 44, conditioned mud to 9.5 ppg, 41 vis, PV 9 and YP 14, held PJSM with crew, Dowell and ASRC truck drivers on cement job while circ. st wt up 245K, Dn wt 88K 07:45 09:30 1.75 11,928 11,928 INTRMI CEME DISP P Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 65 add. Bbls of CW 100 at 8.3 ppg and pumped 75 bbls of 10.5 ppg mudpush at 5 bpm at 500 psi.. Dropped btm plug. Mixed and pumped 366 bbls, 920 sx of Deepcrete cement at 12.5 ppg and 2.25 yield with additives, ave 6.3 bpm at 900 psi, 09:30 12:15 2.75 11,928 11,928 INTRM1 CEME~ DISP P Rig displaced cement with 8.4 ppg MOBM at 7 bpm, initial pressure was 450 psi, max pressure at 7 bpm was 1,800 psi, stopped reciprocating pipe 606 bbls into displacement when we lost all down wt, had 68 bbls of cement out of the shoe, slowed to 3 bpm and pumped calc displace of 902 bbls including ? shoe track and plug did not bump. Shut down with 1,600 psi, held for three minutes, bled off 3 bbls and checked floats-OK. Had good returns through out the job, calc TOC 6,777'. CIP at 11:50 hrs. 12:15 12:45 0.50 11,928 11,928 ~INTRM1 CEME RURD P RD cement head and drained stack. • ~ ~ 07/02/2007 17:00 20:15 3.25 6,116 11,634 INTRM1 DRILL TRIP P RIH out of the derrick from 6,116' to 11,634', SLM on tri in hole. 20:15 21:30 1.25 11,634 11,634 INTRM1 RIGMN' SVRG P Slip and cut 42' of drlg line then serviced to drive. 21:30 22:00 0.50 11,634 11,842 INTRM1 DRILL TRIP P RIH from 11,634' and washed down tagging plugs above FC at 11,842' (FC at 11,848' 22:00 00:00 2.00 11,842 11,917 INTRM1 CEME COCF P Drilled out plugs, FC at 11,848' and driiling on shoe track at 11,917' (FS at 11,928') driliing with 3-4K wob, 60 rpm's, 550 gpm at 2,650 psi with 10K ft-Ibs torque, rot wt 97K, up wt 155K, dn wt 90K. 07/03/2007 00:00 00:15 0.25 11,917 11,957 INTRM1 DRILL DRLG P Continue drilling out shoe track to 11,928' MD. Drilled 25' new hole from 11,932' to 11,957' MD at 80 RPM, 11 K Tr , 550 GPM 2600 si. 00:15 01:00 0.75 11,957 11,957 INTRM1 DRILL CIRC P Circulate hole clean for LOT @ 144 01:00 01:45 0.75 11,957 11,957 INTRM1 DRILL LOT P RU & perform LOT to 14.6 ppg EMW, MASP 1260 psi. Hole Depth 11,957' MD, 3,933' ND w/ 8.4 ppg MOBM. Ri Dwn. 01:45 06:00 4.25 11,957 12,483 PROD1 DRILL DDRL P Drilled 8-1/2" hole in A2 sand with Geopilot from 11,957' to 12,483' MD / 3,934' ND. ADT = 2.74 hrs 06:00 07:00 1.00 12,483 12,483 PROD1 DRILL OTHR T Shut down to repair & weld gear on conveyer in mud pits - POOH from 12,483' to 11,928' MD - TIH to 12,483' MD. 07:00 12:00 5.00 12,483 13,051 PROD1 DRILL DDRL P Drilled 8-1/2" hole in A2 sand with Geopilot from 12,483' to 13,051' MD / 3,947' TVD (568'). Max Gas = 400 units, Ave ECD 10.7 Drilled 4 concretions for a total of 29'. ADT = 2.66 hrs 12:00 00:00 12.00 13,051 14,213 PROD1 DRILL DDRL P Drilled 8-1/2" hole in A2 sand with Geopilot from 13,051' to 14,213' MD / 3,968' TVD (1,162'). Max Gas = 491 units, Ave ECD 10.79 Drilled 6 concretions for a total of 31'. ADT = 7.04 hrs 25 Su ersliders in hole b midni ht. 07/04/2007 00:00 09:30 9.50 14,213 15,109 PROD1 DRILL DDRL P Drillecf 8-1/2" hole in A2 sand with Geopilot from 14,213' to 15,109' MD / 3,961' ND (896'). Drilled 12 concretions for a total of 99'. ADT = 6.42 hrs 09:30 12:00 2.50 15,109 13,804 PROD1 DRILL REAM P Called TD early - North of Fault Crossing at 14,594' MD found reservoir wet. BROOH from 15,109' MD to 13,804' MD @ 150 RPM, 151 spm, 3350 si. 12:00 13:45 1.75 13,804 11,917 PROD1 DRILL REAM P Cont BROOH to 11,917' MD. 07/04/2007 13:45 15:30 1.75 11,917 11,917 PROD1 DRILL CIRC P Pump 35 BBLS Hi-Vis sweep - 120 rpm - 635 gpm - 152 spm - 3050 psi. Pumped 1 full circulation + 1 BU - 10°/a increase in cuttin s. 15:30 16:45 1.25 11,917 14,545 PROD1 DRILL TRIP P RIH from 11,917'to 14,545' MD. 16:45 20:30 3.75 14,545 14,545 PROD1 DRILL CIRC P Pump 35 BBLS Hi-Vis sweep - 140 rpm - 150 spm - 635 gpm - 3400 psi. Pumped 1 full circulation + 1 BU - 10°/a increase in cuttin s. 20:30 22:00 1.50 14,545 14,545 PROD1 DRILL CIRC P Displace well to 1,032 BBLS of SFOBM @ 120 spm - 505 gpm - 2750 psi. Recipricate pipe while pumping. SO Wt = 54k, PU Wt 210k, Rot Wt 105k, Tr 17k. 22:00 22:15 0.25 14,545 14,545 PROD1 DRILL OWFF P Record slow pump rates & monitor well - static. 22:15 22:45 0.50 14,545 14,175 PROD1 DRILL TRIP P POOH on elevators from 14,545' to 14,175' - Not takin ro er fill. 22:45 00:00 1.25 14,175 13,619 PROD1 DRILL TRIP P Pump out of hole with no rotation from 14,175' to 13,619' MD. Pumping @ 30 spm - 130 gpm - 250 psi. Dropped 2-1 /8" rabbit with wire tail on stand #143. 1 stripping rubber in hole @ midnight. During mud change out a slight fluid loss was noted. 15-20 bbls ~~ 07/05/2007 00:00 00:45 0.75 13,619 11,917 PROD1 DRILL TRIP P Continue pumping out of hole from 13,619' to 11,917' MD - 30 spm - 250 si 00:45 01:00 0.25 11,917 11,917 PROD1 DRILL OWFF P Flow check well at 9-5/8" shoe - static - Blow dwn TD. 01:00 06:15 5.25 11,917 446 PROD1 DRILL TRIP P POOH from 11,917' to 2,334' MD on elevators. LD 60 jts of DP to shed to 446' MD. 06:15 07:15 1.00 446 58 PROD1 DRILL PULD P LD HWDP, Jars, NM DC's. Retrieved 2-1/8" rabbit & wire. 07:15 07:45 0.50 58 58 PROD1 DRILL OTHR P Plug in and download MWD. 07:45 08:30 0.75 58 0 PROD1 DRILL PULD P Continue LD BHA - NM Flt Sub, TM HOC, HCIM, Smart Stab, MWD, Smart Stab, NM Geo-Flex, Geo-Pilot, and Bit. 08:30 09:00 0.50 0 0 PROD1 DRILL RURD P Clean and clear rig floor. 09:00 10:30 1.50 0 0 COMPZ RIGMN SVRG P PJSM - Change out Saver Sub. 10:30 11:30 1.00 0 0 COMPZ RIGMN SVRG P PJSM - Slip and cut 45.5' Drill line (7 Wra s 11:30 12:00 0.50 0 0 COMPZ RIGMN' SVRG P Service Top Drive 12:00 12:30 0.50 0 0 COMPZ EVAL SFTY P SWS on location - PJSM with crew and SLB on wireline safe . 12:3Q 13:15 0.75 0 0 ~COMPZ EVAL RURD P RU Wireline unit to rig. 07/05/2007 13:15 14:15 1.00 0 0 COMPZ EVALVI~ PULD P SWS MU BHA: CCL, Pwr supply, 3 Tractors (1 as backup), GR Logging tools, USIT. OAL = 101.6'. 14:15 21:00 6.75 0 11,860 COMPZ EVAL ELOG P RIH with logging tools - Fall to 4840' @ 78 degrees - Tractor down to 11,860' MD. Coorelated to LWD Log. Encountered tight spot tractoring @ 5900' MD. 21:00 00:00 3.00 11,860 5,000 COMPZ EVALNb ELOG P Log 2 up passes from 11,860' to 5000' MD 1800 f h. 07/06/2007 00:00 01:15 1.25 5,000 0 COMPZ EVAL ELOG P Continue Logging Interval with USIT - POOH. 01:15 02:15 1.00 0 0 COMPZ EVALVI~ PULD P On surtace with SWS BHA - Clean & LD Lo in tools. Ri down SWS. 02:15 02:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 5.5" Liner. 02:30 05:15 2.75 0 3,584 COMPZ CASINC RNCS P RIH with 5.5" 15.5 ppf L80 BTCM Liner to 3584' as follows: 1 Blank pup jt with orange peeled end welded shut - Pup jt - Swell PKR - Pup Jt - 55 Jts of Blank & Slotted Liner, 26 Jts of Blank & Slots with Trq Rings (Total - 58 Blanks & 23 Slots). Installed 65 Floatin S iral liders. 05:15 05:45 0.50 3,584 3,656 COMPZ CASIN RUNL P PU XO - BKR SBE - RS Packoff Seal Npl - BKR ZXP Liner Top PKR - Liner Settin Tool. 05:45 06:00 0.25 3,656 3,656 COMPZ CASINC RURD P Clear rig of casing running equipment - Pre for PU DP. 06:00 11:00 5.00 3,656 12,056 COMPZ CASIN RUNL P TIH with Liner on 5" DP taking T&D Data @ 3000' and every 1000' there after. Recorded Trq data @ Shoe - 13K @ 11,920' MD - 20 rpm - PU Wt 175k - SO Wt 50k. Continue TIH to 12,056' MD. 11:00 12:00 1.00 12,056 12,086 COMPZ CASIN RUNL P Rotate liner from 12,056' to 12,086' MD. 12:00 13:30 1.50 12,086 12,371 COMPZ CASIN( RUNL P PJSM - Continue RIH Rotating & Workin liner to 42,371' MQ. 13:30 17:45 4.25 12,371 3,653 COMPZ CASIN RUNL T Decision made to POOH with Liner. Unable to RIH afterworking liner at maximum Trq - Stalling @ 11 k. POOH to 3653' MD. Monitor well - Static. 17:45 19:00 1.25 3,653 3,584 COMPZ CASIN( PUTB T LD Baker Liner Assembly - RU E ui ment to LD Liner. 19:00 19:15 0.25 3,584 3,584 COMPZ CASIN SFTY T PJSM to discuss hazard recognition for LD Liner. 19:15 00:00 4.75 3,584 0 COMPZ CASIN( OTHR T POOH LD Liner, Swell PKR, and shoe Jt. Displacement 8 BBLS long. Sweli PKR had minor damage to lower ta ered end. 07/07/2007 00:00 00:30 0.50 0 COMPZ WELCT BOPE P Clear rig floor of casing tools. Drain Stack - PU 5" Test Jt - Install wear rin retrievin lu and LD wear rin . 00:30 00:45 0.25 COMPZ WELC SFTY P PJSM on testing BOPE. 07l07/2007 00:45 05:15 4.50 COMPZ WELC BOPE P Install test Plug - Fill with water and test BOPE to 250 psi low and 3000 psi high for 5 minutes on chart. Test choke manifoid valves #1 -14, manual & HCR choke and kill, Bag, Top VBR rams 3.5x6, Top Drive Upper & Lower IBOP, 5" TIW and Dart Valves, Blind Rams. Test Koomy. PU 4.5" Test Jt and test with top rams. All tests good. Test Witnessed by AOGCC State Rep Chuck Sheve. 05:15 05:30 0.25 COMPZ WELCT BOPE P Install wear ring and LD test jt. 05:30 05:45 0.25 COMPZ DRILL SFTY T PJSM and Hazard recognition on PU BHA and TIH. 05:45 06:30 0.75 292 12,012 COMPZ DRILL PULD T PU & MU Bullnose Hole Opener BHA #5. 06:30 10:30 4.00 292 12,012 COMPZ DRILL TRIP T TIH from 292' to 12,012' MD - Filling pipe every 25 stands. Record T&D Numbers @ Shoe, 50 rpm: PU Wt 195k, SO Wt 80k, Trq 13.5k ft-Ibs. 10:30 12:00 1.50 12,012 12,690 COMPZ DRILL REAM T Ream to 12,690' @ 50 rpm, 13-20k Tr , 4 b m, 440 si, Rot Wt 90k. 12:00 13:45 1.75 12,690 14,680 COMPZ DRILL REAM T PJSM - Continue wash/ream from 12,690' to 14,680' @ 340 gpm, 100 m, 13-14k tr . 13:45 16:30 2.75 14,680 14,680 COMPZ DRILL CIRC T Circulate & Recip. pipe while pumping 55 bbls Hi-Vis Sweep - 620 gpm, 3000 psi, 110 rpm. Sweep returned minimal excess. PU Wt 235k, Rt Wt 105k. 16:30 16:45 0.25 14,680 14,587 COMPZ DRILL TRIP T Monitor well - static - Drop 1-7/8" rabbit with 100' tail. POOH from 14,680' to 14, 587' - Swabbing while POOH. 16:45 20:00 3.25 14,587 11,900 COMPZ DRILL REAM T BROOH @ 126 gpm and 50 rpm from 14,587' to 11,900' MD. Monitor well - static. Record T&D numbers above shoe in csg @ 50 rpm: PU Wt 210k, SO Wt 35-37k, Rot Wt 105k, Tr 20k with stall at 19.5k ft-Ibs. 20:00 22:00 2.00 11,900 7,305 COMPZ DRILL REAM T Continue POOH to 8500' MD. Record T&D numbers @ 25 rpm: PU Wt 155k, SO Wt 60k, Rot Wt 100k, Trq 16k with stall at 14.5k ft-Ibs. Continue POOH to 7305' MD. 22:00 22:30 0.50 7,305 7,305 COMPZ DRILL OTHR T Service blocks and TD. Call with town en ineers to discuss lan forward. 22:30 00:00 1.50 7,305 9,768 COMPZ DRILL TRIP T Decision made to RIH to shoe, pump hi-vis sweep, and displace SFOBM over to OBM. RIH to 9768' MD. Filled DP 9300'. 07/08/2007 00:00 01:00 1.00 9,768 11,832 COMPZ DRILL TRIP T Continue TIH from 9,768' to 10,328' MD. Ran out of SO Wt @ 10,328' MD - FZotate to 11,832' MD @ 50 rpm. Trq limit sei at 20K - would stall if pipe not movina. Pum~ina 60 snm Ca~ 650 ~si. • i 07/08/2007 23:30 00:00 0.50 14,619 14,619 COMPZ CASIN CIRC P Circulate ball down DP at 31 spm, 400 si. 07/09/2007 00:00 01:00 1.00 14,619 14,616 COMPZ CASIN OTHR P Continue pumping 1-3/4" ball down @ 31 spm, 400 psi - On seat at 1445 stks and 600 psi. Pumped 1.4 bbls to inflate PKR @ 1800 psi. SO to 35k. Pumped to 3715 psi to blow ball seat. PU to release from liner @ 155k. Lined up to pump down the annulus and test to 2500 psi for 5 mins on chart. PU Wt 158k - Dwn Wt 75k. Tag Liner Top @ 10,970' MD - Btm of liner set at 14,616' MD, Swell PRK set at 14,542' MD. 01:00 01:15 0.25 10,970 10,934 COMPZ CASIN( OTHR P LD Single jt of DP - Flow check weli - Static. 01:15 03:00 1.75 10,934 8,312 COMPZ CASIN( RUNL P POOH from 10,934' to 9,135' MD. LD 27 jts of HWDP to the pipe shed - SB 2 jts for upcoming window BHA - POOH to 8312' MD. 03:00 04:30 1.50 8,312 8,312 COMPZ RIGMN SVRG P Slip and cut 81' of Drill line. Service To Drive. 04:30 08:00 3.50 8,312 72 COMPZ CASINC RUNL P Continue POOH from 8,312' to Liner runnin tool. 08:00 08:45 0.75 72 0 COMPZ CASINC PUTB P LD Liner Running tool. 08:45 09:00 0.25 COMPZ CASIN( OTHR P Clean and Clear Rig Floor 09:00 09:15 0.25 PROD2 DRILL SFTY P PJSM on PU and MU Whipstock BHA 09:15 12:00 2.75 0 167 PROD2 STK PULD P MU Whipstock assembly BHA: MU Window mill - Lower mill - Flex Jt - Upper Mill - Fit Sub - TM - 1 jt 5" DP - Rack Back. PU Locator sub - XO - Unloader sub - 2 jts 4-1/2" DP - Pup jt - 2 XO's - Bianking Sub - Trip Anchor - Shear Disconnect - Drain sub - Debris Sub - 9-5/8" Window w/17.64' slide. MU Mill Assembl to slide. 12:00 12:30 0.50 167 250 PROD2 STK PULD P PJSM. PU MWD & Bumper Sub. Pro ram MWD. 12:30 13:15 0.75 250 533 PROD2 STK PULD P PU 3 jts Flex DC's - PU HWDP - Shallow Pulse test 533' MD. 13:15 16:45 3.50 533 9,648 PROD2 STK TRIP P RIH with Whipstock/Milling Asmbly. Fill DP 3371', 6218' and 9648' MD. 16:45 17:30 0.75 9,648 9,733 PROD2 STK TRIP P Mad Pass from 9,662' to 9,733' MD. Orient toolface at 7 de Left. 17:30 18:00 0.50 9,733 10,875 PROD2 STK TRIP P Continue RIH - Break Circulation at 10,875' MD. PU Wt 135k, SO Wt 70k. 18:00 18:45 0.75 10,875 10,875 PROD2 STK WPST P Orient and set whipstock @ 13 deg Left High Side. Pumps on Up Wt 135, SO Wt 70 - Pumps off Up Wt 145k, SO Wt 78k. Shear anchor and confirm with 20k over ~ull. 07/09/2007 18:45 21:30 2.75 10,875 10,827 PROD2 STK WPST P Shear off Whipstock - Top of Whipstock set at 10, 827' MD with Btm set at 10,843.5' MD. Inclination at KOP 85 de . 21:30 00:00 2.50 10,827 10,833 PROD2 STK WPST P Milling B Lat Window from 10,827' to 10,833' MD. Weight on Mill 2-4k, 90-100 rpm, 11-12k Trq, Pumping 500 m 2100 si. 07/10/2007 00:00 04:15 4.25 10,833 10,889 PROD2 STK WPST P Continue milling window @ 509 gpm, 1925 psi, 90 rpm, Trq 9.5k. Milled a total 25' of 8.5" gauged hole to 10,889' MD. 04:15 05:30 1.25 10,889 10,889 PROD2 STK CIRC P Circulate Hi-Vis Sweep plus BU's @ 600 gpm, 90 rpm. Recip to polish milled window. 05:30 05:45 0.25 10,889 10,889 PROD2 STK TRIP P Worked string through window with no um s and rotation smoothl . 05:45 09:30 3.75 10,889 393 PROD2 STK TRIP P Flow check - Static - Pump Dry Job - POOH from 10,889' to 393' MD. 09:30 10:30 1.00 393 107 PROD2 STK PULD P Rack back 1 std HWDP and NMFIex DC's, LD 3'ts HWDP & Bum er Sub. 10:30 11:00 0.50 107 107 PROD2 STK PULD P Down Load MWD Data 11:00 12:00 1.00 107 24 PROD2 STK PULD P LD MWD, Flt Sub, 1 Jt HWDP, 8.5" OD U er Mill. 12:00 12:30 0.50 24 0 PROD2 STK PULD P PJSM - Cont LD Flex Jt & 8' Lower Mill & Window Mill. Clear Ri Floor. 12:30 14:00 1.50 0 0 PROD2 DRILL OTHR P Pull Wear Ring & Flush Stack - Problems Setting wear ring - Found piece of rubber shaved off annular element - Set & Pull Wear Rin . 14:00 16:30 2.50 0 0 PROD2 WELCT BOPE NP Set test plug - Fill stack with water - RU & test Hydril to 250 low and 3000 si for 10 minutes. 16:30 17:30 1.00 0 75 PROD2 DRILL PULD P PU BHA #7 - 8.5" Bi#, GeoPilot, Pony Flex, MWD, & Float Sub. 17:30 18:00 0.50 75 75 PROD2 DRILL OTHR P Program MWD - Lube Crown. 18:00 19:30 1.50 75 365 PROD2 DRILL PULD P RIH with Flex Dc's - PU Jars and 2 jts HWDP - RIH - Break in GP and Shallow Pulse Test tools. 19:30 21:15 1.75 365 2,241 PROD2 DRILL TRIP P RIH picking up 60 jts of 5" DP from shed to 2,241' MD. Monitor well - Static. 21:15 00:00 2.75 2,241 8,878 PROD2 DRILL TRIP P Cont RIH to 8,878' MD - Fill DP @ 3,186', 6,023', and 8,878' MD. 07/11/2007 00:00 00:15 0.25 8,878 10,868 PROD2 DRILL TRIP P Continue TIH from 8,878' to 10,868' MD. 00:15 00:45 0.50 10,868 10,889 PROD2 DRILL REAM P Ream from 10,868' to 10,889' MD. Take check shot survey. Ream @ 50 rpm, 550 gpm, 2600 psi. Trq 10k, Rot Wt 90k, Up Wt 145k, SO Wt 70k. ~ ~ ~ 07/1 21:00 21:15 0.25 10,770 10,770 PROD2 DRILL SFTY P PJSM to review hazards with Slip & Cut DL. 21:15 22:45 1.50 10,770 10,770 PROD2 RIGMN SVRG P Slip and Cut 69' of driliing line - Service Top Drive - Adjust Drilling brakes - Identified a small Glycol leak on the drillers side of the brake drum. Mechanic inspected - Decision was made to continue with normal 22:45 00:00 1.25 10,770 11,451 PROD2 DRILL TRIP P Continue to RIH from 10,770' MD without pumps and rotary - Lose Wt and Stack out 15k #just above TOW @ 10,825' MD - Worked string and rotated 1/2 turn without success. Brought Pumps online to verify GP was set a 0% deflection. Worked pipe - Rotated 10 rpm, 15K Wt - No success. Rotated 10 RPM with pumps @ 585 gpm, 2540 psi - Stalled at 14K ft-Ibs of torque. PUH - Slide down through window without rotary and pumps @ 585 gpm and 25K WOB. Slide down total of 2 stands through window to 10,975' MD. Continue RIH to 11,451' MD with um s off. 07/14/2007 00:00 00:45 0.75 11,451 13,901 ~PROD2 DRILL TRIP P Continue RIH to 13,901' MD. 00:45 01:00 0.25 13,901 13,960 PROD2 DRILL CIRC P Break Circulation @ 13,901' MD - Wash and Ream to 13,960' MD - No Fill encountered - Pumped 150 spm @ 3450 si, 110 m, 12k ft-Ibs of tr . 01:00 04:00 3.00 13,960 13,960 PROD2 DRILL CIRC P Pump a 30 BBL HiVis sweep and 3 BU's at 150 spm, 3450 psi, 110 rpm, 12k ft-Ibs of tr . 04:00 06:00 2.00 13,960 13,960 PROD2 DRILL CIRC P Displaced well over to 60/40 8.4 ppg SFOBM - Pumped a total of 961 BBLS Monitor Well - Static. Obtain SPR's and T&D data on btm. 06:00 08:15 2.25 13,960 10,784 PROD2 DRILL TRIP P POOH on elevators to 10,784' MD. Obtain T& D per rig engineer - Pull 50k Dra . 08:15 10:00 1.75 10,784 10,784 PROD2 RIGMN' SVRG T Service Rig - Repair Glycol leak on DrawWorks. 10:00 12:00 2.00 10,784 10,784 PROD2 DRILL CIRC P Circulate and condition mude with 3% 776 Lube to reduce trq and drag - Pumped 60 spm, 600 psi, Trq 8-10k ft-Ibs. Reduced Tr from 16k to 9k. 12:00 12:30 0.50 10,784 10,784 ~ PROD2 RIGMN SVRG P PJSM - Repair DrawWorks leak. 12:30 16:45 4.25 10,784 2,244 PROD2 DRILL TRIP P POOH from 10,784' to 2,244' MD - Continue to record T&D data. 16:45 19:30 2.75 2,244 75 IPROD2 DRILL TRIP P LD 60 Jts of 5" DP, 5 Jts HWDP, Jars, and 3 NM Flex Collars. 07/14/2007 19:30 21:30 2.00 75 0 PROD2 DRILL PULD P Download MWD - Break Bit, LD MWD & GeoPilot. Inspection of BHA at surface - GP had damage to the roller blades with a few of the lower rollers missing - Possible Brass Shear Pin from Whipstock Asmbly lodged into one of the cutter blades on GP - Flex Collars had scarin . 21:30 22:30 1.00 0 0 COMPZ CASIN( RURD P Clear floor - RU equipment to run 4.5" B Lat Liner - PJSM to reveiew rocedures and discuss hazards. 22:30 00:00 1.50 0 899 COMPZ CASIN RNCS P Run 21 jts of 4.5" 11.6 ppf L-80 Slottted & Blank Liner to 899' MD. 07/15/2007 00:00 01:00 1.00 899 2,833 COMPZ CASIN RNCS P PJSM - Continue RIH with 46 jts plus 2 pup jts of 4.5" 11.6 ppf L-80 Slotted & Blank Liner to 2833' MD. Ran total of 67 Jts: 43 Blanks and 24 Slots. Liner included 58 Hydroform Centralizers - 8 TAM FreeCap Constrictor Packers - 27 Torque Rin s. 01:00 02:00 1.00 2,833 2,921 COMPZ CASIN RNCS P PU & RIH with XO, 4.5" Pup, XO, Baker Receptacle Jt, 5.5" Pup, XO, Baker "HR" Liner setting sleeve, Setting tool to 2921' MD. RD Casing E ui ment and clear floor. 02:00 09:00 7.00 2,921 13,949 COMPZ CASIN( RUNL P RIH with liner on 5" DP - Obtain Trq & Drag data every 10 stands. Tag Btm at 13,977.61'. Liner set with shoe @ 13,948.85' MD and TOL @ 11,040.72' MD. PU Wt 175k, SO Wt 60k. 09:00 10:30 1.50 13,949 11,041 COMPZ CASIN( CIRC P Circulate ball on seat at 1900 strokes, Pressure up to 3600 psi and release from liner. 10:30 11:00 0.50 11,041 10,836 COMPZ CASIN( RUNL P Pull out of liner- PU wt 165k, SO Wt 65k, Rot Wt 115k, Trq 8-10k ft-Ibs. POOH to 10,836' MD 11:00 11:30 0.50 10,836 10,836 COMPZ CASIN CIRC P Wash slot on slide @ 10,836' MD at 7 b m, 650 si. 11:30 12:00 0.50 10,836 10,330 COMPZ CASIN( RUNL P Continue to POOH to 10,330' MD. 12:00 13:00 1.00 10,330 10,330 COMPZ CASIN( CIRC P PJSM - Displace from SFOBM to OBM from 10,330' MD (Planned depth for "D" Sand TO 13:00 18:15 5.25 10,330 0 COMPZ CASIN RUNL P Flow check well - static - POOH to 8,540' MD - Pump slug - Continue to POOH (strapping pipe). LD Baker settin tool. 18:15 18:45 0.50 0 0 COMPZ CASIN RURD P Clean and clear rig floor - Pick up Baker Whipstock Hook Assembly and Tools from beaver slide. 18:45 19:00 0.25 COMPZ FISH SFTY P PJSM - Discuss Hazards and Procedures for RU Fishinq BHA. ~.I ~ 07/15/2007 19:00 00:00 5.00 0 10,751 COMPZ FISH TRIP P PU Whipstock Hook, 1 Jt HWDP, Bumper Sub, Oii Jars, Float Sub, 1 Std HWDP. RIH to 10,751' MD(strapping DP). Filled DP @ 2,515', 4,887', 8,808'. 07/16/2007 00:00 00:45 0.75 10,751 10,842 COMPZ FISH PULL P CONT RIH F/ 10751' - 10800' MD; PU SINGLE - P/U = 170K, S/O = 63K. WORK PIPE DOWN TO 10,842'. HOOK SLIDE@ 10,840' MD - OVERPULL 90K AND FIRED JARS - PULL TO 290K TO PULL FREE AND RELEASE WHIPSTOCK. MONITOR WELL - STATIC. "'* WHIPSTOCK LOCATED 2.83' HIGH "' 00:45 01:15 0.50 10,842 10,340 COMPZ FISH TRIP P POOH TO 10,340' MD. PU WT 182K. LD SINGLE TO SHED. 01:15 02:30 1.25 10,340 10,340 COMPZ FISH CIRC P CIRCULATE BTMS UP ONCE WHIPSTOCK RELEASED - 8 BPM, 900 PSI - MAX GAS OBSERVED 42 UNITS. 02:30 08:15 5.75 10,340 63 COMPZ FISH TRIP P POOH FIRST 15 STANDS MONITORING WELLBORE DISPLACEMENT (INITIAL SWABBING DUE TO DEBRIS CUP) - PUMPED DRY JOB AND PUH ON ELEVATORS WITH PROPER DISPLACEMENT TO 63' MD; CALCULATED DISPLACEMENT 85 BBLS - ACTUAL 82.75 BBLS. 08:15 10:30 2.25 63 0 COMPZ FISH PULD P LD BHA, OIL JARS, BUMPER SUB, FLT SUB, WHIP STOCK & TRIP ANCHOR ASSY. WHIPSTOCK IN GOOD CONDITION. 10:30 11:30 1.00 COMPZ CASIN OTHR P CLEAN & CLEAR RIG FLOOR 11:30 12:00 0.50 COMPZ CASIN( RURD P R!U HOOK HANGER ASSY TOOLS 12:00 1230 0.50 COMPZ CASIN RURD P P/U BAKER CASING TONGS AND TOOLS FROM BEAVER SLIDE 12:30 15:00 2.50 COMPZ CASIN RUNL P PJSM; P/U HOOK HANGER BHA AS FOLLOWS; BENT JT, SPACE OUT JTS, ECP, SPACER JTS, INNER STRING, MWD, X-O; ORIENT MWD - RIG DOWN SMALL BAKER CASING TONGS AND CLEAR FLOOR AREA. 15:00 22:15 7.25 0 10,191 COMPZ CASINC RNCS P RIH TO 741' - SHALLOW PRESSURE TEST MWD TOOLS - CONT RIH TO 10,191' MD; UD 7 STDS OF 5" DP FROM DRILL STRING TO SHED (STDS 106 - 112), P/U 10 STDS HWDP FROM SHED AND SINGLE IN VIA MOUSE HOLE. 07/16/2007 22:15 00:00 1.75 10,191 11,069 COMPZ CASIN RUNL P RIH TO 11,069' MD - TAG'A' SAND LATERAL NO-GO; PUH TO TOW @ 10,826' MD; ROTATE PIPE AND RIH - TAG SAME DEPTH (ON DEPTH WITH PIPE TALLY & CSG DETAILS). ATTEMPT ENTERING 'B' LATERAL & CONTINUE TAGGING AT SAME DEPTH. 07/17l2007 00:00 05:15 5.25 11,069 11,069 COMPZ CASIN( RUNL P Cont to attempt to go thru "B" lat window with HH assembly with no success, made 12 attempts to go thru window and rotated several times also and cont. to tag up on "A2" lat. XO at 11,069'. Decision was made to POOH and run a different bent jt. Original bent jt was 10" at 16' up on the jt, the next bent jt to be 12" at 16' up on the 't. 05:15 05:30 0.25 11,069 11,069 COMPZ CASINC OTHR T Monitored well-static, pumped dry job 05:30 12:00 6.50 t1,069 269 COMPZ CAS1N RUNL T POOH from 11,069' to HH assembly at 269', calc fill on trip out 90 bbis, actual 96 bbls. 12:00 12:30 0.50 269 269 COMPZ CASINC OTHR T Cleaned rig floor and held PJSM on LD Hook Han er assembl . 12:30 18:45 6.25 269 0 COMPZ CASINC PUTB T Cont to POOH from 269' LD HH assembly, had problems puiling the cups on the inner string thru ECP, made up 44' of add. innner string and stacked out on XO bushing, was then able to POOH LD inner st. and HH assembly. Note :jt below ECP was a 15.5 ppf while ECP is 5 1/2" 23# and on next run to change out pup jt below ECP to 23#. 18:45 19:15 0.50 0 0 COMPZ CASIN( OTHR T Clear and clean floor. 19:15 19:30 0.25 0 0 COMPZ CASIN( SFTY T PJSM on changing out Hook Hanger assembl ieces. 19:30 21:15 1.75 0 265 COMPZ CASIN( PUTB T Change out the 15.5 ppf pup below th ECP packer f! 15.5 ppf to 23 ppf. change the Bent joint from a 10" bend to 12" bend. Make up inner string w/ MWD, MU hook hanger and orient w/ MWD. 21:15 21:30 0.25 265 265 COMPZ CASINC RURD T Rig down casing tongs and clear floor. 2130 00:00 2.50 265 3,200 COMPZ CASIN( RUNL T Trip in the hole w/ the Hook Hanger asembly to 741', shallow test MWD, continue to RIH w/ Hook hanger to 3200'. 07/18/2007 00:00 03:00 3.00 3,200 11,069 COMPZ CASINC RUNL T Cont to RIH with 2nd HH assembly from 3,200' and tagged up at 11,069', same as 1 st run, st wt up 180K, dn wt 83K 07/18/2007 03:00 10:30 7.50 11,069 11,069 COMPZ CASIN RUNL T Cont to attempt to go thru "B" lat window with new bent jt and HH, cont to set down on A lat XO, est circ above and saw an increase in pressure and percentage of flow went from 20% to 13% showing good sign to be pumping below ZXP packer and blank jts on the A2 liner, cont to rotate from above the TOW to below the BOW and did not see any change in torque or any sign of tagging the window. Made numerous attempts. Discussed options with town and decision was made to POOH and MU4 1/2" BTC bentjtwith 5 1/2" XO back to 4 3/4" MWD and attempt to o thru window. 10:30 10:45 0.25 11,069 11,069 COMPZ CASIN OTHR T Monitored well-static, pumped dry job. 10:45 16:30 5.75 11,069 364 COMPZ CASIN( RUNL T POOH with HH assembly from 11,069' to 364', calc fill on trip out 90 bbls, actual fill 98 bbls. Cleared ri floor. 16:30 17:45 1.25 364 364 COMPZ RIGMN SVRG P Held PJSM then slip and cut 100' of drl line. 17:45 21:15 3.50 364 0 COMPZ CASIN PUTB T Cont to POOH from 364' LD HH assembly and inner string with MWD. Inside of the hook hanger, between inner string jt and ID of hook hanger a small piece of possible Hydril rubber was brought to surface with the hook hanger. Also small metal shavings were recovered as well. 21:15 22:00 0.75 0 0 COMPZ CASIN RURD T R/D casing tools, Clean and clear rig floor. PU tools from the beaver slide for next run. 22:00 22:15 0.25 0 0 COMPZ CASIN( SFTY T PJSM on PU/MU BHA#9. 22:15 23:00 0.75 0 65 COMPZ CASIN PUTB T PU/MU dummy run BHA#9. Made up the 12" bend bent joint of 4.5" L-80 BTC casing with a 4.5" x 5.5" BTC x-o, xo (5.5 LTC x 5.5" BTC), x-o (3-1/2" IF x 5.5" LTC), nm float sub, DM han off collar, TM han off collar. 23:00 23:30 0.50 65 65 COMPZ CASIN OTHR T Install MWD probe. 23:30 23:45 0.25 65 550 COMPZ CASIN RUNL T RIH dummy bentjtw/ MWD assembly on 5 stands of 5" drill i e. 23:45 00:00 0.25 550 550 COMPZ CASIN( OTHR T Shallow test MWD tools. Pumping 338 gpm w/ 650 psi. aquired good toolface and ood detection. 07/19/2007 00:00 04:45 4.75 550 10,734 COMPZ CASINC RUNL T Cont. to RIH with BHA #9 from 550', install 2-7" boot baskets at 634' then cont to RIH to 10,734', st wt up 170K, dn wt 83K (TOW (a~ 10,827) ! 07/19/2007 04:45 06:45 2.00 10,734 11,085 COMPZ CASIN( RUNL T Oriented bent jt to 4 left of high side ( pumping 313 gpm w/ 1250 psi), then shut down pumps, and RIH from 10,734', had siight loss of down wt at 11,060' and cont. to RIH with 5-SK wt dn and tagged up at 11,085' with mule shoe, sat 20K wt dn with no add. movement, PU and sat back down at the same spot, with mule shoe at 11,085', less bentjt and setting sleeve places "B" lat TOL at 11,036'. Took survey also and reconfirmed to be in the "B" lat. 06:45 07:30 0.75 11,085 10,960 COMPZ CASIN RUNL T POOH from 11,085' to above TOW to 10,770', oriented bent jt to 142R and RIH tagging up mule shoe at 11,038', no go at 11,001' putting the TOL at 10,970, reconfirmed by est. circ and saw pressure increase and flow decrease as we sat down on no go. Same as previous run. PU to above TOL to 10,960'. 07:30 09:45 2.25 10,960 10,960 COMPZ CASIN( CIRC T Pumped 35 bbl wt'd hi vis sweep (2# over MW of 8.4 ppg MOBM), circ sweep out of hole with no increase in cuttings back from the sweep, circ at 325 m, 1,400 si. 09:45 10:00 0.25 10,960 10,960 COMPZ CASINC RUNL T Monitored well-static, pumped dry 'ob. 10:00 14:00 4.00 10,960 66 COMPZ CASINC RUNL T POOH with BHA #9 to 66', LD boot basket while POOH (Had no recovery in the baskets . 14:00 15:30 1.50 66 0 COMPZ CASIN( PUTB T POOH and LD 4 3/4" MWD and 4 1/2" BTG bent jt, cleared rig floor, bent jt went in hole 12" at 16' and came out 8 1/2" at 16', re-bent 't to 11" at 16' 15:30 15:45 0.25 0 0 COMPZ CASINC SFTY T Held PJSM on MU Hook Hanger assembl with inner strin and MWD. 15:45 17:45 2.00 0 267 COMPZ CASIN( PUTB T MU Hook hanger assembly #3 with inner string and MWD and oriented same RIH to 267'. 17:45 18:00 0.25 267 267 COMPZ CASIN RURD T Rig down casing tools. 18:00 00:00 6.00 267 10,741 COMPZ CASIN RUNL T RIH w/ Hook Hanger assembly f/ the "B" lateral, on 5" drill string from 267' to 10,741' and oriented bent jt, st up wt 170K. dn wt 82K 07/20/2007 00:00 02:30 2.50 10,741 11,079 COMPZ CASIN RUNL P Oriented bent jt to 132R (3 left of actual high side) and RIH from 10,741' going thru the window with no problems, tagged up on no go of 5 1/2" BTC XO bushing at 11,044' with mule shoe at 11,085', PU and oriented hook and hooked same, unhooked and re-hooked several times to verify BOW depth, hooked hanger at 10,843', set 35K wt down, st wt up 185K, dn wt 82K. 02:30 05:45 3.25 11,079 10,822 COMPZ CASIN( OTHR P Dropped 29/32" ball and pumped down to seat, with ball on seat pressured up to 2,000 psi and ball seat blew, dropped 1 3/4" ball and pumped down to seat, press. up to 2,000 psi, then to 2,800 psi to open ECP pkr, press. bled dn to 2,580 psi, press. back up to 2,700 to inflate ECP, (took approx 0.1-0.2 bbls) pressured up to 3,500 psi to release running tool. PU to 225K and went back down a couple of times due to cups below ECP dragging then pulled free, sat dn and ck'd hook and hook hadn't moved. Top of hook set at 10,822' with mule shoe at 11,079'. 05:45 09:45 4.00 10,822 150 COMPZ CASIN RUNL P Monitored well-static, POOH 3 stds from 10,822' and hole took calc fill, pumped dry job and cont to POOH to Bakers runnin tool and inner strin . 09:45 11:45 2.00 150 0 COMPZ CASIN PUTB P POOH LD Baker running tool along with inner string and MWD. Cleared rig floor. 11:45 12:15 0.50 0 0 COMPZ CASINC RURD P RU to run LEM assembly. 12:15 12:30 025 0 0 COMPZ CASlN SFTY P Held PJSM with rig crew and Baker reps on making up and RIH with LEM procedures and the associated hazards. 12:30 14:30 2.00 0 600 COMPZ CASIN PUTB P MU "B" lateral LEM assembly with ZXP packer and inner string with the slim hole MWD RIH to 600'. Oriented MWD to LEM. st wt up 40K, dn wt 42K. 14:30 20:00 5.50 600 10,799 COMPZ CASINC RUNL P RIH with LEM assembly from 600', shallow tested MWD at 1072' then cont. RIH to 10799'. PU wt 165k, SO wt 80k. 20:00 20:15 0.25 10,799 10,890 COMPZ CASIN OTHR P Make a top drive connection, establish circutation pumping 118 gpm w/ 900 psi, then orient MWD to 137 left. RIH past the top of the Hook Hanger @ 10822'. Saw no indication of dra . 20:15 20:30 0.25 10,890 10,982 COMPZ CASIN( RUNL P RIH w/ stand #110 and make a top drive connection on stand # 111. PU ~ a ~ 07/21/2007 09:45 10:00 0.25 0 0 COMPZ WELCT SFTY T Held PJSM on changing out annular element. 10:00 14:15 4.25 0 0 COMPZ WELCT EQRP T ND riser and changed out Hydril annular element. 14:15 15:30 1.25 0 0 COMPZ WELCT BOPE T Tested new annular with 4 1/2" and 5" test jts to 250 psi low and 3,000 psi hi h, ood test. 15:30 15:45 0.25 0 0 COMPZ DRILL OTHR P Installed wear bushing 15:45 16:00 0.25 0 0 COMPZ RIGMN SVRG P Clean and inspected saver sub and checked ok. 16:00 16:30 0.50 0 0 PROD3 STK PULD P PU Baker Oil Tools to the rig floor to set whipstock and mill window f/ the "D" IateraL 16:30 16:45 0.25 0 0 PROD3 STK OTHR P PJSM on PU/MU Baker whipstock assembl . 16:45 18:30 1.75 0 143 PROD3 STK PULD P PU/MU Whipstock assembly (BHA # 10 . 18:30 19:30 1.00 143 196 PROD3 STK PULD P PU/MU Sperry MWD tools. 19:30 20:00 0.50 196 196 PROD3 STK OTHR P Upload MWD. 20:00 20:30 0.50 196 400 PROD3 STK PULD P PU/MU Baker bumper subs. Make up a stand of 5" drill pipe, then 1 stand of 5" drill i e. 20:30 21:00 0.50 400 400 PROD3 STK OTHR P Shallow test MWD. Pumping 320 gpm w/ 350 si. 21:00 00:00 3.00 400 5,038 PROD3 STK TRIP P RIH w/ BHA #10 (whipstock assembly f/ the "D" lateral . 07/22/2007 00:00 01:45 1.75 5,038 9,601 PROD3 STK TRIP P RIH with whipstock from 5,038' to 9;601' 01:45 02:30 0.75 9,601 9,671 PROD3 STK OTHR P MADD passed K-13 while RIH from 9,601' to 9,671' (9,450' to 9,520' GR de th 02:30 03:30 1.00 9,671 10,422 PROD3 STK TRIP P RIH from 9,671' to 10,203' and oriented WS to 18L while RIH, cont. to RIH at 18L and tagged "B" lat TOL at 10,422', sat down and set WS at 18L, st wt up 180K, dn wt 86K 03:30 07:00 3.50 10,422 10,332 PROD3 STK OTHR P Worked pipe to shear off from whipstock, worked pipe up to 225K and dn to blk wt and finally sheared the bolt, had good down wt and saw both bumper subs work while attem tin to shear bolt. 07:00 13:00 6.00 10,332 10,391 PROD3 STK WPST P Milled window in 9 5/8" csg in the "D" lat sand from 10,332' to 10,348' (16'), cont to mill to 10,391' MD/ 3,698' ND. (59' total with 20' of gauge hole). Milled at 2-5K WOM, 90-100 rpm's, off btm torque 9K ft-Ibs, on btm 9-12K, milled window at 385 gpm at 1,325 psi and milled OH at 450 qpm at 1,830 psi. • ~ 07/22/2007 13:00 14:30 1.50 10,391 10,391 PROD3 STK CIRC P Pumped 35 bbl wt'd hi vis sweep and circ out of hole, had 10% increase in cuttings back from the sweep, circ hole at 500 gpm at 2,100 psi, worked mills thru window while circ clean, went thru window 2x wo pump and had no dra . 14:30 14:45 0.25 10,391 10,300 PROD3 STK OWFF P Monitored well-static, POOH 1 std to 10,300' and um ed d'ob. 14:45 16:00 1.25 10,300 10,300 PROD3 RIGMN SVRG P Held PJSM then slip and cut 71' of drlg line and adjusted the brakes on the drawworks. 16:00 20:15 4.25 10,300 216 PROD3 STK TRIP P Cont to POOH from 10,300', LD 21 jts of 5" HWDP and installed jars and stood back while POOH to BHA #10 at 216' 20:15 21:45 1.50 216 0 PROD3 STK OTHR P Download MWD, lay down same. Lay down Baker BHA (Mills). Upper mill was full ua e. 21:45 22:30 0.75 0 0 PROD3 STK OTHR P Clear and ciean rig floor. Pull Wear bushin . 22:30 23:30 1.00 0 0 PROD3 STK OTHR P MU stack washer. Flush stack, function rams, reflush stack. Reinstall wear bushin . Clear floor. 23:30 00:00 0.50 0 23 PROD3 DRILL PULD P PU/MU BHA # 11 (Sperry Sun Geopilot ser # TL 129 and Security FMF 3643Z 8-1/2" bit . 07/23/2007 00:00 01:45 1.75 23 354 PROD3 DRILL PULD P Fin MU BHA #11 and RIH to 354', MU MWD and uploaded same, RIH with HWDP and 'ars to 354'. 01:45 02:30 0.75 354 354 PROD3 DRILL DHEQ P Shallow tested MWD and broke in Geo ilot. 0230 0830 6.00 354 10,391 PROD3 DRILL TRIP P RIH with BHA #11 from 354' to TOW at 10,332', PU 81 jts of 5" DP from pipe shed after MU BHA and singled in the hole, st wt up 145K, dn wt 75K. RIH thru the window with no problems then washed from 10,348' (BOV1n to btm at 10,391', washed down at 575 gpm at 2,600 psi, 60 rpm's with 10K ft-Ibs tor ue. 08:30 12:00 3.50 10,391 10,577 PROD3 DRILL DDRL P Directionally drilled 8 1/2" hole in "D" sand lateral with Geopilot from 10,391' to 10,577' MD/3,716' ND ( 186') ADT 2.3 hrs, 8.55 ppg MOBM MW, ave ECD 10.2 ppg (clean hole est. at 10.0 . Drilled thru 4 concretions for 27'. 12:00 00:00 12.00 10,577 12,270 PROD3 DRILL DDRL P Directionally drilled 8 1/2" hole from 10,577' to 12,270' MD/ 3,745' ND 1,693' ADT 7.23 hrs, no concretions 07/24/2007 00:00 12:00 12.00 12,270 14,110 PROD3 DRILL DDRL P Directionally drilled 8 1/2" hole in "D" sand lateral with Geopilot from 12,270' to 14,110' MD/ 3,776' ND (1,840') ADT 7.08 hrs, 8.4 ppg MOBM MW, ave ECD 10.2 ppg, ave BGG 150 units, max gas 377 units, no concretions. ~~ 07/24/2007 12:00 00:00 12.00 14,110 16,010 PROD3 DRILL DDRL P Cont. to directionally drill 8 1/2" hole from 14,110' to 16,010' MD/3,771' ND (1,900') ADT 7.59 hrs, ave MW 8.55 ppg, ave ECD 11.7 ppg, ave BGG 150 units, max gas 507 units. Drilled 4 concretions for 19'. 07/25/2007 00:00 12:00 12.00 16,010 17,579 PROD3 DRILL DDRL P Directionaily drilled 8 1/2" hole with Geopilot from 16,010' to 17,579' MD/ 3,788' TVD (1,569') ADT 7.54 hrs, 8. 45 ppg MOBM, ave ECD 11.65 ppg, ave BGG 300 units, max gas 477 units, drilled 4 concretions for 23'. Pumped hi vis sweep at 16,155' with no increase in cuttin s. 12:00 17:15 5.25 17,579 18,078 PROD3 DRILL DD12L P Drilted 8 1/2" hole from 17,579' to 18,078' MD/ 3,797' ND (499') ("D" lat TD). ADT 3.33 hrs, 8.5 ppg MOBM, ave ECD 11.5 ppg, max gas 277 units, drilled thru 5 concretions for 13'. Pumped hi vis sweep at 17,960' with no increase in cuttin s. 17:15 1730 0.25 18,078 18,078 PROD3 DRILL OWFF P Monitored well-static, took SPR's. 17:30 00:00 6.50 18,078 13,243 PROD3 DRILL REAM P Began backreaming out of hole to the window, BROOH from 18,078' to 13,243'. BROOH at 130 rpm's, 630 00:00 02:45 2.75 13,243 10,290 PROD3 DRILL REAM P Cont. BROOH from 13,243' to 10,388' (BOU~ pulled thru window w/no problems then POOH to 10,290'. BROOH at 120 rpm's, 620 gpm at 02:45 04:30 1.75 10,290 10,290 PROD3 DRILL CIRC P Monitored well-static, pumped 30 bbl hi vis sweep and circ out of hole, saw no increase in cuttings from sweep, circ an add. btms up and was clean at shakers, circ hole at 110 rpm's with 9K ft-Ibs torque, 630 gpm at 2,750 psi, rot wt 100K, u wt 160K, dn wt 70K. 04:30 06:00 1.50 10,290 10,290 PROD3 RIGMN SVRG P Slip and cut 87' of drlg line, serviced top drive and adjusted brakes on the drawworks. 06:00 13:00 7.00 10,290 18,078 PROD3 DRILL REAM P RIH from 10, 290' and thru the window with no problem, cont. RIH to 11,625' and lost down wt, washed and reamed down to 12,196' and was able to RIH to 12,673' when we lost dn wt again, cont. to wash and ream to btm at 18,978'. Wash and reamed down at 100 rpm's, 15K ft-Ibs torque and at 330 m at 1,400 si. 13:00 14:45 1.75 18,078 18,078 PROD3 DRILL CIRC P Pumped 35 bbl hi vis sweep and circ out of hole, saw no increase in cuttings from sweep, circ an add. btms up and was clean at shakers, circ hole at 130 rpm's with 15K ft-Ibs C~ ~ 07/26/2007 14:45 15:30 0.75 18,078 18,078 PROD3 DRILL CIRC P Pumped and spotted SFMOBM (50/50) in open hole, cut displacement short to account for pipe displacement, circ at 510 gpm at 300 si. 15:30 15:45 0.25 18,078 18,078 PROD3 DRILL OWFF P Monitored well-static, dropped 2" rabbit on a wire. 15:45 00:00 8.25 18,078 10,198 PROD3 DRILL TRIP P POOH from 18,078' to 17,868' and hole did not take calc fill, cont to POOH pumping calc fill out pipe to fin. spotting SFMOBM in open hole, POOH thru window with no problems to 10,198' 07/27/2007 00:00 01:30 1.50 10,198 10,198 PROD3 DRILL CIRC P Est circ at 10,198' at 590 gpm, 2,500 psi and hole took 20 bbls, slowed pump rate to 300 gpm and had no losses, increased to 400 gpm (9.5 bpm) and ave 1/2 bpm loss, slowed to 300 gpm at 900 psi with loss, circ btms up while est circ rate, no gas at btms up. Lost approx 30 bbls to hole while circ. 01:30 03:30 2.00 10,198 10,198 PROD3 DRILL CIRC P Displaced hole over at 10,198' (TOW @ 10,332') from 8.5 ppg MOBM to 8.4 ppg SFMOBM (60/40) with 3% 776 lubricant. Circ at 300 gpm, 900 psi, 50 rpm's with 9K ft-Ibs torque, rot wt 104K, u wt 135K, dn wt 80K 03:30 03:45 0.25 10,198 10,198 PROD3 DRILL OWFF P Monitored well-static. 03:45 09:45 6.00 10,198 354 PROD3 DRILL TRIP P POOH wet on elevators from 10,198' to BHA #11 at 354', LD 20 stds of 5" DP while POOH due to space on rig floor. Calc fill on trip out 73 bbl;s, actual fill 93 bbls. 09:45 12:30 2.75 354 0 PROD3 DRILL PULD P POOH from 354' LD HWDP and jars, downloaded MWD and LD same along with Geo ilot and bit. 12:30 13:15 0.75 0 0 PROD3 DRILL OTHR P Clear and cleaned rig floor. 13:15 13:45 0.50 0 0 COMPZ CASIN RURD P RU Doyon's 4 1/2" liner running e ui ment. 13:45 14:00 0.25 0 0 COMPZ CASIN SFTY P Held PJSM with rig crew, tong operator and Baker rep on liner running order and hazards of PU liner and runnin tool. 14:00 21:30 7.50 0 7,565 COMPZ CASINC PUTB P PU and RIH with 180 jts of 4 1/2" 12.6 ppf, L-80 BTC and Hydrill blank and slotted liner per detail sheet and well plan, ran 1 Hydraform centralizer per jt floating (178 total) and used 67 torque rings. MU Baker 7" HR liner setting sleeve on a 5 1/2" receptaclejt RIH to 7,565', st wt up 70K, dn wt 53K, MU std and rotated at 20 rpm's with 2K ft-Ibs toraue and 60K dn wt. . ~ 07/27/2007 21:30 00:00 2.50 7,565 10,400 COMPZ CASIN RUNL P RIH with 4 1/2" liner on 5" DP from 7,565' to 10,300' (TOW @ 10,332') rotated liner at 15 rpm's 4K ft-Ibs torque, st wt up 100K, dn wt 62K, cont RIH thru window to 10,400' 07/28/2007 00:00 02:00 2.00 10,400 15,575 COMPZ CASIN RUNL P Cont. RIH with 4 1/2" liner from 10,400' to 15,575' when we lost down wt. 02:00 04:00 2.00 15,575 18,068 COMPZ CASIN( RUNL P Rotated liner down from 15,575' to 16,084' at 20 rpm's and 8K ft-Ibs torque, RIH on elevators from 16,084' to 17,124' and lost down wt again, cont. to rotate liner in the hole form 17,124' and tagged btm at 18,078', PU and set liner on depth with TOL at 10,515' and shoe at 18,068', liner up wt 175K, dn wt 53K rot wt 90K, 20 r m's at 12K ft-Ibs tor ue at TD. 04:00 05:45 1.75 18,068 10,515 COMPZ CASIN( OTHR P Dropped 29/32" ball and pumped down to seat, pressured up to 3,000 psi to release from the liner, set 50K wt down then PU to 160K and was released from liner, pressured up to 4,250 si and blew the ball seat. 05:45 06:45 1.00 10,515 10,515 COMPZ CASIN CIRC P Monitored well and well was U-tbg, circ btms up to even mw in and out at 8.45 , circ at 250 m at 450 si. 06:45 07:00 0.25 10,515 10,515 COMPZ CASIN OTHR P Monitored well- static. 07:00 10:30 3.50 10,515 30 COMPZ CASIN RUNL P POOH with Baker running tool from 10,515' to 30' 10:30 11:30 1.00 30 0 COMPZ CASIN( PUTB P POOH & LD running tool and cleared ri floor. 11:30 12:15 0.75 0 338 COMPZ FISH PULD P MU whipstock retrieving hook on BHA #12 RIH to 338'. 12:15 17:00 4.75 338 9,800 COMPZ FISH TRIP P RIH with retrieving hook BHA #12 from 338' to 9,800'. 17:00 18:15 1.25 9,800 9,800 COMPZ RIGMN' SVRG P Held PJSM then Slip and cut 81' of drl line and serviced to drive. 18:15 18:45 0.50 9,800 10,300 COMPZ FISH TRIP P RIH from 9,800' to 10,300' (TOW @ 10,332' , st wt u 160K, dn wt 60K. 18:45 21:45 3.00 10,300 10,338 COMPZ FISH FISH P Worked whiptock retrieving hook while washing across WS slide, hooked WS and jarred free pulling 75K over st wt then after jars hit pulled 110K over and came free after 3rd try. Monitored well-static. 21:45 00:00 2.25 10,338 8,380 COMPZ FISH TRIP P POOH with whipstock and seal assembl from 10,338' to 8,380'. 07/29/2007 00:00 02:30 2.50 8,380 338 COMPZ FISH TRIP P Cont. to POOH with whipstock and seal assembly from 8,380' to BHA #12 at 338'. 02:30 05:30 3.00 338 0 COMPZ FISH PULD P POOH from 338', stood back 3 stds of 5" HWDP then LD bumper and oil jars, whipstock slide, subs and seal assembly, cleared and cleaned rig ~ • 07/29/2007 05:30 06:00 0.50 0 0 COMPZ CASIN RURD P RU to run Hook Hanger assembly. 06:00 06:15 025 0 0 COMPZ CASIN SFTY P Held PJSM with crew and Baker reps on MU Hook Hanger assembly and associated hazards. 06:15 08:30 2.25 0 273 COMPZ CASIN( PUTB P MU "D" lateral Hook Hanger assembly with ECP packer and slim hole MWD RIH to 273' and shallow tested same. 08:30 13:00 4.50 273 10,300 COMPZ CASIN( RUNL P RIH from 273' to 10,300' 13:00 15:00 2.00 10,300 10,557 COMPZ CASIN RUNL P Est. circ at 125 gpm, 750 psi, st wt up 163K, dn wt 63K, oriented bent jt to high side and RIH thru window, re-oriented to hook and hooked same at BOW, unhooked and RIH tagging XO at 10,570' on depth, PU and rehooked hanger several times to confirm BOW at 10,348', set hook with 20k wt down and final orientaion showed to be 54R. 15:00 17:30 2.50 10,557 10,327 COMPZ CASIN( RUNL P Dropped 29/32" ball and pumped down to seat, with ball on seat pressured up to 3,500 psi to inflate packer, did not see any indication of inflating pkr, bled off press. and pressured back up to 3,700 psi to blow the ball seat and prior to blowing the ball seat saw slight indication of packer possibly inflating. PU to release from hook, worked st wt up to 30K over several times to get cups to pull thru ECP then came free, slacked back off on hook and hook was still on de th. 17:30 17:45 0.25 10,327 10,327 COMPZ CASINC CIRC P Monitored well-staic 17:45 22:00 4.25 10,327 50 COMPZ CASIN( RUNL P POOH with running tool from 10,327' to 50', calc fill on trip out 85 bbls, actual fill 100 bbls. 22:00 00:00 2.00 50 0 COMPZ CASIN PUTB P POOH LD running tool and MWD, cleared rig floor and brought LEM tools to ri floor. 07/30/2007 00:00 00:15 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, Sperry and Baker rep on MU LEM with Torquemaster packer and slim hole MWD. 00:15 01:45 1.50 0 171 COMPZ CASIN( PUTB P MU "D" lat. LEM assembly with Baker Torquemaster packer and slim hole MWD RIH to 171' and shallow tested MWD. 01:45 05:45 4.00 171 10,290 ~COMPZ CASIN RUNL P RIH with LEM from 171' to 10,290' • ~ C~ C~ 07/31/2007 06:15 11:30 5.25 COMPZ RPCOti NUND P Remove all rams from BOP's and ND BOP's - Remove from cellar. 11:30 12:00 0.50 COMPZ RPCO NUND P Start NU Tree - Hang tree and clean API Rin - Remove nuts 12:00 14:30 2.50 COMPZ RPCOI~ NUND P NU Tree - Test void to 5000 psi for 10 min - Test tree to 5000 si for 10 min 14:30 20:00 5.50 COMPZ RPCO CIRC P RU and pump 721 BBLS diesel FP with Rig pumps - Staging up from 10 spm @ 420 psi to 27 spm 300 psi - SimOps LD DP from derrick to shed via mousehole 30 std's 20:00 2030 0.50 COMPZ RPCOti PULD P BD FP Lines - RD same 20:30 22:00 1.50 COMPZ RPCOti NUND P PU Lubricator - Install BPV 22:00 23:00 1.00 COMPZ RPCOh OTHR P Flush mud pumps - mud Ines - Geo Span with water * safe surf-o - Blow down same. 23:00 00:00 1.00 COMPZ RPCO OTHR P Cont LD DP - Sim Ops cleaning mud its - 10 STDS LD b midni ht 08/01/2007 00:00 00:15 0.25 COMPZ DRILL SFTY P PJSM - Hazard Recognition LD DP 00:15 09:45 9.50 COMPZ DRILL PULD P Continue LD 5" DP via mouse hole to shed - 89 stands slick - 40 stds with super sliders (120 VWVf SS removed in the i e shed . 09:45 10:00 025 COMPZ RIGMN SFTY P PJSM - Slip and cut DL 10:00 11:00 1.00 COMPZ RIGMN' SVRG P Slip and cut 71' of drill line. 11:00 12:00 1.00 COMPZ DRILL PULD P Clean GeoSpan manifold - LD all tbg elevators, Sli s, XO, TIW & Dart Vlvs. 12:00 16:00 4.00 COMPZ MOVE OTHR P Wash OBM from floor mats, Rig Floor, Drip pans, Pollution pan under floor, Pipe racks, Draworks, Top Drive, Iron RoughNeck, Remove GeoSpan from Ri Flr. 16:00 18:00 2.00 COMPZ MOVE DMOB P Prep Rig for Move - RD Service lines & BD - PU Skate, Stairways, Geronimo Line & Landings. ** RIG OFF HI-LINE @ 1600 HRS "" ** RIG RELEASED @ 1800 HRS'" "* RDMO 1J-122 aC~. 1800 HRS ** Daily Operations Summary Report 1 J-122 6/18/2007 ~1"!~: 6%20/2007 I6/24/2007 16/26/2007 I 6/28/2007 ; 7/4/2007 i ~ RIH with 5-1/2" Liner to 12,371' MD - Unable to Rotate Liner, Prep for BOPE Test. - POOH a 6/19/2007 ~1I2(3~}~ 6/21/2007 Job: DRILLING ORIGINAL ~. ~._. . ~ , [ E: :.:.._x3 .• :. ...;o. ri..:r, a ~~ ~..- ::... ~ .~'~. ~ ,::, .: . ... : ., n a -.: , :: . .......~ .. . Moved rig from 1 J-120 to 1J-122 - Set up complexes 8~ hooked up service lines - NU Riser - Load pipe shed with 5" DP - Received water to build spud mud. ** RIG ACCEPTED AT 22:30'* I Drilled 16" hole from 3,467' to 4,086' (csg pt) monitored well & had slight flow, circ hole raising MW to 9.5 ppg, well static, BROOH 10 stds, RIH, CBU then spotted lube pill on btm, POOH 10 stds & cont BROOH to 2,706' Attempted to work csg deeper w/no success, stuck csg off btm at 3,640', circ 8 cond mud f/cmtg, cmtd csg with ! 291 bbls of good cmt back to surf., PU & landed csg on slips, cut off csg & ND diverter, made final cut on csg and ~ prep. to weld on wellhead adapter. 6/25/2007 ~ Fin RIH to Flt Collar, CBU, tested csg to 3,000 psi for 30 min, good test, drilled out shoe track & 20' of new hole to' ; 3,660', RU & attempted to perform FIT to 12.0 ppg & Leaked off @ 11.5 ppg, W.O. Orders, Drilled a total of 75' of new hole w/attemptin~ to sidetrack well. CBU, Performed FIT to 11.0 ppg EMW, cont. to sidetrack well & drilled from 3,735' to 4,086' (16" hole TD) Drilled from 4,086' to 4,847' , . U k x ~ _ / , : ~; ;%. . . F"`~": _ _ ~',.., , : ~. 'i ' ~~. ~6l~t}U7 ,I~ir~ctionatl dKidl~d i2 314' in#ermedt~t~ ~1t~ Fr'am 4,&i7 t~'°;7,~~I1' ;:; y ~ ~~~ ~ . ~ '. .:. . ±T . ,; _ .. . . ~ _ . . . . - . .. _ __^.. 6/27/2007 Directionaily drilled 12 1/4" intermediate hole from 7,211' to 9,713' j Cont to RIH f/3,544' & tagged up @ 3,968', surveyed 8~ showed to be in 12 1/4" hole, washed down to 4,023' then I cont. to RIH to 9,537', washed dn to btm & CBU, drilled from 9,721' to 10,970', worked pipe while repairing #2 , mud pump's mud cross, cont. drilling to 11,215' I~ Fin LD BHA #3, slip & cut drlg line, pulled wear bushi spotted lube pill, cont to RIH with 9 5/8" csg to 8,941' csg to ~ s 3iu~ snoe, Fin POOH & Installing supersliders on 40 stds of 5" DP, tested 9 5/8" csg to 3,000 psi for 30 min. MU 8 1/2" Geopilot BHA #4 & singled in hole 180 jts 5" DP, then RIH f/derrick to 11,634', slip & cut drlg line, RIH 8~ tagged up at 11,842' (FC @ 11,848') drilled out flt collar and drlg shoe track @ 11,917' (FS @ 11,928') 7/5/2007 Drilled 8-1/2" hole in A2 lateral from 14,213' to 15,109' MD. BROOH to 11,917' & pump Hi-Vis sweep. RIH to 14,545' 8~ pump Hi-Vis sweep - Displace well to SFOBM - POOH. Daily Operations Summary Report 1J-122 Job: DRILLING ORIGINAL 7/16/2007 17/17/2007 7/20/2007 17/21 /2007 '~Y~if2~Q7 .': ~' -" 7/2212~(}~ ~~;: . . '~;.. ~; /23/2~ ~ .~. 7/26/2007 7/30/2007 RIH from 3200' and cont to attempt to go out B lat w/Hook Hanger w/no success, POOH & LD HH assembly, PU/MU BHA #9 for dummy run 4-1/2" bent joint w/ MWD, shallow testing @ 550' midnight. Ran in "B" lat window with Hook Hanger & set same along w/ECP pkr, POOH & LD Running tooi, MU LEM assembly & RIH setting same with Top of ZXP @ 10421.8', test to 2500 psi f/5 min, OK, POOH to 10522'. i~`nRIH w/Whipstock, setting same @ 18L, milled window in "D" lat from 10,332' to 10,348' then milled to 10,391', I circ hole clean, slip & cut drlg line, POOH & LD milling assy. Pulled wear bushing & Flushed out BOP stack, ' Began MU 8 1!2" Geopilot BHA #11. ' 7/25l2007 Cont to directionally drill 8 1/2" hole in "D" sand lateral from 12,270' to 16,010' 7/~6/2Q07 " E}riNetl 8'it2" h~te f~bt~~'~~t~'t0' to 1$ #~8,`, ("D" L~# Tb} Bege~r~ M B~~~1~# fo fhe uuincfs~r BF~t~?H ~"i;~;234'. 7/27/2007 ~ Fin BROOH to TOW, Circ hole clean, RIH washing & reaming to btm, circ clean & displaced OH to SFMOBM, '~POOH to above TOW to 10,198'. -- - - --~ Page 2/2 Report Printed: 9/13l2007~ . ~ ~' ~. 1J-122 S/oited and Blank LinerDetail weu Cono~oPhillrps "A2" Sand Liner detaii ~ate: Aiaska,in.c, Rig: Supervisors: DeaHGladden/Nina Woods/SteveShultz : ~.,-~22 ~r4~2oos Doyon 141 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EqUIPMENT RUN Page 1 OD(in) nominal Max OD(in) actual ID(in) actual LENGTH TOPS [re:served~ [reserved] _: ; [resetv!edj jreseived] (reservedj :; [rese[4edj [reserved] [reservedj . :; (rese[4edj .. ....:.._ . :.....: _, :. .:. = :.. :. . . . . .. i': ~. - - - ~«:'x'': » :. ~.>: i ~ i:' Eii;:;i;?;i:;ii:i;>: ?:`.iiii: iiii:i;.,?2v,.;`;:i;i`;i ::: ~ D~S~AkVGE:f~:::.;RF~3: ;:: :.:.;;::::.:: ;::..; ;:: ;. .;: . .. :: < . ~. _ ;.: ;:: > 10959.58 , '~` : . . . ~ ` . : . : > 5" DP to Surface =_> : :::.::..: 10959.58 10959.58 0959.58 ~'" Baker Liner setting tool( Does not stay in hole) s.sa s.14 3.44 10.57 10959.58 Baker "HRD" ZXP Liner Top Pkr 7.00" X 9.&3" (SF 44K } s.31 8.43 6.32 18.62 10970.95 "RS" 7" Packoff Seal Nipple, 7.65" OD / 6.188" ID 7.65 7.65 6.188 2.85 10988.77 7.0" X 9.625" "Flex-Lock" Liner Hgr, 8.32" OD/ 6.20" ID 8.32 8.32 6.2 9.80 10991.62 Cross Over Bushing 7"X 5.5" Hyd 563 OD 7.67" ID 4.88" 6.07 7.67 4.88 1.44 11001.42 190-47 Seal Bore Ext, 5.76" OD / 4.75" ID 5.7s 5.7s 4.75 20.23 11002.86 XO- Pup - Hyd 563 5.5" b X 5.5" Hyd 521 p ID 4.97" 5.56 6.1 4.s7 3.80 11023.09 Liner pup 5.5" Fup 15.5 ppf, L-80 5.5" Hyd 521 p 5.5s 5.72 5.01 3.52 11026.89 5.5`' XO Pup Jt 5.5 Hyd 521 b X 5.5" BTCM p 5.5 s.os 4.95 1.67 11030.41 Jts 61 to 81 21 Jts 5.5" 15.5 f L80 BTCM 81ank csg 5.5 6.05 4.95 911.47 11032.08 JtssO to 60 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.5 s.o5 a.s5 43.56 11943.55 Jts 59 to 59 1 Jts 5.5" 15.5 f L80 BTCM B~ank csg s.s 6.05 4.95 43.42 11987.11 Jts 58 to 58 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.s s.os a.ss 43.37 12030.53 Jts 57 to 57 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.s s.os a:s5 43.57 12073.90 Jts 56 to 56 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.s s.o5 4.s5 42.57 12117.47 Jts 55 to 55 1 ~ts 5.5" 15.5 f L80 BTCM Blank csg s.s 6.05 4.95 42.82 12160.04 Jts 54 to 54 1 Jts 5.5" 15.5 f L80 BTCM Slotted CSg 5.5 s.o5 a.s5 43.19 12202.86 Jts 48 to 53 6 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 6.05 4.95 257.84 12246.05 Jts 47 to 47 1 Jts 5.5" 15.5 f L80 BTCM Slotted CSg 5.5 s.a5 a.s5 42.17 12503.89 Jts 46 to 46 1 Jts 5.5'' 15.5 f L80 BTCM Blank csg 5.5 6.05 a.s5 43.52 12546.06 Jts 45 to 45 1 Jts 5.5" 15.5 f L80 BTCM Slotted CSg 5.5 6:05 4.95 43.00 12589.58 Jts 44 to 44 1 Jts 5.5" 15.5 pf L80 BTCM Biank csg s.s s.o5 a.s5 43.49 12632.58 Jts 43 to 43 1 Jts 5.5" 15.5 f L80 BTCM Slotted Csg 5.5 s.o5 4.s5 43.36 12676.07 Jts 42 to 42 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 a.o5 4.s5 43.27 12719.43 Jts 41 to 49 1 Jts 5.5" 15.5 f L80 BTCM Slo#ted csg s.5 6.05 4.95 43.00 12762.70 Jts 40 to 40 1 Jts 5.5" 15.5p f L80 BTCM Blank csg 5.s s.o5 a.s5 43.51 12805.70 Jts 39 to 39 1 Jts 5.5" 15.5 f L80 BTCM Slotted CS 5.5 s.o5 4.s5 43.49 12849.21 Jts 38 to 38 1 Jts 5.5" 15.5 f L80 BTCM Blank csg s.5 6.05 4.95 38.38 12892.70 Jts 37 to 37 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.5 6.05 a.s5 43.57 12931.08 Jts 31 to 36 6 Jts 5.5" 15.5 pf L80 BTCM Blank csg 5.5 6.05 4.95 260.20 12974.65 Jts 30 to 30 1 Jts 5.5" 15.5ppf L80 BTCM Slotted csg s.s s.os 4.95 43.77 13234.85 Notes: See bftm next page for jewetry. Up Wt, 180K Dn Wt, soK ROt Wt. 100K Blk Wt. 34k Rot. Torque 12-13K • • Jt Number NUR7 of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 29 to 29 1 Jts 5.5" 15.5p f L80 BTCM Blank csg 5.5 6.05 a.s5 43.22 13278.62 Jts 28 to 28 1 Jts 5.5" 15.5ppf L80 BTCM Slotted CSg 5.5 s.o5 a.es 43.00 13321.84 Jts 27 to 27 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 s.os a.ss 43.37 13364.84 Jts 26 to 26 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg s.e s.os a.s5 43.40 13408.21 Jts 25 to 25 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 6.05 a.ss 42.56 13451.61 Jts 24 to 24 1 Jts 5.5" 15.5 pf L80 BTCM Slotted csg 5,5 s.o5 4.s5 43.35 13494.17 Jts 23 to 23 1 Jts 5.5" 95.5 f Z80 BTCM Slank csg 5.5 s.o5 a.s5 43.51 13537.52 Jts 22 to 22 1.lts 5.5" 15.5 pf L80 BTCM Slotted csg s.s s.os a.ss 43.35 13581.03 Jts 21 to 21 1 Jts 5.5" 15.5 f L80 BTCM Blank csg s.s s.o5 4.s5 43.50 13624.38 Jts 20 to 20 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.5 6.05 4.s5 43.46 13667.88 Jts 14 to 19 6 Jts 5.5" 15.5 pf L80' BTCM Blank csg s.s s.os 4.ss 257.77 13711.34 Jts 13 to 13 1 Jts 5.5" 15.5p f L80 BTCM Slotted csg s.s 6.05 4.95 43.44 13969.11 Jts 12 to 12 1 Jts 5.5" 15.5 f L80 BTCM Blank csg s.5 s.o5 a.ss 42.04 14012.55 Jts 11 to 11 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.5 6.05 4.95 43.48 14054.59 Jts 10 to 10 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 6.05 4.95 43.60 14098.07 Jts 9 to 9 1 Jts 5.5" 15.5 f L80 BTCM Siotted csg s.5 s.o5 a.s5 43.46 14141.67 Jts 8 to 8 1 Jts 5.5" 15.5p f L80 BTCM Blank csg. 5.5 s.o5 g.ss 43.39 14185.13 Jts 7 to 7 1 Jts 5.5" 15.5 f L80 BTCM Slotted Csg 5.5 s.o5 4:s5 43.56 14228.52 Jts 6 to 6 1 Jts 5.5" 15.5- f L80 BTCM Blank cs 5.5 s.o5 4.ss 43.44 14272.08 Jts 5 to 5 1 Jts 5.5" 15.5 f L80 BTCM Siotted csg 5.5 6,05 4.95 43.17 14315.52 Jts 4 to 4 1 Jts 5.5" 15.5 f L80 BTCM Biank csg 5.5 s.o5 a.s5 . 42.27 14358.69 Jts 3 to 3 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg s.5 s.o5 a.ss 43.45 14400.96 Jts 2 to 2 1 Jts 5.5" 15.5 f L80 BTCM Blank csg 5.5 s.o5 4.s5 43.44 14444:41 Jts 1 to 1 1 Jts 5.5" 15.5 f L80 BTCM Slotted csg 5.5 s,os 4.ss 42.52 14487.85 Pu Jt - 5.5" 15.5 g L80 BTCM 5.5 6.05 4.95 11.51 14530.37 5-1/2" Swell Packer OD 8.01" 7.s~ 7.91 4.95 19.46 14541.88 Pu Jt - 5.5" 15.5p g L80 BTCM 5.5 6.05 a.s5 11:43 14561.34 5.5" 15.5p f L80 BTCM Blank csg w/ end oran e 5.s s.o5 4.s5 43.23 1457277 peeled and wetded shut. Bttm o#blank off==> 94616.00 14616.00 Total Ran = 58 Blanks / 23 Slots 14616.00 120 jts in shed - 38 left out 21 Blank, 17 Slot 14616.00 TD 8.5" Hole 15,109' MD / 3,961' ND 14616.00 66 total - 5-1/2" x 8" S iral liders floatin 1 eri't 14616.00 Jts 1 thru Jt#60 and then every third jt thru 't# 78 14616.00 14616. 00 81 Tr Rings installed on Jts #1 - 81 14616.00 Tor to 10,990K 14616.00 Remarks ~~ ~ ~`. ~,~ sv~ ,.., \ f y~,~ . N,~ ~ ~ F K `~'' z ~, f ._, ~ ~ ~.R ~ ~ .i~ ~' ~,~s' ~~. ;a '.<-~~ A %~. '~ ~\~~~~ ~ ~ "" - Y ; ~a~~~z,~~ ~ ~ ~e ~ ,9'~ 5 ~ . ._/~ _^.' tiek 1 'a :'v. ~f k _ 1 . •~?c, ~ t~, ~ ~~ ~~i L ~ ~ ~ ~ ~~~ ~~~ ~'' ~ S ~ '~r'~' ~ U ` ~ .6 ~z ~~ ' ,~ `g,. ~, ~~ ,3~g~ .~~.~ ~ ..~ ~"":~~~~ ~.....:~ , ~~ ~ ~1 N . ~ ,,...,. ~. ~ `~~. "`8. : . ,; ~ , , ~ . ., , :: ' ~ <.. _ , ..,~_. . :, - a+- . ~ . ~~# . .^~~,,.-. ..,...... .. . ., .x.,>~. .,.';::.- `~,:.' , .~.: . ,u.;;. «, a:.:..._' ~K.y. '3 ,~,..,. ,ands,. ..:. ~ ..~ . . "..~~. API / UWI Surface Legal Location IField Name BU/JV Latitude (DMS) Longitude (DMS) 5002923359 11N 10E 35 ~WEST SAK Alaska 70° 15' 42.53" N 149° 31' 38.071" W Well Type Well Configuration Type Original KB Elevation (ft) KB-Ground Distance (ft) KB-CF (ft) ConocoPhillips WI (%) Development 108:72 32.01 22.39 _ > ~ .~"if.'I11P.~E~~°~,~~3I S~. .. ~.. E - ~. :-, ~ , ?~ '~. ~, 1 '` b~~.,,:.,,~~ ..._,~.k.s. .~., »v.. E' ~ d ~O~sFk~:`~t ... , ~ ;~. , y`s~' '° ~ ~J.;,~: ~. .:;.z,E,..,. . ' : .. ~ .~,~E.~u.~, ., -. ..~,,., , Description Cementing Start Date Cementmg End Date ' Welibore Name Intermediate Casing Cement _1 7/1/2007 07:30 7/1/2007 11:50 1J-122 ~~ ` Comment - See Daily Op. Log ~E~E[1'~ ~~d ~S ~, ~ ,: x ~`` : ~ ~~ i i~~" ~~ : ~~ ~ ~` ~ ,~. - ~e 3 ~ ' ~ _ a ~s - "i~~ ~~ e ,~. ~ , ~JY/~;~~~ ~ Ra~~~7 A~ F ~ \ ~~-. \~rv1` y ~ R .4 ~ f ~''.. ~~ \\\ :'z~ -ar' 2 : E ~ !':I .. ... .~.:.,.:~v ....~~,,.« .. .'..,~.._m. ,., Ee.t~,. ` i. ...•.~. .___~i::.. . . ,k,! „~,.£'~'°.~~~. ~,~...~ _...,~.:,;:... . _~ x~'~?. l~a.'6~~~~.~~`; Description Objective Top (ftKB) ~~ Bottom (ftKB) Full Return? Cmnt Rtrn ... Top Plug? Btm Plug? ~ Intermediate Casing Cover WS & Ugnu 6,777A 11,928A Yes Yes Yes ~ Cement ~ Q (start) (bbl/min) Q (end) (bbl/min) Q (avg) (bbi/min) P (final) (psi) P (bump) (psi) 'Recip? Stroke (ft) Rotated? Pipe RPM (rpm) ~ ~ 5 6 _ 6 900A Yes 30.00 No '' Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftK6) Drill Out Diameter (in) r Y= Comment ~= ~~ Dowell pumped 10 bbls of CW 100 then pressure tested lines to 3,500 psi, cont to pump 65 add. Bbls of CW 100 at 8.3 ppg and pumped 75 bbis of 10.5 ppg mudpush at 5 bpm at 500 psi:. Dropped btm plug: Mixed and pumped 366 bbls, 920 sx of Deepcrete cement at 12.5 ppg and 2.25 yield with additives, a '~ ave 6.3 bpm at 900 psi, reciprocated casing. Dropped top plug. ;• Rig displaced cement with 8.4 ppg MOBM at 7 bpm, initial pressure was 450 psi, max pressure at 7 bpm was 1,800 psi, stopped reciprocating pipe 606 bbls ;°~ \ into displacement when we lost ail down wt, had 68 bbls of cement out of the shoe, slowed to 3 bpm and pumped calc displace of 902 bbls including ? shoe ~, track and plug did not bump. Shut down with 1,600 psi, held for three minutes, bled off 3 bbls and checked floats-OK. Had good returns through out the job, ;- calc TOC @ 6,777'. CIP at 11:50 hrs. - ~; ~ e: ~. ~ , ~`~ ` ` ,, ~ ~~~ ~' .. C~ment F[u~ds & At~i i iu~ ~ .,o ~ ~° s', „ , ; ~ , ~ '° „~;~ i~I.U~~f'~~,,'R.~i,.~.~uz. ... .: .s!~'~r .,,•'~: F.. .:.: ~~~f~,«.~ :: -~~'% E~~,~~r-;..: . .. ~~ ~i~„ ,,.... - „ E ..~ . ~'~G,.. ~~ ,: \ ~~~~. y. >.~~, ~~ : ~~€~",r~.~~~ , ~,.. ,... .. ~iy ~~` :: Fiuid Type ~ Fluid Description Estimated Top (ftKB) Est Btm (ftK6) IAmount (sacks) ; Class Volume Pumped (bbl) ' `` Tail Cement 6,777.0 11,928A 920 Deepcrete 366.0 Yield (ft'/sack) Mix H20 Ratio (gal/sa Free Water (°/,) Density (Ib/gal) Plastic Viscosity (cp) Thickenmg Time (hrs) CmprStr 1(psi) ~ "~ 2 25 7 62 5 y ., dC1~ ~Y~S.. .. . ;; ~ ~'c....~, ~i , . . . >~~.... : ' _ 'x~ ,,~ a\~ 12_ 0 ~ . ... ~ ~• ' " t ~' ~ >> "~ n. ~,~ ,. , ~ ~.. ~~~~ ~ '= ... .. ..,. ... ~:~~ . .. h' Additive Type 'Concentration Conc Urlit label Antifoam D046 I 0.6 %BWOC F~ Additive Type Concentration Conc Unit label ~'i Retarder D110 0.05 gal/sk ~ Additive 7ype Goncentration Conc Unit label ~4 Fluid Loss Control D167 0.2 %BWOC Additive 7ype I Concentration Conc Unit label a Dispersant ___ D185 0.06 gaUsk E. r.~~ ~ ~ ~: ~; ~_ ~' ~ ~ ~ ~,a :~ ~ :~ ~ '~ a ~&a' ~ ~'. ~ : ~ a`~\y '' ::_ ~,a~i - ~ ~; ~y .~:" ~.-.N . ~ ~. ~` p ,y~ }~} a ~~~ .r~'w ~ yF ..4 \ ~ '',~,~ '~'ti Y::- ~i~^ ~ ~ 'h~. : `ti~'"~' "i{- ~ -: ~ ~ ~~~" ~ ~? s~:r x~ ~`~~~ ~~7-~~iii ~W~~ _.s~. 'a.~ `~ ~..xx.~~~...~. ~ ~` ~,v'a':~,~',~~ ~3 ~~~~, ~:i:.~~z\ ~ `r... ~ ~ ~ ~~~ ~~~ ~~1. ~ `Z~ ~'C:iANICAL iI~ITEGRITY :Z.:PORT - ~ ~~_~~~ ~ ~ UD ;:,.'-. : ~ : : . _G r...~~C.:~. QPER ~ FZEI.~J ~~~~. ~7-L.~ C~.~ ~~ ~~~'~,.,. ir.:.LL Pli1M$E~ ~ ~ " ~ a~ ~-- ~ ~ ~.... ~~+ F LL ~AT ~_ TD : ?~.. Casi~g: ~~~''~ Shoe: ~~;~ MD ;_.,e= : 1.~Pti Shoe: :~ 'I'VD ; ?~TD _ ?II3 TV~D TVD ; i~ a : ~' ~ ?~ ~ ~ -?'4`~ T ~,~'i ; : l Y : ~'~ ~'•! ~ -~;D'__ic • ~ZCiCQ~ ~ T~1 ; Cet ci :ole S~Le ~~~~ ~nci ; ~er~~ ~'~ ~.s,~ ~o ~~-W''~~~J ~Q3~~ ~_ ~Li=..P?~?C~y ~~i'TEGR.TTy _ p A~ZT # i rZna~us ?ress Test: _~ ; ?5 cain ; ~4 min Co~ents : ~ ~ '~ CHA N ~ C~_I.. ~ ~TEGRT'I'~ - PART # 2 ~--~~(o~ 1a~ ~ ~ . Cement Volumes :, A~t. ~~ner ; Cs~ ~-1 ~ ; DV C.~,~ ;rol to cove_ ~er=; ~.-~- v.i~~~c:~.'wJ'~~C~l L~~~~c:~C~ - ~~~~ ~~~~ _ _e~retical TOC ~-" ~~';`~1.~ - ~U~~~ f ~1~c) c~~`~e.~~ ~ ~+~~~ ~~~ i ' -_~_~.~ 1~ I (~ Cement Bond Log (Yes ar No~ ~~ ; In AOGCC Fi? e~~ CBL ~vzluation, ~ane ~.bove perfs ~ ~~~ ~3~V ~-.a` ~s~ ~ ~~m~c~C~~`~v~.. - ~ \~vJ ~' \~:~~v'~ ~`'a ~"~:.~'~e~ , ~ ~ Production Log: Type ; Evali:.ation ~ ~ ~ ~ ; ~ COI~CLJS ~ Ot~S : ' ~i. . ~ ?ar~ t ?ar~ i2 ~~ - ` - + - ~'C~+ Ye ~ V ~ (C~ - ~ - ~ /~ ~ `~ ~ . . . • 27-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-122 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 3,615.17' MD Window / Kickoff Survey: 3,643.00' MD (if applicable) Projected Survey: 15,109.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. / Anchorage, AK 99518 ~ ~ ,~ ~ ~ , Date1pC, ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~ a2~' c~ ~ o ~ ~ 27-Aug-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-122PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 28.00' MD 0.00' MD (if applicable) 4,086.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) oC. V ~ `"~ ~ ~ V 1J-122 (PTD 2070700) permissiQn to pre-produce Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, August 31, 2007 10:49 AM to: 'NSK Problem We11 Supv' Cc: Regg, James B(DC7A); 'AI{sup-Drake, Sharon K' Subject: RE: 1J-122 (PTD 2070700) permission to pre-produce Brent, Pre-producing the well was described in the permit to drill application. Provided the IA and tubing pressure tests were accomplished successfully during the completion operations so that pressure integrity was demonstrated, approval of the permit is sufficient to pre-produce the well. Your notification that the well is ready to bring on or that you have brought it on is appreciated. But as I have indicated, so long as the well is constructed and pressure tested as described in the approved permit, you already have the approval you need. If you need a copy of the approved permit, please contact Sharon Allsup-Drake in Drilling. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK Pmblem Well Supv [mailto:n1617@conocophillips.com] Sent: Thursday, August 30, 2007 6:02 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B(DOA); NSK Probtem Well Supv Subject: iJ-122 (PTD 2070700) permission to pre-produce Tom, New West Sak injector 1J-122 (PTD 207070U} is I~ing prepped for pre production. The comple#ion has a packer with a stiding steeve (CMD) above the packer. To lift the well as deep as passible, the sliding sleeve wiA be left open as the lifting point. With the sleeve open there will ~ T x IA communication. Permission is requested to pre-produce 1 J-122 with #he sliding sleeve open above the packer during the pre-production period. The pre- production period is tentatively scheduied to start later this week. If you have any questions please give me a call. Brent Rogers Problem Wells Supervisor 659-7224 8/31 /200'7 07/12/07 ~ tl~r~~~~~~r~~r~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # "~'~. ,q~~~... ~<-~' ~1~~, ~ ~ 20~7 r~l ~a5~~ ~il <? Ga,s ~+~i~~. Gvmrr~i~~i~+~ ;~,n~or~,~ 0~0'~-b~ NO. 4332 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD ~ I Log Description 1C-125 (REDO) N/A MEM INJECTION PROFILE 05105107 1 1E-31 11629042 GLS 07109107 1 1 R-20 11839632 LDL 07/06/07 1 3F-19A 11839634 PRODUCTION PROFILE 07/08107 1 2L-309 11839633 GLS 07107/07 1 1J-122 11629039 USIT 07/05107 1 2N-342 11629036 FMI 07104107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. CPAI - West Sak Updates ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 05, 2007 3:01 PM To: 'Hartwig, Dennis D' Cc: Jerome Eggemeyer; Randy Thomas Subject: RE: CPAI - West Sak Updates Dennis, As we discussed, 1. With regard to 1J-162, the requirement at 20 AAC 25.030 (~ is conduct test to a predetermined EMW, leak-off or fracture pressure as specified [and approved] in the permit. The test results must demonstrate that the integrity of the casing shoe is sufficient to contain anticipated wellbore pressures ... Jerome and I had discussed LOTIFIT procedures, i have not seen what I understand is a new procedure. The practice of 3 barrels past pump-in came from annular disposal issues where 20 AAC 25.080(e)(2) requires that the downhole disposal pressure may not exceed the downhole pressure obtained during the formation integrity test ... Actually pumping in was the requirement to clearly demonstrate what was occurring proximate to the shoe. Where AD is not planned, so long as the 030 requirements are met, FIT or LOT with 3 points past appears sufficient. Where annular disposal is planned, 3 points may not be sufficient. Proof will be when an AD application is received and is determined not to have sufficient information. 2. Stopping short of TD is not a problem. The actual depth drilled will be reported on the 407. Call or message with any questions. ~"'~ ~, -~~. a ad~-o~ c~ Tom Maunder, PE AOGCC From: Hartwig, Dennis D [mailto:Dennis.D.Hartwig@conaophillips.rnm] Sent: Thursday, July 05, 2007 2:31 PM To: Maunder, Thomas E (DOA) Subject: CPAI - West Sak Updates Importance: High Tom, I am covering West Sak for Pat Reilly over the next couple of days and thought I would update you on a few items of note. Doyon__15 - Drilling_Dual_Lat Producer 1J-162 The 16" surface hole was drilled to appraximately 3,998'MD. 13 3/8" surface casing was run and could not pass beyond 3,832'MD - the casing was cemented in place approximately 178' off boftom. The cement job went well - 226 bbfs back to surface with plugs bumped. Considering the possibility that we have 178' of open hole below the 13 3/8" shoe, we are more biased to pump longer to obtain an accurate LOT. The current plan is to obtain 3 additionat points (approximatety 3/." bbl) beyond 7/5/2007 CPAI - West Sak Updates • • Page 2 of 2 the break-over point. The initial plan afso involves sidetracking the well shortfy after drilling out the shoe. A lOT witl be conducted once it is confirmed that we have drilled ~20' of new formation. Doyon 141 - Drilling_Tri-1_at Injector 1J-1_22 ap'~ -O'1 v We have just finished driliing the lower A-lateral and will be running a USIT log across fhe intermediate casing in the ne7ct few hours. The permitted Tota! depth of the 1J-122 was 18,054'. After drilling to approximately 15,109'MD it was decided to end drilling prematurely due to water contact. Please contact me if I can provide any further information...Regards Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Office : 907-265-6862 Cell : 907-980-1433 Fax :907-265-1535 7/5/2007 1J-122 Plan Forward ~ ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Reilly, Patrick J [Patrick.J.Reilly@conocophillips.com] Sent: Monday, June 25, 2007 12:00 PM To: Thomas Maunder Cc: Thomas, Randy L; Eggemeyer, Jerome C. Subject: RE: 1.~-~22 Pt~n Forward Attachments: Patrick.J.Reilly@conocophiTiips.com.vcf Tom, ~~~-0~1~ We proceeded with option 1. We drilied 20' (below shae) and tested. The initial analysis of the test indicated an 11.5 ppg LOT. We started to drill 40' more in preparation for another LOT. While drilling the 40', you and I discussed the situation and agreed on a FIT to 11.0 ppg. We performed a new test FIT and based on a cantinuing straight line build of pressure (i.e. psi/strake pumped), the interval did not break down and we achieved an F17 of 11.0 ppg. We have reviewed the initial 11.5 ppg LOT and have determined that the data was not adequate to declare 11.5 ppg because the last point on the test showed an increasing psi/stroke pressure build (not consistent with typical leak off rollover). Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J.Reilly@conocophillips.com From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 25, 2007 7:59 AM To: Reilly, Patrick J Cc: Thomas, Randy L Subject: Re: iJ-122 Plan Forward Pat, This confirms our discussion on Saturday morning regarding the plan forward for 1J-122. As I understand you were proceeding with option 1. Please message back as you have further information. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 6/22/2007 5:11 PM: Tom, Thanks for discussing this well earlier today. We have completed our cement job and have cement to surface. Our plan forward is as follows: 1. Sidetrack 70 left out of the shoe per directional plan 7/2/2007 1 J-122 Plan Forward ~ ~ 2. Drill 20' of new hole 3. Perform FIT to 12.0 ppg If sidetrack fails 1. Clean out rat hole (do not drill 20' of new hole) 2. Perform FIT to 12.0 ppg 3. Drill ahead ~ Please call me at the numbers below or at home at~~~ if you wouid like to discuss. Thanks. ~.• \ Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (918) 662-8284 FAX TO E-MAIL F'atrick,_J. Rei_I#y_~canocophiNlips.cc~r~ «Patrick.J.f2~illy a~conocophillips.com.vcf» Page 2 of 2 7/2/2007 RE: 1J-122 Again ~ + I Subject: RE: 1J-122 Again From: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com> Date: Mon, 11 Jun 2007 10:15:25 -0800 To: T'homas Maunder <tom maunder@admin.state.ak.us> Tom, The LEM is tested to 2500 psi for 30 minutes if the well is an injector and it is the uppermost LEM. I will change future permit applications to reflect that instruction. I apoloqize for the dimension discrepancy. The TVD of the Ll window is supposed to read 3787 as you noted below. 3969 is the TVD for the intermediate casing. 3787 is the value indicated on the Halliburton paperwork and the Baker Oil Tools schematic. Thanks. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 GELLULAR (918) 662-8284 FAX TO E-MAIL Patrick.J.Reilly@conocophillips.com -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Sunday, June 10, 2007 2:33 PM To: Reilly, Patrick J Subject: Re: 1J-122 Again Pat, Would you please check the tvd on the L1 window. The tvd listed on the permit sheet is 3969 which is the same as the tvd of the casing shoe. Looking at page 3 of 8 of the Halliburton document it would appear the the correct tvd is 3787 at 10779.8 md. Would you please confirm? Thanks, Tom Maunder, PE AOGCC Thomas Maunder wrote, On 6/10/2007 2:07 PM: Pat, One quick question. When the LEM is run in step 38, is the casing x DP annulus tested at that time? If so, that is an instruction that should be mentioned. Call or message with any questions. Tom Maunder, PE AOGCC > 1 of 1 6/l l/2007 1:08 PM ~ ~ i.l ~ ~ ~ ~ ~ SARAH PAtIN, GOVERNOR CO~8~71~~ ~~ ~ I~ 333 W. 7thAVENUE, SUITE 100 r+ ~Z~OJ~ ~iai~~~~ ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 Randy Thomas F~ t90~f 2~easa2 Drilling Team Leader ConocoPhillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-122 ConocoPhillips Alaska Inc. Permit No: 207-070 Surface Location: 1837' FSL, 2347' FEL, SEC. 35, T11 N, R 10E, UM Bottomhole Location: 318' FSL, 422' FEL, SEC. 24, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtai~ing 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). DATED this /7iday of June, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~ STATE OF ALASKA ~ " "`~~~~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSIO~~ I~ J MAY 2 5 2007 PERMIT TO DRILL 20 AAC 25.005 Ataska pil ~ Gas Cons. Comm~ssion 1a. 7ype of Work: Drilt ^~ • Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ~ Stratigraphic Test ^ Service Q/ ~ Development Gas ~ Multiple Zone^ Single Zone ~ 1c. Specify if well is pro . Coalbed Methane ^ 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: 1J-122 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 18055' • ND: 3990' • 12: Field/P001(s): Kuparuk River Field 4a. Location of Well (Governmental Section): SurFace: 1837' FSL, 2347' FEL, Sec. 35, T91 N, R10E, UM ' 7. Property Designation: ADL 25661 & 25650 ~ West Sak Oil Pool . Top of Productive Horizon: 636' FNL, 315' FEL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 6/18/2007 Total Depth: 318' FSL, 422' FEL, Sec. 24, T11 N, R10E, UM . 9. Acres in Property: 2560 14. Distance to Nearest Property: ~1 mile a~., 4b. Location of Well (State Base Plane Coordinates): SurFace: x- 558863 ' y- 5945649 + Zone- 4 10. KB Elevation (Height above GL): 1 OJ' RKB feet 15. Distance to Nearest ~Netl withi~ Pool: 1J-f 09 , 9 osao' ~ 1711 16. Deviated wells: Kickoff depth: 300' '~• Maximum Hole Angle: 99° deg 17• Maximum Anticipated Pressures in psig (see 2o AAC 25.035) Downhole: 1803 psig • Surface: 1362 psig . 18. Casing Program S if ti Setting Depth Quantity of Cement Size peC iCa ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) 40" 20" 62.5# H-40 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 16" 13-3/8" 68# L-80 BTC 4164' 28' 28' 4204'. 2265' ' 770 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 11778' 28' 28' 11818' • 3969' - 900 sx DeepCrete 8.5" 5.5" 15.5# L-80 BTCM 7175' 10879' 3805' 18054' ~ 3990' • slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structu ra I Surface Intermediate Production Liner PerForation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee Q BOP Sketch ~ Drilling Program Q Time v. Depth Plot Shallow Hazard Analysis / Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q/ 20 AAC 25.050 requirements ~/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt Pat Reilly @ 265-6048 Printed Name Ran~d-~ Thomas ritie Drilling Team Leader Signature ~~( JG~ s~ /~ f Phone Date ~ 2/~ ~ ~ ~r~ • ~ ~ l h nAll k Commission Use Only Permit to Drill Number: ~7-- Q"?b API Number: 50- ~Z,g- 2335~ ~ Permit Approval ~ate: See cover letter for other requirements COnditionS of appfoval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydr or gas contained in shales: ~ ~~"~~ ~,~~,,`~ ~v~~~~t<~ ~ Samples req'd: Yes ^ No ~ d og req'd: Yes ^ No [~ Other: ~~~ H2S measures: Yes ~ No D' ctio svy req'd: Yes [~ No ^ ~+~c ~~ ` '~E'S~"~ ~~-i.1~..G~ ~ ~ti~~ h.S / Q ~~ ~ 3~ ~ ` _. ! APPROVED BY THE COMMISSION DATE: ~ w" ~~D~ , COMMISSIONER e7 Form 10-401 Revised 12/2005 ~ ~"~ ~ ~ ~ ~~4 ~ ~ V ~. ~t- Submit'n Duplicate 1E t /13~~~ ~A t' 3~. C'T / C~1'lOCO ~'11 ~ ~ 1 S p Alaska Post Office Box 100360 Anchorage, Alaska 99530-0360 Randy Thomas Phone (907) 265-6830 Email: Randy.L.Thomas@conocophillips.com • R~~~~vEo MAY 2 ~ 10~'i May 24, 2007 Alaska OiM & Gas Cons, C~mmission An~hora~~ Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Injector, 1J-122, 1J-122L1, iJ-122L2 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Driil for an onshore injection well, a trilateral horizontal well in the West Sak ~~A2", °B" and °D" sands. The main bore of the well will be designated 1J- 122, and the lateral bores of the well will be designated 1J-122L1 and iJ-122L2. Please make note of the additional text in bold in steps #40, 45, and 46 of the Drilling Program. These steps address the pre- production period prior to injection. Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for this well bore. The expected spud date of iJ-122 is June 18, 2007. If you have any questions or require any further information, please contact Mike Greener at 263-4820. Sincerely, ~: ~ ~ ~ ~ ~ ~ ~~//?it4 ~~~~ ~ ~~ ~f r s Randy Thomas / Greater Kuparuk Area Drilling Team Leader • ~ation for Permit to Drill, We11 1J-122 Revision No.O Saved: 23-May-07 Permit It - West Sak Well #1J-122 Application fo~ Permit to Drill Document „~ r.w #k r.i'~. f~la~cW~ll r.~ax~m~~~ 1M~II VQlue Table of Contents 1. Well Name ................................................................................................,................. 2 Requirements of 20 AAC 25.005 (fl .......................................................................................................~..... 2 2. Location Summary ........................................................................... ............ 2 .............. Requirements of 20 AAC 25.OOS(c)(2) ...........................................................................:............................, 2 Requirements of 20 AAC 25. 050(b) ............................................................................................................. 3 3. Blowout Prevention Equipment Information ............................................................... 3 Requirements of 20 AAC 25.005(c)(3) ......................................................................................................... 3 4. Drilling Hazards Information ..................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ........................................................................................................ 3 5. Procedure for Co~ducting Formation Integrity Tests .................................................. 3 Requirements of20AAC25.005 (~)~S~•-•-• ..........................•--•---................................-•-•--............................ 3 6. Casing and Cementing Program ..............................................................................:.. 4 Requirements of 20 AAC 25.005(c)(6) ......................................................................................................... 4 7. Diverter System Information ...................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ......................................................................................................... 4 8. Drilling Fluid Program ............................................................................................... 4 Requirements of 20 AAC 25.005(c)(8) ..................................................................................................... m... 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) ............................e.....................:.,............................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .............................................,...... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) ........................................................................................................ 5 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ........................................................e............................................. 5 11. Seabed Condition Analysis...........~ ...................................................................:........... 5 Requirements of 20 AAC 25.005 (c)(11) .................................................................................................•--.- 5 1J-922 PERMITIT Page 1 of 8 ~ ~ ~ ~ ~ ~ ~ ~ Printed: 23-May-07 . A~on for Permit tobrill, Well 1J-122 Revision NoA Saved: 23-May-07 12. Evidence of Bonding .................. ..................................................................... ... 5 Requirements of 20 AAC 25.005 (c)(12) .........................................:............................................................ 5 13. Proposed Drilling Program ......................................................................................... 6 Requirements of 20 AAC 25.OOS (c)(13) ......................................................................................:............... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. ? Requirements of 20 AAC 25.005 (c)(14) .....................................................................................................: 7 15. Attachments ............................................................................................................... 8 Attachment 1 Doyon 141 West Sak 2004 3ksi BOP Configuration ................ Error! Bookmark not def-ned. Attachment 2 Directional Plan .......................................................•---:...................................-•-•-•--=•---•-~--- 8 Attachment 3 Drilling Hazards Summary ...............................................................•--•----•---........................ 8 Attachment 4 CemCADE Summary ............................................................................................•-•-•-•-•-•-•••-• 8 Attachment S Well Schematic ..................................................:................................................................. 8 L We11 Name Requirement.s of 20 AAC 25.005 (fl Zi'ach well m'ust Ue irlenti,fi~ d by~ a unzyue nanze desfgnated by the operator anc! a unic~zre ~IPI nzrmber asszgned by= the corrzrnfssicrn under 20 AAC ZS:Q¢(1(fij.1~'~t• a rvell wrtli i^rau(tiple well firaraclzes, eaeh ht-anch must sfrnilarlv he identi}iect by a ta~azyue rscnrie arad ~2Y1 nu~riGer hy addirtg a.su~x to the narnQ designafed for tlze we111ry tlze oper•ator and to tJt~ nuirzber• a,rsigned to dhe ~well bv dhe commissio~2. ~ ~ ~~ The well for which this Application is submitted will be designated as 1J-122. 2. Location Summary Requirement,s of 2D AAC 25.005(c)(2) ~ta a~placadfon for• a PeYmzt to 1~~-ill rraust be accomf~crraied l~y eacli of tlJ~e foll~nt~ir^ag ztetras, e:rcept.f~r- an ifiem ak'eacly ort file wilh tJie coromessiora ~ ~~~~ ~ c~rzd iden~ti~rcl irt the ap~jlication: ~ ~ (,'1 a~IaP zc~entifi~ing the ~~roperZy arrd tbre pro~~ert}~'s owners ~~nd slaowirag (A)the coorctzncates of tfae pr~a~~see~ locati~n nf the well at tF~e,s~rrface, at the top r1f each ofijectzve formc~tion, ~atad at tntal dc;pt&, refer~~eracec~#o ~ ~~~~ ~ ~ P,{ltiC'371Yi1f'32lLIl J'{?CZI(J31 1i71L'S. . ~ ~ ' . . ~ {I3) tlie c~ordinntes ~ft'r,e~roposec! dacarzon of the xvell rzt the.ruF f"ace, referenced to 1{~te statE plan~e c~ordinate systtim for tlais.state as ertiixtnirred ~ ~~ b,v the Ncrtional Cieoc~etic Su~-vey in ttrt National C3ceantc rrnd Atrrms~aheric Adrnir~istraLion; (C) the prc'r(~~secf ~~IepYh of'tS~e ti+;edt a[ Ylse top of'each ohjective forrraati.o~2 and at tota! d~pt72; ~ ~ Location at Surface 1837' FSL, 2347' FEL, Section 35, TllN, R10E ' .4SP Zone 4 N,4D 27 Coordinates ~ RKB Elevation 109' AMSL ` Northings: 5,945,649 Eastings: 558,863 Pad Elevation ~ ~ 81' AMSL ~' Location at Top of Productive Interval (West 636' FNL, 315' FEL, Section 36, T11N, R10E Sak "A2" Sand) ~ ASP Z e 4 NAD 27 C di Measured Depth, RKB: ~ ll,819 on oor nates Northin 948 517 Eastin s: 5 s: 566 149 Total Vertical Depth, RKB: 3,969 g , , g , Total Vertical Depth, SS: 3,860 Location at Total Depth 318' FSL, 422' FEL, Section 24, T11N, R10E , 4 NAD 27 C ASP Z di Measured Depth, RKB: 18,055 i o~e oor nates No~thin 954 749 Eastin s: 565 s: ~ 5 988 Total Vertical Depth, RKB: ~ 3,990 / g , ~ , g , ~ Total Vertical Depth, SS.• 3,88] ~ 1J-122 PERMIT IT ~g Page 2 of 8 . (~ ~ ~ ~ ~ ~ ~~ ~ ~ Printed: 23-May-07 ~! ~ ~ication for Permit to Drill, Well 1 J-122 Revision No.O Saved: 24-May-07 ancl ~ (I?) oCher inforrnat;'on r-equ;'recll~i~ 20f1AC 2S.(JS(J(n); ~ ~ Requirements of 20 AAC 25.050(b) If u tvell is to be iratentionally ctevi~zterl, tlxe czpplicatiUn for a Pennit to ZJrill (Frrrm 1f1-=SfJl) mt~st (1) itaclzede a plat, drau~n to a sarztahle scale; showing tFze path r3f'the proposed ivellhr~re, irrcludirag a1l adjacenL wellbores ivrtlain 200 feet of az2y ~~nrtzon Uf the pto~oced tivell; ~ ~ Please see Attachment~ l: Directional Plan ~ ~ ~ ~ ~ ~ an~l (2j f~}r call wella~ ~viiFtin 2(lt),fc:et of thc; prr~ptssc:d wellbore (~~) 1isC lhe ncatra~s~ nI'tlae o~er-utors oJCd~ore welt,r, to the extenz that t6a~sr: nc~mes clre knn~vn ~~r di,rcUVerable in publfc recor~ic and el~ow that each narrtecl oPerazon c~zs beEn furnishe~d a cn~?y of~Zhc: ~ppZication by certifieel trtail; or ~~ ~ (B) state th~zt fhe appZicani is tTte orzlY affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) ~ ~ _An czpplieaiion for c~ Perrrait to 1?rrll must be accorry~anred by each r~f'the, followang items, exce~t f'or ura zt~m czZready on file u~ith the corranaission and itleniifiec~ in the appllccztii~rt: {3) a clia„ram ttrad de.scriptiort ~f tEae bfo~rtzrt pr~evention equiprlaent (/30PE") as required fiv 2El ~~C' 25.03_S, 2(I ~1C 2~.036, or 20 t2~?C 25.03? C!S Ujljl~TC.U~?lE'~; . . ~ ~ . . ~ An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-122. Please see information on the Doyon Rig 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An ap~rlicczti~n,Jor a Pertnil to Dril( mus~t be ucr.otnpaniec~ ~ry e<arh of ~the f~lloivrng i?em.s, excepLfor an iter7t alreudy pn flde wit/s the c~trunission and irletzfiifietl in the a~~lica~iort: ~ ~ (4) informadzora ~n drillirag hcazarcls, inctudin~ ~~ (-A) the rtuxxirrrutrt do~vtihole pressupe thc~t may be encor~ntered, critet-tez used lo determine it and mezxin2urra poteniial surface ~resstare based orx u methtrne gt•ac~ier~t; The expected reservoir pressure in the West Sak sands in the 1J-122 area is 0.45 psi/ft, or 8.6 ppg EMW (equivalent mud weight). ~"'" -- The maximum potential surface pressure (MPSP) Based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak A2 sand formation is 1,362 PSI, calculated as follows: The MPSP is: MpsP = (4,00~ r~~~o.4s - o.ii ps~~t~ =1,362 psi (BJ daata on poterrfial gas zr~nes; The well bore is not expected to penetrate any gas zones. cxrad (C) data concerning poter~tial eczuses of hote problerr~,s such as abnorinallv geo-~ressts~ed str•ala, lost cirezada[ion ~anes, and zanes that h~2ve a propt•nsity fc~r di~ferentic~l.riickit2g; Please see Attachment 2: 1J-122 Drilling Hazards Summary. 5. Procedure for Conducfing Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) ~4n capPlzcation for ca Permat to DNill must be accr~rnp~znietd by= ench ~fthe falXowzng items, except for an iren2 alreudv on file ivath the cc~rrzinissfon and itlertt~etl in the applicnfi~tz: ~ ~ ~ ~ {3) a~~aecriptiort af the procecTure for conductit2g formation u2tegrity te.sts, czs reqztired under 20.4AC 25. ~30(~; 1J-122 PERMIT IT Page 3 of 8 printed: 24-May-07 ~ ~ ~ ~ ~ ~~ ~ ~ A~ion for Permit to Drill, Well 1J-122 Revision No.O Saved: 24-May-07 1J-122 will be completed with 9-5/8" casing landed at the top of the West Sak "B" sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the "Formation Integrity Test Procedure" that ConcocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c) (6) An applieaiivn for a Pernsit to I~rill rmrst be ~rcc•ompanu~d by eur:h of the Jo?Iniving iterrzs, exeet~t,for can item a?r'ea~Iy on fite =rJilh t~te eonsnsirsiota c[rat7 ide~nti~ed itz the applicutior: ~ ~ ~E~) a complete pr~posed casittg an~ cementittg prooram as req2tzred by 2Cl fLAC 25.P3D,, and ~a desct•z~tion of `any slotted linet; ~rz-~etfr~t-atGd ~~~ tzner, or• screert fo b~ ir;stnlfecl,• Casing and Cementing Program ~ Hole Top Btm ~^~aa Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) ~(in) (Ib/ft) Grade Connection t) (ft) (ft) Cement Pt^o ram 20" 40" 62.5 H-40 Welded 80 28' / 28' 80' / 80' ~ Cemented to surface with 260 cf ~ ArcticCRETE Cemented to Surface with 13-3/8" 16" 68 L-80 BTC 4,164 28' / 28' 4,204' / 2,265 ~ 770 sx ArcticSet Lite I,ead, 220 sx Dee CRETE Tail Cement Top planned @ 6,750' ~ 9-5/8" 12-1/4" 40 L-80 BTCM 11 778 28' / 28' 818' / 3 969' 11 MD / 2,860' TvD. Cemented , , , w/ 900 sx Dee CRETE 5-1/2 . SlOtted~ 8-ll2" A2 Sand ~-Lateral(1Y122) 15.5 L-80 BTCM 7,175 10,879' / 3,805' 18;054' / 3,910' Slotted- no cement ~"4= slotted 8- " B Sand I,ateral (11-i~~Li> 11.6 L-80 BTC CSG 7,260 10,779' / 3,969' 18,039' / 3,845' Slotted- no cement ~ ~ 4-1/2 8-1/2" D Sand Lateral 11.6 L-80 BTC CSG 7 663' 10 368' / 3 701' 18 031' / 3 778' Slotted- no cement slotted (11-i~~ L~~ , , , , , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) Ara a~~ulzcat~orz, fcrr^ 01'etmzL to Drill naust 1~~ czccc~mpctnie~ by eadz of tlte f`ollutit~ira~ zierns, ea cept fot- an item already on fzle witlt thc commzs.rir~n and identifieci i~a the appltccatfon: (7) cz cltagrarn and ilescriFriir~n of the diverter system as requi~-et/ hy i0 ~4AC 25. f135, utzless tlais r•equiresnetad is :waived by the corrtrrtission uniler 20 ~~AC 25.035(hJ{2); ~ ~ A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1J- 122. Please see diagrams of the Doyon 141 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c) (8) An ap~~licataora fo~' a Perrnii tc~ Drill must be aer.nm~unied hy eacdz qf'th~ f'ollowin~ itesns, except for an iterra aZrcady on file ;vii{i f'he comrnzssion and idei~aEified in the a~~}~lica~tinta: ~ ~ ~ : : p,s._, . ~_ . (8) a tlrillzng, f~uid program; iraelarding a diagrurre crrad deseriptzorz of tlae c~t-rlZrng fluid sYStem, ~zs rer~uired by '0 _4.~C ?_S. (}g~,' " '` ` Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base ofPermafi°ost Base ofPermafi~ost to Surface Casing Point Initial Value Final Value Iraitial Value Final Palue Densiry (pp~ $.5 9.2 9.2 9.6 Funnel Viscosiry 150 250 200 300 (seconds) ~ ~ Yield Point ~ (cP) 50-70 50-70 30-50 30-50 `C~~~~~~ ~F~~~: / 1J-122 PERMIT IT Page 4 of 8 Pnnted: 24-May-07 ~ ~cation for Permit to Drill, Well 1J-122 Revision No.O Saved: 25-May-07 Plast~c Viscostiy ~ 20-45 20-45 15-20 15-20~ (lb/100 s~ pH 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 gPlFiltrate ~ ~ NC-8 0 ~ NC-8 0 5 0-7 0 ~ 5 0-7.0 ~ (cc /30 min)) . . ~ . . . *9.6 ppg if hydrates are encountered Intermediate Hole Mud Program (LSND) 10-3/4" Casing Shoe to Intermediate Casing Point ~ ' Initial T'alue Density (ppg) 9.0-9.1 Funnel Viscosity 45-60 (seconds) ~ Plastic Viscostiy ~ ~ 12-18 ~ (lb/100 s~ ~ ~ Yield Point 26-35 ~ ~~P~ API Filtrate 4-6 (cc / 30 min)) Chlorides (m /l) <500 pH 9.0-9.5 MBT <20.0 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals Value Densi (ppg) 9A ~ Plastic Viscostiy ~ ~~ ~ 15-25 (lb/100 s~ YieldPoint ~18 28 ~ ~ (cP) ~ HTHP Fluid loss (ml/30 min @ <4A 200psi & 1 SO° Dil / Water Ratio 80:20 ~ Electrical >600 Stability s Drilling fluid practices wi11 be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 14 L 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9J ~ !ln application for cr 1'F~~rnit to PYill must be accort2panied by eczch of the followzng idem~s, ercept fc~r an item calreaclv ot~ file witt~ the c~~rrarr~aissian anciidenti~iecd in t~he ay~~ticatit~ra: ~ ~ ~ ~ (9J Fot° an ~xp7orcrtorv or sdreatigra~hic test well, a tab2rlc'e~zon sedtita~ out the depths qf prec~icter~ afinarmally geo ~ressured c~h^ata as Pequirecl 1>y ?~ ,4,~C 2 ~.G33F1}1 Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25. 005 (c)(10) .4n ap~lic~ati~n f~r a Peranii t~ Z)rill must be uce~mf~anied I~y each qf the fntFoti~~ing itemc, e~aept fc~r rxn itern rxlready ~n jile wiih the c:ornmisszon and ideratifrerl t`ra the a~~plrcafiont (70) for rrta ex~loraivey ar a~tratibrapFtic test weld, a seismic refi~ action or reflection ar~talvsis as required Iry 2(I 2~~C' 25.OS1(a); Not applicable: Appiication is not for an exploratory or stratigraphic test we1L 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An appfictafa~n far u Perrrait to L)rill must be aec~tnpanied by each of the ft~llowing items, exce~t, f'or an item c~Zreadv an~ fcle witGr Lhe cot~zrrtission ~ ~ unct identifiec! in the apr~liccttiofa: (IIJ for ca ~vell drilled from ara nff,shorr; ~~lcatf~tvn: mobile fiottam-Jouvtc~ecl structztre, jack u~ rig, ~jr flacating cL^i/ling vc:s.sel, ara anc~lysis ~f seufied ~ c<3raditions ras reyuired fiy 20 AAC lS.t1C~~1(h); Not applicable: Application is not for an offshare well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) .4r2 ap~alication fr.~t^ a Pennit to -rzll ntust hc act.~m~anie~l by e~zch qf tl2e follox~ing iiems, except fot- an iPern already on file.wii{a the cnmrnis,sion and idefs/ifzed in the application: ~ ~ ~ (72) tvidence showing that the requfr•erraents of ZO f1~2C 25.O25 {Bonr~dng,}have bezn met; 1J-122 PERMIT IT.doc Page 5 of 8 Printed: 25-May-07 ~n~nl~~ ~ I ~ A~ion for Permit to Drill, Well 1 J-122 Revision NoA Saved: 25-May-07 Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. -13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An applieation fi3r u Permit to Dr-zTl mirst t~e accot7zpfxrzir:d by erxeh of the fn?lc~ltiing iteeras, exeept f«r a~a item a?recafly on~le vriih the com~nissiati cand i~dentified in the ~pplicatfon: ~ ~ ~ The proposed drilling program is listed below. Please refer also to Attachment 5, Well Schematics. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 108' RKB. Install landing ring on conductar. 2. Move in / rig up Doyon Rig 141. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 4,204' MD / 2,265' TVD as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi) Notify AOGCC 24 hrs before test. 6. PU 12-1/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Pressure test casing to 2500 psi for 30 minutes and record results. 7. Dri11 out cement and between 20' and 50' of new hole. Perfo~n formation integrity test to leak off, recording results. 8. Directionally drill to 9-5/8" casing point at 11,818' MD / 3,969' TVD, the prognosed top of the B sand. 9. Run Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,750' MD, 500' above the Ugnu C ~ 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. ~~~ 11. F1ush 13-3/8" x 9-518" annulus with water, followed by dieseL 12. PU 8-1/2" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Pressure test casing to 3,000 psi for 30 minutes and record results. 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation ~h integrity test to leak off, recording results. , ''~~~~ 14. Directionally dri118-1/2" hole to TD at +/- 18,054' MD / 3,990' TVD as per directional plan. ~ 15. POOH, back reaming out of lateral. POOH. 16. Run USIT log for cement bond. 17. PU and run 5-1/2" slotted liner. 18. Land liner, set liner hanger @+/- 10,879' MD / 3,805'. POOH. Note: Remaining operations are covered under the 1J-122 Ll Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of 10,779' MD / 3,787' TVD, the top of the "B" sand. 20. Mi118-1/2" window. POOH. 21. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. ~ ~~ ~~ ~ ~ 22. Drill to TD of "B" sand lateral at 18,039' MD / 3,845' TVD, as per directional plan. 1J-122 PERMIT lT.doc ~ Page 6 of 8 ~ ~ ~` ~ ~"u. ~ Printed: 25-May-07 ~ ~ 1 ~,..~ ~ ~ 1~ ~" ~.... ~ 23. POOH, back reaming out of lateral. POOH. 24. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 25. PU and run 5-1/2" slotted liner. ~ication for Permit to Drill, Well 1 J-122 Revision No.O Saved: 25-May-07 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. Make up junction isolation / re-entry assembly (Lateral Entry Module ar LEM) and RIH to depth. Orient and set. packer atop assembly and release from assembly. POOH. Note: Remaining operations are covered undeY the IJ-122 L2 Application for Permit to Drill, and are provided here for information only. 29. Run and set Baker WindowMaster whipstock system, at window point of 10,368' MD / 3,701' TVD, the top of the "D" sand. 30. Mill 8-1/2" window. POOH. ~ ~ ~ 31. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. ~ ~ 32. Drill to TD of "D" sand lateral at 18,031' MD / 3,778' TVD, as per directional plan. 33. POOH, back reaming out of lateral. POOH. 34. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 35. PU and run 4-1/2" slotted liner. 36. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 37. Release hanger running tool. POOH. 38. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 39. POOH, laying down drill pipe as required. 40. PU completion as required and RIH to depth. Run CMD sliding sleeve in open position for gas lift during injector pre-production period. Land tubing. Set BPV. 41. Nipple down BOPE, nipple up tree and test. Pull BPV. 42. Freeze protect well with diesel by pumping into 4-U2" x 9-5/8" annulus, taking returns from tubing and allowing to equalize. 43. S~t BPV and move rig off. ~ ~ 44. Rig up wire line unit. Pull BPV. J . 45. Set gas lift valves in mandrels. Operate well on gas lift for +/- 45 days through open CMD sliding sleeve (flowback cleanup). Shut well in. 46. Rig up wireline. Replace gas lift valves with blank dummy valves. Close sliding sleeve. Perform MITIA. Return well to injection. 14. Discussion of Mud and Cuttings Disposal and Annular DisposaT Requirements of 20 AAC 25.005 (c)(14) r~n ap,z~licati~ln foe• a Permit to 1?F~ill rmsstc be accom~anie<Z1ay errch of ihe follox~ira~ items~, exeeptfar° an iterr: a/rEadv on,fi.le witft the cnmma,ssd~n catarl identif~d an tlae applicatic~n: ~ ~ ~ (14} a generul c~escri~7tion of hcfw the oj~ercitor plar~s to disp~se of c~r•alling rnud and cutFirtgs and a sla~emeizt of'tivhether the r?~~eratot- intends t~ reyuest authorization under 2~i4.AC: '~.080 fi}Y an anraular dis~osal operati~ta rn the tive71.; Q~~~t~AL 1J-122 PERMIT IT.doc Page 7 of 8 Printed: 25-May-07 ~ A~on for Permit to Drill, Well 1J-122 Revision No.O Saved: 25-May-07 Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated wi11 be disposed of either down a permitted annulus on lE Pad, hauled to the Prudhoe Bay Grind and Inject Facility far temporary storage and eventual processing for injection down an approved disposal well, or stored, tested far hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request autharization far the use of this well for annular disposal ~ operations. ~ ~ ~ 15. Attachments Attachment 1 Di~ectional Plan ~ ~ ~ ~ ~ Attachment 2 Drilling HazaNds Summary ~ ~ Attachment 3 Cen~CADE Summary ~ ~ Attachment 4 Well Schematic ~ ~ ~ ~ ~ ~ 1J-122 PERMIT IT.doc Page 8 of 8 ~ ~ ~ ~ ~ ~ ~ ~ Printed.~ 25-May-07 ~ ~ ~ • Cor~ocoPh ~! I i ps Alaska ~ Plan: 1 J-122 (wp06) Sperry Drilling Services Proposal Report - Geographic 09 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-122 - Slot 1J-122 1J-122 Local Coordinate Origin: Centered on Well Plan 1J-122 - Slot 1J-122 Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet H~LL~BU~ ~ Spsrry Drillir~g S~rviaes a~~~E~~~ ~ALL~~u -~on~ Sperry Drilllnp Serviees O ~ ...~~ V f ~ ~ 1 -2000 -1500 0 500 1000 Pfrost ~=K15--- -------- _ - T3 13 3/8" _Casing Pt_ _ _ _ ~~ ~35~ WELLDETAfLS: Plan U-122 Ground L.evel: 81.00 +N/S +F/-W Northing Easting Latittude Longitude Slot 0.00 0.00 594SG49.48 55886337 • 70°IS'43.595N 149°31'26.931W U-122 CASING DETAILS No MD TVD TVDss Name Size 1 4204.50 2265.30 2156.3 13 3/8" 13-3/8 2 11818.65 3969.00 3860 9 5/8" 9-5/8 3 18054 85 3990.10 . 3881.1 4 112" 4-112 SHL - 1837' FSL, 2347' FEL - Sec35-T11N-R10E 0° 500 10° ~f800 30° an~ FORMATION TOP DETAILS No TVDPath TVDSS MDPath Formation 1 1504.91 1395.91 1650.33 Pfrost 2 1657.88 1548.88 1893.72 K15 3 1987.24 1878.24 3015.12 T3 4 2265.30 2156.3 4204.50 Casing Pt 5 2981.00 2872 7265.86 Ugnu C 6 3268.45 3159.45 8495.41 Ugnu B 7 3344.82 3235.82 8822.09 Ugnu A 8 3537.88 3428.88 9647.89 K 13 9 3701.06 3592.06 10365.70 W Sak D 10 3749.55 3640.55 10591.24 W Sak C 11 3787.06 3678.06 10779.79 W Sak B 12 3828.12 3719.12 10996.12 W Sak A4 13 3889.30 3780.3 11318.46 W Sak A3 14 3966.39 3857.39 11788.65 W Sak A2 ------------------------------------------------------------------------ Ugnu C s"~O~" ~ 3000 ~ O , sS ~p~ ---- -~e$- ~a°- ------------------------- --------------------- ° --------------------------- 9 cb U nuB ' o ~ ~ _ ~=-U nuA--------- 9 p p _ _41 _ _ y~ _ _ ~ - _ 6 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ---~---o - ~ ---o ---------------------------- _ _ _ - - _ - _ _ ------------ - ---------- 3500 -- - - - o -- -- ~ - -- -- - - - ---- - o -o - -o - -o - -a - o ` T - - o~ -~ - --- - -- - - 'o o - oo- - - a o - o - -~ J=T22i2 w ( ~ K 13 ---- --------- o ----------- ----~ -- - °---`0---~0----~ --o- --°-- oa ~ . _o - ° -- °---ID --~'--- -- - '--- - ~~_____________ ________________ -__ -_ - ---- ---- - - ~ - -- --- ------- -_- -- 1~-~2~iL~~ ~ -- -=~SakD------- ~ --- --- --- --- - - -- --------------------- ------------- --- --- ----_----_ 4000 W Sak C , ~„ o ~- 1J-122 (wp06) i , W Sak 8 i 4 1/2" 4500 W Sak A4 ~i ~~ W Sak A3 i ~ ,' 5000 W Sak A2 9 5/8" Casing @ 11819' MD, 3969' ND: 636' FNL, 315' FEL - Sec36-T11 N-R10E ~ BHL @ 18055' MD, 3990' ND: 378' FSL, 422' FEL - Sec24-T11 N-R10E 5500 6000 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 / COI'lOCO~'11~~Ip5 ~~ NALl.~ E'~ U ~Tt~N Spsrry De~tiling Servt~es Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-122 Wellbore: 1 J-122 Plan: 1J-122 (wp06) WELLDETAII.,S: P1an1J-122 Gromd Level: 81.00 +N/-S +E/-W Nort}ting Easting Latittude Longitude Slot 0.00 0.00 5945649.48 55886337 70°15'43,595N 149°31'26.931W 1J-122 REFERENCEINFORMATION CO-Ofdif18Y8(N/E)R@fef8flCB: WeIIPIan1J-122-Sb11J-122,TrueNOrth Vertical (TVD) Reference: Pianned RKe ~ ~as.ooa ~ooyon ~a~ ~za+e~» Measured Depth Reference: Pianned Rres ~~oa.ooe ~ooyon ia~ ~2e+e»~ Calculation Method: Minimum Curvature tJazz (wPO6~ a ~ 0 0 ~ + s ~ 0 ~ s ~ 0 ~ 2400 1800 1200 S~ 600 0 -600 -1200 -1800 0 600 1200 1800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7801 ti"" West(-)/East(+) (1500 ft/in) ~~n~~0~~'~~p~ Alaska ~~~~~~~~. __ , , _~ ~_ ~ , ~~ ~~~ Ku aruk River~Unit, Nortfi Sfo e 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 ~ ti~~~ - - ~~ _ ,.~ ~~ ~,:___ ~ M~ x~ 1J'-122 ` 06 ~,nn~ ` :t. w °~ . "'= -- = ~ - - Audit Notes: Version: Phase: PLAN Tie On Depth: 28.00 28.00 0.00 0.00 0.00 5/9/2007 3:45:21PM Page 2 of 11 COMPASS 2003.11 Build 48 ~~~~~~~~ ~ . ~-'~ Halliburton Company HALL.e1BURTON COIlOCO~'ll~~lp5 Compass Proposal Report - Geographic ,41as{ca Sperry Driiling Servlcas ~~ ~~,~~~ ~~~ ~,.~ ~.~~ _ ~ ~ ~~~. -~ ~ Plan 1J-122 = Slot 1J=122 ,; . _ r~+*;,~ ~~~ vde~iw~~nima ~~~'~~a,~~ . ~,..~,7~z~ . .. . Well Position +N/-S 0.00 ft Northing: 5,945,649.48 ft Latitude: 70° 15' 43.595" N +E/-W 0.00 ft Easting: 558,863.37ft Longitude: 149° 31' 26.931" W Position Uncertainty 0.00 ft Welihead Elevation: ft Ground Level: 81.OOft ~ ~ C0110C0~'11~~IpS Alaska Halliburton Company Compass Proposal Report - Geographic HALLlBU1RTON Sperry Drilling Servioes , .~~; 28.00 0.00 0.00 28.00 -81.00 0.00 ~, 0.00 0.00 0.00 0.00 0.00 250.00 0.00 0.00 250.00 141.00 0.00 0.00 0.00 0.00 0.00 0.00 702.94 11.32 112.00 700.00 591.00 -16.71 41.36 2.50 2.50 0.00 112.00 1,642.89 48.69 101.47 1,500.00 1,391.00 -125.42 489.06 4.00 3.98 -1.12 -13.00 1,742.89 48.69 101.47 1,566.02 1,457.02 -140.36 562.67 0.00 0.00 0.00 0.00 2,300.01 76.48 99.31 1,820.06 1,711.06 -227.51 1,044.53 5.00 4.99 -0.39 -4.50 6,690.01 76.48 99.31 2,846.37 2,737.37 -918.09 5,256.64 0.00 0.00 0.00 0.00 9,696.46 76.48 1.00 3,549.24 3,440.24 733.34 7,235.62 3.18 0.00 -3.27 -90.00 10,368.70 77.41 1.76 3,701.06 3,592.06 1,388.01 7,251.40 0.18 0.14 0.11 38.48 10,618.70 77.41 1.76 3,755.53 3,646.53 1,631.89 7,258.89 0.00 0.00 0.00 0.00 10,686.41 79.06 2.98 3,769.34 3,660.34 1,698.12 7,261.63 3.00 2.43 1.80 36.07 11,551.07 79.06 2.98 3,933.45 3,824.45 2,545.91 7,305.74 0.00 0.00 0.00 0.00 11,788.65 85.00 359.00 3,966.39 3,857.39 2,781.01 7,309.74 3.00 2.50 -1.67 -33.85 11,818.65 85.00 359.00 3,969.00 3,860.00 2,810.90 7,309.22 0.00 0.00 0.00 0.00 11,977.34 91.00 356.91 3,974.55 3,865.55 2,969.30 7,303.57 4.00 3.78 -1.31 -19.21 12,018.16 91.00 356.91 3,973.84 3,864.84 3,010.06 7,301.37 0.00 0.00 0.00 0.00 12,099.96 89.55 359.85 3,973.45 3,864.45 3,091.81 7,299.06 4.00 -1.77 3.59 116.21 12,424.96 89.55 359.85 3,976.00 3,867.00 3,416.80 7,298.21 0.00 0.00 0.00 0.00 12,523.74 89.25 358.91 3,977.04 3,868.04 3,515.57 7,297.14 1.00 -0.31 -0.95 -107.99 13,325.30 89.25 358.91 3,987.60 3,878.60 4,316.92 7,281.90 0.00 0.00 0.00 0.00 13,360.73 88.89 358.96 3,988.18 3,879.18 4,352.34 7,281.24 1.00 -0.99 0.15 171.34 14,025.63 88.89 358.96 4,001.00 3,892.00 5,017.00 7,269.22 0.00 0.00 0.00 0.00 14,055.66 89.20 358.96 4,001.50 3,892.50 5,047.03 7,268.68 1.00 1.00 -0.01 -0.38 14,425.79 89.20 358.96 4,006.70 3,897.70 5,417.06 7,261.97 0.00 0.00 0.00 0.00 14,597.20 92.62 358.96 4,003.98 3,894.98 5,588.39 7,258.86 2.00 2.00 0.00 0.00 14,826.20 92.62 358.96 3,993.50 3,884.50 5,817.11 7,254.72 0.00 0.00 0.00 0.00 14,928.28 93.64 358.96 3,987.92 3,878.92 5,919.02 7,252.87 1.00 1.00 0.00 -0.03 15,126.84 93.64 358.96 3,975.30 3,866.30 6,117.14 7,249.28 0.00 0.00 0.00 0.00 15,277.11 90.64 358.96 3,969.69 3,860.69 6,267.27 7,246.56 2.00 -2.00 0.00 179.99 15,527.09 90.64 358.96 3,966.90 3,857.90 6,517.19 7,242.03 0.00 0.00 0.00 0.00 15,645.87 89.45 358.96 3,966.81 3,857.81 6,635.96 7,239.88 1.00 -1.00 0.00 180.00 16,427.39 89.45 358.96 3,974.30 3,865.30 7,417.31 7,225.72 0.00 0.00 0.00 0.00 16,452.38 89.20 358.96 3,974.59 3,865.59 7,442.30 7,225.27 1.00 -1.00 0.00 179.97 17,427.78 89.20 358.96 3,988.20 3,879.20 8,417.44 7,207.60 0.00 0.00 0.00 0.00 17,446.17 89.84 358.96 3,988.35 3,879.35 8,435.82 7,207.27 3.45 3.45 0.00 -0.03 18,054.86 89.84 358.96 3,990.10 3,881.10 9,044.42 7,196.24 0.00 0.00 0.00 0.00 5/9/2007 3:45:21PM Page 3 of 11 COMPASS 2003.11 8uild 48 ' C~~~GIl~~L • • - -- ~ 1 J-122 ~ :~~ d6 `' ~ - ~ , ~ ._ .. ._ _ . I ._.. . i ......... ~„ ~~ .... 4 .. . . .. . . . ..... 28.00 '~0.00 0.00 28.00 -81.00 0.00 0.00 5,945,649.48 • 558,863.37 , 0.00 0.00 SHL -1837' FSL, 2347' FEL - Sec35-T11 N-R10E 100.00 0.00 0.00 100.00 -9.00 0.00 0.00 5,945,649.48 558,863.37 0.00 0.00 200.00 0.00 0.00 200.00 91.00 0.00 0.00 5,945,649.48 558,863.37 0.00 0.00 250.00 0.00 0.00 250.00 141.00 0.00 0.00 5,945,649.48 558,863.37 0.00 0.00 300.00 1.25 112.00 300.00 191.00 -0.20 0.51 5,945,649.28 558,863.88 2.50 -0.20 400.00 3.75 112.00 399.89 290.89 -1.84 4.55 5,945,647.68 558,867.93 2.50 -1.84 500.00 6.25 112.00 499.50 390.50 -5.10 12.63 5,945,644.48 558,876.04 2.50 -5.10 600.00 8.75 112.00 598.64 489.64 -9.99 24.73 5,945,639.68 558,888.18 2.50 -9.99 700.00 11.25 112.00 697.11 588.11 -16.50 40.83 5,945,633.30 558,904.32 2.50 -16.50 702.94 11.32 112.00 700.00 591.00 -16.71 41.36 5,945,633.09 558,904.86 2.50 -16.71 800.00 15.13 108.66 794.47 685.47 -24.34 62.21 5,945,625.63 558,925.76 4.00 -24.34 900.00 19.09 106.59 890.02 781.02 -33.18 90.25 5,945,617.01 558,953.87 4.00 -33.18 1,000.00 23.05 105.21 983.32 874.32 -42.99 124.83 5,945,607.47 558,988.52 4.00 -42.99 1,100.00 27.03 104.22 1,073.90 964.90 -53.71 165.77 5,945,597.07 559,029.54 4.00 -53.71 1,200.00 31.02 103.46 1,161.32 1052.32 -65.29 212.88 5,945,585.86 559,076.73 4.00 -65.29 1,300.00 35.00 102.86 1,245.17 1136.17 -77.68 265.92 5,945,573.89 559,129.86 4.00 -77.68 1,400.00 38.99 102.38 1,325.02 1216.02 -90.82 324.63 5,945,561.21 559,188.67 4.00 -90.82 1,500.00 42.98 101.96 1,400.49 1291.49 -104.63 388.73 5,945,547.90 559,252.87 4.00 -104.63 1,600.00 46.97 101.61 1,471.21 1362.21 -119.06 457.92 5,945,534.02 559,322.16 4.00 -119.06 1,642.89 48.69 101.47 1,500.00 1391.00 -125.42 489.06 5,945,527.90 559,353.35 4.00 -125.42 1,650.33 48.69 101.47 1,504.91 1395.91 -126.53 494.54 5,945,526.83 559,358.83 0.00 -126.53 Pfrost 1,700.00 48.69 101.47 1,537.70 1428.70 -133.95 531.10 5,945,519.70 559,395.45 0.00 -133.95 1,742.89 48.69 101.47 1,566.02 1457.02 -140.36 562.67 5,945,513.54 559,427.07 0.00 -140.36 1,800.00 51.53 101.19 1,602.64 1493.64 -148.96 605.64 5,945,505.27 559,470.09 5.~0 -148.96 1,893.72 56.21 100.76 1,657.88 1548.88 -163.36 679.93 5,945,491.46 559,544.49 5.00 -163.36 K15 1,900.00 56.52 100.74 1,661.36 1552.36 -164.33 685.07 5,945,490.52 559,549.63 4.99 -164.33 2,000.00 61.51 100.33 1,712.82 1603.82 -179.99 769.33 5,945,475.52 559,634.01 5.00 -179.99 2,100.00 66.50 99.97 1,756.64 1647.64 -195.82 857.77 5,945,460.39 559,722.57 5.00 -195.82 2,200.00 71.49 99.63 1,792.47 1683.47 -211.70 949.74 5,945,445.23 559,814.64 5.00 -211.70 2,300.01 76.48 99.31 1,820.06 1711.06 -227.51 1,044.53 5,945,430.16 559,909.54 5.00 -227.51 2,400.00 76.48 99.31 1,843.43 1734.43 -243.24 1,140.47 5,945,415.18 560,005.59 0.00 -243.24 2,500.00 76.48 99.31 1,866.81 1757.81 -258.97 1,236.41 5,945,400.21 560,101.65 0.00 -258.97 2,600.00 76.48 99.31 1,890.19 1781.19 -274.70 1,332.36 5,945,385.23 560,197.71 0.00 -274.70 2,700.00 76.48 99.31 1,913.57 1804.57 -290.43 1,428.31 5,945,370.25 560,293.77 0.00 -290.43 2,800.00 76.48 99.31 1,936.95 1827.95 -306.16 1,524.26 5,945,355.27 560,389.83 0.00 -306.16 2,900.00 76.48 99.31 1,960.33 1851.33 -321.89 1,620.20 5,945,340.29 560,485.89 0.00 -321.89 3,000.00 76.48 99.31 1,983.71 1874.71 -337.62 1,716.15 5,945,325.31 560,581.94 0.00 -337.62 3,017.64 76.48 99.31 1,987.83 1878.83 -340.40 1,733.08 5,945,322.67 560,598.89 0.00 -340.40 T3 3,100.00 76.48 99.31 2,007.08 1898.08 -353.36 1,812.10 5,945,310.33 560,678.00 0.00 -353.36 3,200.00 76.48 99.31 2,030.46 1921.46 -369.09 1,908.05 5,945,295.36 560,774.06 0.00 -369.09 3,300.00 76.48 99.31 2,053.84 1944.84 -384.82 2,004.00 5,945,280.38 560,870.12 0.00 -384.82 3,400.00 76.48 99.31 2,077.22 1968.22 -400.55 2,099.94 5,945,265.40 560,966.18 0.00 -400.55 5/9/2007 3:45:21PM Page 4 of 11 COMPASS 2003.11 Build 48 ~-.:,:tYi~~~~F~~ Halliburton Company HALLIBURTGtN ~OIIOCOP~'11~~~~5 Compass Proposal Report - Geographic Spsrry Drilling Servieses ~ ~ ~' Halliburton Company HALL.IBURTC]1'~1 ConocoPhitfips Compass Proposal Report - Geographic ,q~~ 8perry Drilling Smrvice~ , 1J-122~<~ 06 '~ _ ~ ~ - 3,500.00 ~76.48 - ~ 99.31 2,100.60 T1991.60 -416.28 2,195.89 ,,~ ~; 5,945,250.42 ~ 561,062.24 0.00 - -416.28 3,600.00 76.48 99.31 2,123.98 2014.98 -432.01 2,291.84 5,945,235.44 561,158.30 0.00 -432.01 3,700.00 76.48 99.31 2,147.35 2038.35 -447.74 2,387.79 5,945,220.46 561,254.35 0.00 -447.74 3,800.00 76.48 99.31 2,170.73 2061.73 -463.47 2,483.74 5,945,205.48 561,350.41 0.00 -463.47 3,900.00 76.48 99.31 2,194.11 2085.11 -479.20 2,579.68 5,945,190.50 561,446.47 0.00 -479.20 4,000.00 76.48 99.31 2,217.49 2108.49 -494.93 2,675.63 5,945,175.53 561,542.53 0.00 -494.93 4,100.00 76.48 99.31 2,240.87 2131.87 -510.66 2,771.58 5,945,160.55 561,638.59 0.00 -510.66 4,200.00 76.48 99.31 2,264.25 2155.25 -526.39 2,867.53 5,945,145.57 561,734.65 0.00 -526.39 4,204.50 76.48 99.31 2,265.30 2156.30 -527.10 2,871.85 5,945,144.89 561,738.97 0.00 -527.10 13 3!8" 4,204.89 76.48 99.31 2,265.39 2156.39 -527.16 2,872.22 5,945,144.84 561,739.34 0.00 -527.16 Casing Pt 4,300.00 76.48 99.31 2,287.63 2178.63 -542.12 2,963.47 5,945,130.59 561,830.71 0.00 -542.12 4,400.00 76.48 99.31 2,311.00 2202.00 -557.85 3,059.42 5,945,115.61 561,926.77 0.00 -557.85 4,500.00 76.48 99.31 2,334.38 2225.38 -573.58 3,155.37 5,945,100.63 562,022.82 0.00 -573.58 4,600.00 76.48 99.31 2,357.76 2248.76 -589.32 3,251.32 5,945,085.65 562,118.88 0.00 -589.32 4,700.00 76.48 99.31 2,381.14 2272.14 -605.05 3,347.27 5,945,070.67 562,214.94 0.00 -605.05 4,800.00 76.48 99.31 2,404.52 2295.52 -620.78 3,443.21 5,945,055.70 562,311.00 0.00 -620.78 4,900.00 76.48 99.31 2,427.90 2318.90 -636.51 3,539.16 5,945,040.72 562,407.06 0.00 -636.51 5,000.00 76.48 99.31 2,451.27 2342.27 -652.24 3,635.11 5,945,025.74 562,503.12 0.00 -652.24 5,100.00 76.48 99.31 2,474.65 2365.65 -667.97 3,731.06 5,945,010.76 562,599.18 0.00 -667.97 5,200.00 76.48 99.31 2,498.03 2389.03 -683.70 3,827.01 5,944,995.78 562,695.24 0.00 -683.70 5,300.00 76.48 99.31 2,521.41 2412.41 -699.43 3,922.95 5,944,980.80 562,791.29 0.00 -699.43 5,400.00 76.48 99.31 2,544.79 2435.79 -715.16 4,018.90 5,944,965.82 562,887.35 0.00 -715.16 5,500.00 76.48 99.31 2,568.17 2459.17 -730.89 4,114.85 5,944,950.85 562,983.41 0.00 -730.89 5,600.00 76.48 99.31 2,591.55 2482.55 -746.62 4,210.80 5,944,935.87 563,079.47 0.00 -746.62 5,700.00 76.48 99.31 2,614.92 2505.92 -762.35 4,306.74 5,944,920.89 563,175.53 0.00 -762.35 5,800.00 76.48 99.31 2,638.30 2529.30 -778.08 4,402.69 5,944,905.91 563,271.59 0.00 -778.08 5,900.00 76.48 99.31 2,661.68 2552.68 -793.81 4,498.64 5,944,890.93 563,367.65 0.00 -793.81 6,000.00 76.48 99.31 2,685.06 2576.06 -809.54 4,594.59 5,944,875.95 563,463.70 0.00 -809.54 6,100.00 76.48 99.31 2,708.44 2599.44 -825.28 4,690.54 5,944,860.97 563,559.76 0.00 -825.28 6,200.00 76.48 99.31 2,731.82 2622.82 -841.01 4,786.48 5,944,845.99 563,655.82 0.00 -841.01 6,300.00 76.48 99.31 2,755.20 2646.20 -856.74 4,882.43 5,944,831.02 563,751.88 0.00 -856.74 6,400.00 76.48 99.31 2,778.57 2669.57 -872.47 4,978.38 5,944,816.04 563,847.94 0.00 -872:47 6,500.00 76.48 99.31 2,801.95 2692.95 -888.20 5,074.33 5,944,801.06 563,944.00 0.00 -888.20 6,600.00 76.48 99.31 2,825.33 2716.33 -903.93 5,170.28 5,944,786.08 564,040.06 0.00 -903.93 6,690.01 76.48 99.31 2,846.37 2737.37 -918.09 5,256.64 5,944,772.60 564,126.52 0.00 -918.09 6,700.00 76.48 98.99 2,848.71 2739.71 -919.63 5,266.23 5,944,771.13 564,136.12 3.17 -919.63 6,800.00 76.48 95.72 2,872.09 2763.09 -932.07 5,362.64 5,944,759.45 564,232.62 3.18 -932.07 6,900.00 76.48 92.45 2,895.47 2786.47 -938.98 5,459.61 5,944,753.29 564,329.63 3.18 -938.98 7,000.00 76.48 89.18 2,918.84 2809.84 -940.36 5,556.82 5,944,752.68 564,426.84 3.18 -940.36 7,100.00 76.48 85.91 2,942.22 2833.22 -936.18 5,653.95 5,944,757.61 564,523.92 3.18 -936.18 7,200.00 76.48 82.64 2,965.60 2856.60 -926.47 5,750.68 5,944,768.07 564,620.56 3.18 -926.47 7,243.24 76.48 81.22 2,975.71 2866.71 -920.57 5,792.30 5,944,774.30 564,662.13 3.18 -920.57 Ugnu C 7,300.00 76.48 79.37 2,988.98 2879.98 -911.27 5,846.69 5,944,784.03 564,716.45 3.18 -911.27 7,400.00 76.48 76.10 3,012.36 2903.36 -890.60 5,941.69 5,944,805.43 564,811.27 3.18 -890.60 5/9/2007 3:45:21PM Page 5 of 11 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ t ~ ~ ~ • ~ - - __ ~ ~ 1 J 122 ~ m _.... i 06 .... ...~:~_. - . - - .. . 7,500.00 76.48 ~~ - 72.83 ~_.. 3,035.74 ~. 2926.74 m~ _ -864.56 . 6,035.35 ~ .. . . 5,944,832.21 564,904.71 i 3.18 . „ , -864.56 7,600.00 76.48 69.56 3,059.12 2950.12 -833.21 6,127.37 5,944,864.27 564,996.48 3.18 -833.21 7,700.00 76.48 66.29 3,082.49 2973.49 -796.67 6,217.46 5,944,901.51 565,086.27 3.18 -796.67 7,800.00 76.48 63.02 3,105.87 2996.87 -755.04 6,305.31 5,944,943.82 565,173.79 3.18 -755.04 7,900.00 76.48 59.75 3,129.25 3020.25 -708.48 6,390.65 5,944,991.05 565,258.75 3.18 -708.48 8,000.00 76.48 56.48 3,152.63 3043.63 -657.12 6,473.19 5,945,043.05 565,340.88 3.18 -657.12 8,100.00 76.48 53.21 3,176.01 3067.01 -601.13 6,552.67 5,945,099.64 565,419.91 3.18 -601.13 8,200.00 76.48 49.94 3,199.39 3090.39 -540.71 6,628.82 5,945,160.66 565,495.58 3.18 -540.71 8,300.00 76.48 46.67 3,222.76 3113.76 -476.03 6,701.41 5,945,225.89 565,567.65 3.18 -476.03 8,400.00 76.48 43.40 3,246.14 3137.14 -407.33 6,770.18 5,945,295.12 565,635.88 3.18 -407.33 8,500.00 76.48 40.13 3,269.52 3160.52 -334.81 6,834.93 5,945,368.14 565,700.05 3.18 -334.81 8,524.50 76.48 39.32 3,275.25 3166.25 -316.48 6,850.16 5,945,386.58 565,715.13 3.18 -316.48 Ugnu B 8,600.00 76.48 36.86 3,292.90 3183.90 -258.72 6,895.43 5,945,444.70 565,759.95 3.18 -258.72 8,700.00 76.48 33.59 3,316.28 3207.28 -179.30 6,951.50 5,945,524.54 565,815.39 3.18 -179.30 8,800.00 76.48 30.32 3,339.66 3230.66 -96.81 7,002.94 5,945,607.42 565,866.18 3.18 -96.81 8,854.16 76.48 28.54 3,352.32 3243.32 -50.94 7,028.82 5,945,653.49 565,891.70 3.18 -50.94 Ugnu A 8,900.00 76.48 27.05 3,363.04 3254.04 -11.52 7,049.60 5,945,693.07 565,912.16 3.18 -11.52 9,000.00 76.48 23.78 3,386.41 3277.41 76.29 7,091.31 5,945,781.19 565,953.19 3.18 76.29 9,100.00 76.48 20.51 3,409.79 3300.79 166.34 7,127.95 5,945,871.52 565,989.11 3.18 166.34 9,200.00 76.48 17.24 3,433.17 3324.17 258.33 7,159.39 5,945,963.74 566,019.83 3.18 258.33 9,300.00 76.48 13.97 3,456.55 3347.55 351.97 7,185.53 5,946,057.57 566,045.24 3.18 351.97 9,400.00 76.48 10.70 3,479.93 3370.93 446.94 7,206.29 5,946,152.69 566,065.25 3.18 446.94 9,500.00 76.48 7.43 3,503.31 3394.31 542.95 7,221.59 5,946,248.80 566,079.81 3.18 542.95 9,600.00 76.48 4.16 3,526.68 3417.68 639.66 7,231.40 5,946,345.59 566,088.85 3.18 639.66 9,663.97 76.48 2.06 3,541.64 3432.64 701.76 7,234.77 5,946,407.71 566,091.74 3.18 701.76 K13 9,696.46 76.48 1.00 3,549.24 3440.24 733.34 7,235.62 5,946,439.29 566,092.34 3.18 733.34 9,700.00 76.48 1.00 3,550.06 3441.06 736.79 7,235.68 5,946,442.73 566,092.37 0.18 736.79 9,800.00 76.62 1.12 3,573.32 3464.32 834.03 7,237.48 5,946,539.98 566,093.41 0.18 834.03 9,900.00 76:76 1.23 3,596.33 3487.33 931.32 7,239.47 5,946,637.27 566,094.65 0.18 931.32 10,000.00 76.90 1.34 3,619.11 3510.11 1,028.67 7,241.66 5,946,734.62 566,096.07 0.18 1,028.67 10,100.00 77.04 1.46 3,641.66 3532.66 1,126.07 7,244.04 5,946,832.03 566,097.69 0.18 1,126.07 10,200.00 77.18 1.57 3,663.96 3554.96 1,223.51 7,246.62 5,946,929.48 566,099.50 0.18 1,223.51 10,300.00 77.32 1.68 3,686.03 3577.03 1,321.01 7,249.38 5,947,026.99 566,101.51 0.18 1,321.01 10,368.70 77.41 1.76 3,701.06 3592.06 1,388.01 7,251.40 5,947,094.00 566,103.00 0.18 1,388.01 W Sak D-1 J-122 D Tap (wp06) 10,400.00 77.41 1.76 3,707.88 3598.88 1,418.55 7,252.34 5,947,124.54 566,103.70 0.00 1,418.55 10,500.00 77.41 1.76 3,729.67 3620.67 1,516.10 7,255.33 5,947,222.10 566,105.93 0.00 1,516.10 10,600.00 77.41 1.76 3,751.46 3642.46 1,613.65 7,258.33 5,947,319.66 566,108.17 0.00 1,613.65 10,600.42 77.41 1.76 3,751.55 3642.55 1,614.06 7,258.34 5,947,320.07 566,108.18 0.00 1,614.06 W Sak C 10,618.70 77.41 1.76 3,755.53 3646.53 1,631.89 7,258.89 5,947,337.91 566,108.59 0.00 1,631.89 10,686.41 79.06 2.98 3,769.34 3660.34 1,698.12 7,261.63 5,947,404.14 566,110.81 3.00 1,698.12 10,700.00 79.06 2.98 3,771.92 3662.92 1,711.44 7,262.33 5,947,417.47 566,111.40 0.00 1,711.44 5/9I2007 3:45:21PM Page 6 of 11 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ ~ ~ ~ C4110C0~11~~Ip5 Halliburton Company HALI_IBURTORI ~S~ Compass Proposal Report - Geographic sp~.,,y Drtliing ~'3~vice~ ~ ~ ~ 1 J-122 06 -~~~ ° 3,200.00 9.25 58.91 ~ ~ ~~ 3,985.95 876.95 ,191.65 ,284.28 ,949,897.54 66,113.97 - 0.00 ,191.65 13,300.00 89.25 358.91 3,987.27 3878.27 4,291.62 7,282.38 5,949,997.48 566,111.28 0.00 4,291.62 13,325.30 89.25 358.91 3,987.60 3878.60 4,316.92 7,281.90 5,950,022.77 566,110.60 0.00 4,316.92 1J-122 MB A2 CP3 04/11/07 13,360.73 88.89 358.96 3,988.18 3879.18 4,352.34 7,281.24 5,950,058.18 566,109.67 1.00 4,352.34 13,400.00 88.89 358.96 3,988.93 3879.93 4,391.59 7,280.53 5,950,097.42 566,108.65 0.00 4,391.59 13,500.00 88.89 358.96 3,990.86 3881.86 4,491.56 7,278.72 5,950,197.36 566,106.06 0.00 4,491.56 13,600.00 88.89 358.96 3,992.79 3883.79 4,591.52 7,276.92 5,950,297.30 566,103.48 0.00 4,591.52 13,700.00 88.89 358.96 3,994.72 3885.72 4,691.49 7,275.11 5,950,397.24 566,100.89 0.00 4,691.49 13,800.00 88.89 358.96 3,996.65 3887.65 4,791.45 7,273.30 5,950,497.18 566,098.30 0.00 4,791.45 13,900.00 88.89 358.96 3,998.58 3889.58 4,891.42 7,271.49 5,950,597.12 566,095.71 0.00 4,891.42 14,000.00 88.89 358.96 4,000.51 3891.51 4,991.38 7,269.68 5,950,697.05 566,093.12 0.00 4,991.38 14,025.63 88.89 358.96 4,001.00 3892.00 5,017.00 7,269.22 5,950,722.67 566,092.45 0.00 5,017.00 1J-122 MB A2 CP4 04/11/07 14,055.66 89.20 358.96 4,001.50 3892.50 5,047.03 7,268.68 5,950,752.68 566,091.68 1.00 5,047.03 14,100.00 89.20 358.96 4,002.12 3893.12 5,091.35 7,267.87 5,950,797.00 566,090.53 0.00 5,091.35 14,200.00 89.20 358.96 4,003.53 3894.53 5,191.33 7,266.06 5,950,896.94 566,087.93 0.00 5,191.33 14,300.00 89.20 358.96 4,004.93 3895.93 5,291.30 7,264.25 5,950,996.89 566,085.34 0.00 5,291.30 14,400.00 89.20 358.96 4,006.34 3897.34 5,391.27 7,262.44 5,951,096.84 566,082.75 0.00 5,391.27 14,425.79 89.20 358.96 4,006.70 3897.70 5,417.06 7,261.97 5,951,122.62 566,082.08 0.00 5,417.06 1J-122 MB A2 CP5 04/11/07 14,500.00 90.68 358.96 4,006.78 3897.78 5,491.25 7,260.63 5,951,196.79 566,080.15 2.00 5,491.25 14,597.20 92.62 358.96 4,003.98 3894.98 5,588.39 7,258.86 5,951,293.90 566,077.63 2.00 5,588.39 14,600.00 92.62 358.96 4,003.85 3894.85 5,591.19 7,258.81 5,951,296.70 566,077.56 0.00 5,591.19 14,700.00 92.62 358.96 3,999.28 3890.28 5,691.07 7,257.00 5,951,396.55 566,074.97 0.00 5,691.07 14,800.00 92.62 358.96 3,994.70 3885.70 5,790.95 7,255.19 5,951,496.40 566,072.38 0.00 5,790.95 14,82620 92.62 358.96 3,993.50 3884.50 5,817.11 7,254.72 5,951,522.56 566,071.70 0.00 5,817.11 1J-122 MB A2 CP6 Q4l11/07 14,900.00 93.36 358.96 3,989.65 3880.65 5,890.80 7,253.38 5,951,596.23 566,069.79 1.00 5,890.80 14,928.28 93.64 358.96 3,987.92 3878.92 5,919.02 7,252.87 5,951,624.44 566,069.06 1.00 5,919.02 15,000.00 93.64 358.96 3,983.36 3874.36 5,990.59 7,251.57 5,951,695.99 566,067.20 0.00 5,990.59 15,100.00 93.64 358.96 3,977.01 3868.01 6,090.37 7,249.77 5,951,795.75 566,064.61 0.00 6,090.37 15,126.84 93.64 358.96 3,975.30 3866.30 6,117.14 7,249.28 5,951,822.51 566,063.92 0.00 6,117.14 1J-122 MB A2 CP7 04/11107 15,200.00 92.18 358.96 3,971.58 3862.58 6,190.20 7,247.96 5,951,895.55 566,062.02 2.00 6,190.20 15,277.11 90.64 358.96 3,969.69 3860.69 6,267.27 7,246.56 5,951,972.60 566,060.02 2.00 6,267.27 15,300.00 90.64 358.96 3,969.43 3860.43 6,290.16 7,246.14 5,951,995.48 566,059.43 0.00 6,290.16 15,400.00 90.64 358.96 3,968.32 3859.32 6,390.13 7,244.33 5,952,095.43 566,056.84 0.00 6,390.13 15,500.00 90.64 358.96 3,967.20 3858.20 6,490.11 7,242.52 5,952,195.38 566,054.24 0.00 6,490.11 15,527.09 90.64 358.96 3,966.90 3857.90 6,517.19 7,242.03 5,952,222.46 566,053.54 0.00 6,517.19 1J-122 MB A2 CP8 04/11/07 15,600.00 89.91 358.96 3,966.55 3857.55 6,590.09 7,240.71 5,952,295.34 566,051.65 1.00 6,590.09 15,645.87 89.45 358.96 3,966.81 3857.81 6,635.96 7,239.88 5,952,341.19 566,050.46 1.00 6,635.96 15,700.00 89.45 358.96 3,967.33 3858.33 6,690.07 7,238.90 5,952,395.29 566,049.06 0.00 6,690.07 15,800.00 89.45 358.96 3,968.29 3859.29 6,790.05 7,237.09 5,952,495.24 566,046.46 0.00 6,790.05 5/9/2007 3:45:21PM Page 8 of 11 COMPASS 2003.11 Build 48 '' ~ ~~ ~ ?e.d' ~ ~ ~ ~ ~-'' Halliburton Company HALLIBURTON C0110C0~'ll~~lp5 Compass Proposal Report - Geographic ,q~~ Sperry Driiling Services ~ COC10C0~'11~~i~?5 aaska Halliburton Company Compass Proposal Report - Geographic ~ HALL..IBURT ~el 9p~rry Drilling Services 10,779.79 79.06 2.98 3,787.06 3678.06 1,789.68 7,266.40 5,947,495.73 566,114.86 0.00 1,789.68 W Sak B 10,800.00 79.06 2.98 3,790.90 3681.90 1,809.49 7,267.43 5,947,515.55 566,115.74 0.00 1,809.49 10,900.00 79.06 2.98 3,809.88 3700.88 1,907.54 7,272.53 5,947,613.63 566,120.07 0.00 1,907.54 11,000.00 79.06 2.98 3,828.86 3719.86 2,005.59 7,277.63 5,947,711.71 566,124.40 0.00 2,005.59 11,006.98 79.06 2.98 3,830.18 3721.18 2,012.43 7,277.99 5,947,718.55 566,124.71 0.00 2,012.43 W Sak A4 11,100.00 79.06 2.98 3, 847.84 3738.84 2,103.64 7,282.73 5,947, 809.78 566,128.74 0.00 2,103.64 11,200.00 79.06 2.98 3,866.82 3757.82 2,201.69 7,287.83 5,947,907.86 566,133.07 0.00 2,201.69 11,300.00 79.06 2.98 3,885.80 3776.80 2,299.74 7,292.94 5,948,005.94 566,137.41 0.00 2,299.74 11,338.43 79.06 2.98 3,893.09 3784.09 2,337.43 7,294.90 5,9G8,043.63 566,139.07 0.00 2,337.43 W Sak A3 11,400.00 79.06 2.98 3,904.78 3795.78 2,397.79 7,298.04 5,948,104.01 566,141.74 0.00 2,397.79 11,500.00 79.06 2.98 3,923.76 3814.76 2,495.84 7,303.14 5,948,202.09 566,146.08 0.00 2,495.84 11,551.07 79.06 2.98 3,933.45 3824.45 2,545.91 7,305.74 5,948,252.17 566,148.29 0.00 2,545.91 11,600.00 80.28 2.15 3,942.22 3833.22 2,594.00 7,307.90 5,948,300.28 566,150.06 3.00 2,594.00 11,675.91 82.18 0.87 3,953.80 3844.80 2,669.00 7,309.87 5,948,375.28 566,151.45 3.00 2,669.00 1J-122 MB A2 Heel 04/11/07 11,700.00 82.78 0.47 3,956.95 3847.95 2,692.87 7,310.15 5,948,399.15 566,151.55 2.99 2,692.87 11,781.99 84.83 359.11 3,965.80 3856.80 2,774.38 7,309.85 5,948,480.65 566,150.61 3.00 2,774.38 1J-122 MB A2 CP1 04/71Y07 11,788.65 85.00 359.00 3,966.39 3857.39 2,781.01 7,309.74 5,948,487.28 566,150.45 3.00 2,781.01 W Sak A2 -1J-122 A Top (wp06) 11,800.00 85.00 359.00 3,967.38 3858.38 2,792.32 7,309.55 5,948,498.58 566,150.16 0.00 2,792.32 11,818.65 85.00 359.00 3,969.00 3860.00 2,810.90 7,309.22 5,948,517.15 566,149.69 0.00 2,810.90 9 5/8" Casing @ 11819' MD, 3969' ND: 636' FNL, 315' FEL - Sec36-T11 N-R10E - 9 5/8" 11,900.00 88.07 357.93 3,973.92 3864.92 2,892.05 7,307.05 5,948,598.28 566,146.88 4.00 2,892.05 11,977.34 91.00 356.91 3,974.55 3865.55 2,969.30 7,303.57 5,948,675.50 566,142.80 4.00 2,969.30 12,000.00 91.00 356.91 3,974.15 3865.15 2,991.93 7,302.35 5,948,698.11 566,141.41 0.00 2,991.93 12,018.16 91.00 356.91 3,973.84 3864.84 3,010.06 7,301.37 5,948,716.23 566,140.29 0.00 3,010.06 12,099.96 89.55 359.85 3,973.45 3864.45 3,091.81 7,299.06 5,948,797.96 566,137.34 4.00 3,091.81 12,200.00 89.55 359.85 3,974.23 3865.23 3,191.85 7,298.80 5,948,897.98 566,136.30 0.00 3,191.85 12,300.00 89.55 359.85 3,975.02 3866.02 3,291.85 7,298.54 5,948,997.96 566,135.25 0.00 3,291.85 12,400.00 89.55 359.85 3,975.80 3866.80 3,391.84 7,298.28 5,949,097.94 566,134.21 0.00 3,391.84 12,424.96 89.55 359.85 3,976.00 3867.00 3,416.80 7,298.21 5,949,122.90 566,133.95 0.00 3,416.80 1J-122 MB A2 CP2 04/11(Q7 12,500.00 89.32 359.14 3,976.74 3867.74 3,491.84 7,297.55 5,949,197.92 566,132.70 1.00 3,491.84 12,523.74 89.25 358.91 3,977.04 3868.04 3,515.57 7,297.14 5,949,221.65 566,132.11 1.00 3,515.57 12,600.00 89.25 358.91 3,978.04 3869.04 3,591.81 7,295.69 5,949,297.86 566,130.06 0.00 3,591.81 12,700.00 89.25 358.91 3,979.36 3870.36 3,691.78 7,293.79 5,949,397.81 566,127.38 0.00 3,691.78 12,800.00 89.25 358.81 3,980.68 3871.68 3,791.76 7,291.89 5,949,497.75 566,124.70 0.00 3,791.76 12,900.00 89.25 358.91 3,982.00 3873.00 3,891.73 7,289.99 5,949,597.70 566,122.01 0.00 3,891.73 13,000.00 89.25 358.91 3,983.31 3874.31 3,991.70 7,288.09 5,949,697.65 566,119.33 0.00 3,991.70 13,100.00 89.25 358.91 3,984.63 3875.63 4,091.68 7,286.18 5,949,797.59 566,116.65 0.00 4,091.68 5/9/2007 3:45:21PM Page 7 of 11 COMPASS 2003.11 Bui/d 48 ~ °~- ~~ ' r'~^F ~ ~k '~ ~`~ :'~ • ~ CanocoPhillips _ _ p,~~ Spmrry Drflling 8s~vices , r _- - ~ __ ~ __~ - 1,1-122 ~ ~ ___ 06 ~~ , - __~ -- - _ ~~~, - ~ ~ - - , 15,900.00 ~ 89.45 - °- ,__ 358.96 3,969.24 3860.24 ~ 6,890.03 _ 7,235.27 ' ' , , m 5,952,595.19 - 566,043.87 0.00 - 6,890.03 16,000.00 89.45 358.96 3,970.20 3861.20 6,990.01 7,233.46 5,952,695.15 566,041.28 0.00 6,990.01 16,100.00 89.45 358.96 3,971.16 3862.16 7,089.99 7,231.65 5,952,795.10 566,038.69 0.00 7,089.99 16,200.00 89.45 358.96 3,972.12 3863.12 7,189.97 7,229.84 5,952,895.05 566,036.09 0.00 7,189.97 16,300.00 89.45 358.96 3,973.08 3864.08 7,289.95 7,228.03 5,952,995.00 566,033.50 0.00 7,289.95 16,400.00 89.45 358.96 3,974.04 3865.04 7,389.93 7,226.22 5,953,094.95 566,030.91 0.00 7,389.93 16,427.39 89.45 358.96 3,974.30 3865.30 7,417.31 7,225.72 5,953,122.33 566,030.20 0.00 7,417.31 1J-122 MB A2 CP9 04(11/07 16,452.38 89.20 358.96 3,974.59 3865.59 7,442.30 7,225.27 5,953,147.31 566,029.55 1.00 7,442.30 16,500.00 89.20 358.96 3,975.26 3866.26 7,489.90 7,224.40 5,953,194.90 566,028.31 0.00 7,489.90 16,600.00 89.20 358.96 3,976.65 3867.65 7,589.88 7,222.59 5,953,294.85 566,025.72 0.00 7,589.88 16,700.00 89.20 358.96 3,978.05 3869.05 7,689.85 7,220.78 5,953,394.80 566,023.13 0.00 7,689.85 16,800.00 89.20 358.96 3,979.44 3870.44 7,789.82 7,218.97 5,953,494.74 566,020.54 0.00 7,789.82 16,900.00 89.20 358.96 3,980.84 3871.84 7,889.80 7,217.16 5,953,594.69 566,017.94 0.00 7,889.80 17,000.00 89.20 358.96 3,982.23 3873.23 7,989.77 7,215.35 5,953,694.64 566,015.35 0.00 7,989.77 17,100.00 89.20 358.96 3,983.63 3874.63 8,089.74 7,213.54 5,953,794.59 566,012.76 0.00 8,089.74 17,200.00 89.20 358.96 3,985.02 3876.02 8,189.72 7,211.73 5,953,894.53 566,010.17 0.00 8,189.72 17,300.00 89.20 358.96 3,986.42 3877.42 8,289.69 7,209.91 5,953,994.48 566,007.57 0.00 8,289.69 17,400.00 89.20 358.96 3,987.81 3878.81 8,389.67 7,208.10 5,954,094.43 566,004.98 0.00 8,389.67 17,427.78 89.20 358.96 3,988.20 3879.20 8,417.44 7,207.60 5,954,122.19 566,004.26 0.00 8,417.44 1J-122 MB A2 CP10 44(11f87 17,446.17 89.84 358.96 3,988.35 3879.35 8,435.82 7,207.27 5,954,140.57 566,003.79 3.45 8,435.82 17,500.00 89.84 358.96 3,988.51 3579.51 8,489.65 7,206.29 5,954,194.38 566,002.39 0.00 8,489.65 17,600.00 89.84 358.96 3,988.80 3879.80 8,589.63 7,204.48 5,954,294.34 565,999.80 0.00 8,589.63 17,700.00 89.84 358.96 3,989.08 3880.08 8,689.61 7,202.67 5,954,394.29 565,997.20 0.00 8,689.61 17,800.00 89.84 358.96 3,989.37 3880.37 8,789.60 7,200.86 5,954,494.25 565,994.61 0.00 8,789.60 17,900.00 89.84 358.96 3,989.66 3880.66 8,889.58 7,199.04 5,954,594.21 565,992.02 0.00 8,889.58 18,000.00 89.84 358.96 3,989.94 3880.94 8,989.56 7,197.23 5,954,694.16 565,989.42 0.00 8,989.56 ~ 18,054.86 89.84 358.96 3,990.10' 3881.10 9,044.42 7,196.24 5,954,749.00 565,988.00 0.00 9,044.42 BHL @ 18055' MD, 3990' ND: 318' FSL, 422' F EL - Sec24-T11N-R10E - 4 1/2" -1J-1 22 MB_A2_Toe 04/11t07 5/9/2007 3:45:21PM Page 9 of 11 COMPASS 2003.11 Build 48 Halliburton Company Compass Proposal Report - Geographic HALLIBURTC7N ~.ft\~~~~~~ CCN1~0~'11~~I pS Alaska ~ Halliburton Company Compass Proposal Report - Geographic ~ HALLIBURTON Sperry Driiiiny Bervirae: 3,966.39 1J-122 A Top (wp06) 2,781.01 7,309.74 5,948,487.28 566,150.45 - Point 4,006.70 1J-122 MB_A2_CP5 04/11/07 5,417.06 7,261.97 5,951,122.62 566,082.08 - Polygon Point 1 0.00 48.93 5,951,123.00 566,131.00 Point 2 400.27 49.06 5,951,523.00 566,128.00 3,974.30 1J-122 MB_A2_CP9 04/11/07 7,417.31 7,225.72 5,953,122.33 566,030.20 - Polygon Point 1 0.00 85.81 5,953,123.00 566,116.00 Point 2 1,000.24 85.63 5,954,123.00 566,108.00 4,001.00 1J-122 MB_A2_CP4 04/11/07 5,017.00 7,269.22 5,950,722.67 566,092.45 - Polygon Point 1 0.00 42.55 5,950,723.00 566,135.00 Point 2 400.10 41.68 5,951,123.00 566,131.00 3,987.60 1J-122 MB_A2_CP3 04/11/07 4,316.92 7,281.90 5,950,022.77 566,110.60 - Polygon Point 1 0.00 29.40 5,950,023.00 566,140.00 Point2 700.21 29.87 5,950,723.00 566,135.00 3,965.80 1J-122 MB_A2_CP1 04/11/07 2,116.64 7,287.42 5,947,822.81 566,133.32 - Polygon Point 1 0.00 23.68 5,947,823.00 566,157.00 Point2 1,300.20 23.84 5,949,123.~0 566,147.00 3,988.20 1J-122 MB_A2_CP10 04/11/07 8,417.44 7,207.60 5,954,122.19 566,004.26 - Polygon Point 1 0.00 103.75 5,954,123.00 566,108.00 Point 2 626.08 103.74 5,954,749.00 566,103.10 3,990.10 1J-122 MB_A2_Toe 04/11/07 9,044.42 7,196.24 5,954,749.00 565,988.00 - Point 3,701.06 1J-122 D Top (wp06) 1,388.01 7,251.40 5,947,094.00 566,103.00 - Point 3,966.90 1J-122 MB_A2_CP8 04/11/07 6,517.19 7,242.03 5,952,222.46 566,053.54 - Polygon Point 1 0.00 69.47 5,952,223.00 566,123.00 Point 2 900.22 69.50 5,953,123.00 566,116.00 3,976.00 1J-122MB_A2_CP204111/07 3,416.80 7,298.21 5,949,122.90 566,133.95 - Polygon Point 1 0.00 13.05 5,949,123.00 566,147.00 Point 2 900.19 13.09 5,950,023.00 566,140.00 3;953.80 1J-122 MB_A2_Heel 04/11/07 1,388.01 7,251.40 5,947,094.00 566,103.00 - Polygon Point 1 0.00 0.00 5,947,094.00 566,103.00 Point 2 728.72 59.71 5,947,823.00 566,157.00 3,975.30 1J-122 MB_A2_CP7 04/11/07 6,117.14 7,249.28 5,951,822.51 566,063.92 - Polyqon _ _ ._ 5/9/2007 3:45:21 PM Page 10 of 71 COMPASS 2003.11 Build 48 ~~~~~~~~~ • ~ ConocoPhillips Halliburton Company H~LIrIBURT ~~~ Compass Proposal Report - Geographic gperry Dritling Servlaes Point 1 0.00 62.09 5,951,823.00 566,126.00 Point 2 400.05 62.22 5,952,223.00 566,123.00 3,993.50 1J-122 MB_A2_CP6 04/11/07 5,817.11 7,254.72 5,951,522.56 566,071.70 - Polygon Point 1 0.00 56.31 5,951,523.00 566,128.00 Point 2 300.17 56.65 5,951,823.00 566,126.00 4,204.50 2,265.30 13-3/8 16 11,818.65 3,969.00 9-5/8 12-1l4 18,054.85 3,990.10 4-1/2 6-3t4 1,650.33 48.69 101.47 1,504.91 -126.53 494.54 Pfrost 1,893.72 56.21 100.76 1,657.88 -163.36 679.93 K15 3,017.64 76.48 99.31 1,987.83 -340.40 1,733.08 T3 4,204.89 76.48 99.31 2,265.39 -527.16 2,872.22 Casing Pt 7,243.24 76.48 8L22 2,975.71 -920.57 5,792.30 tJgnu C 8,524.50 76.48 39.32 3,275.25 -316.48 6,850.16 Ugnu B 8,854.16 76.48 28.54 3,352.32 -50.94 7,028.82 Ugnu A 9,663.97 76.48 2.06 3,541.64 701.76 7,234.77 K 13 10,368.70 77.41 1.76 3,701.06 1,388.01 7,251.40 W Sak D 10,600.42 77.41 1.76 3,751.55 1,614.06 7,258.34 W Sak C 10,779.79 79.06 2.98 3,787.06 1,789.68 7,266.40 W Sak B 11,006.98 79.06 2.98 3,830.18 2,012.43 7,277.99 W SakA4 11,338.43 79.06 2.98 3,893.09 2,337.43 7,294.90 W Sak A3 11,788.65 85.00 359.00 3,966.39 2,781.01 7,309.74 W Sak A2 28.00 28.00 0.00 0:00 SHL - 1837' FSL, 2347' FEL - Sec35-T11 N-R10E 11,818.65 3,969.00 2,810.89 7,309.22 9 5/8" Casing ~ 11819' MD, 3969' IVD: 636' FNL, 315' FEL - Sec36-T11 N-R~ 18,054.86 3,990.10 9,044.41 7,196.24 BHL (c~ 18055' MD, 3990' ND: 318' FSL, 422' FEL - Sec24-T11 N-R10E 5/9/2007 3:45:21PM Page 11 of 11 ' COMPASS 2003.11 Build 48 , ~~~'~{~~~+ \~. ~ ~ ~ • ~ ConocoPh ~ I I ~ ps Alaska P1an: 1 J-122 (wp06) Sperry Drilling Services Anticollision Summary 02 May, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1 J-122 1 J-122 Local Coordinate Origin: Centered on Well Plan 1J-122 - Slot 1J-122 Viewing Datum: Planned RKB @ 109.OOft (Doyon 141 (28+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet ~ HALLIBl.1RTC~N ~ ~ 8psrry Drtlling 8ervices ~~~~~~~~~ ~ 0 3 ~o a~~ a ~~r; N N o a N Z ~ ~ N ~ F c F ~ ~ W N ~ ~ N N O ~ N N d N ~O ~ ~rnu J L ~ C C J ~ Q y LL ~ K m H ~~~`m Z o,~E~ ¢ ~„~. aa~ `m °' 0 ~ C ` L Y ~ O N R Z V Q ~ N C .~ ? 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Date: 5/16/2007 3'ime: 91:03:04 ' Page: 1 Field: Kuparuk River UniC Reference site: Kuparuk 1J Pad'i Ca4rdinate(NE) Reference: We1t: Plan 1J-122, True North Reference Well: ~ Plan lJ-122 Vertical (TVD) Reference: C)oy4i~ 141 ~2$+81} 1 09.~ Reference WeDpath: ' Plan 1J'~122 Db:` Qrade GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.00 to 18054.87 ft Scan Method: Trav Cylinder No rth Maximum Radius: 2002.69 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/18/2006 Validated: No Version: 2 Planned From To Survey Toolcode Tool N ame ft ft 28.00 788.00 Planned: 1J- 122 (wp06) V7 CB-GYRO-SS Camera based gyro single s hot 788.00 18054.87 Planned: 1J- 122 (wp06) V7 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Casing Points ' MD TVl~ Diameter Hole Size Name' ft ft ' in in' 4204.89 2265.39 13.375 16.000 13 3/8" 11818.65 3969.18 9.625 12.250 9 5/8" 18054.87 3990.28 5.500 8.500 51/2" Summary {- ------------------- Offset Wellpath -- --------'-------~ Reference ' Offset Ctr-C#r No-Go i Allowable Site Well Wellpath MD ' MD Distance Area Deviatiou Warning , ~ift ft ft ft ft' Kuparuk 1 D Pad 1 D-141 1 D-141 VO Out of range Kuparuk 1 D Pad 1 D-141 1 D-141 L1 VO Out of range Kuparuk 1 D Pad 1 D-30 1 D-30 V6 Out of range Kuparuk 1 D Pad 1 D-30 1 D-30L1 V2 Out of range Kuparuk 1 D Pad 1 D-32 1 D-32 V5 18046.34 9750.00 915.59 148.65 766.94 Pass: Major Risk Kuparuk 1D Pad 1D-32 1D-32L1 V1 18046.34 9750.00 915.59 148.62 766.96 Pass: Major Risk Kuparuk 1 D Pad 1 D-32 1 D-32L1 P61 V1 18046.34 9750.00 915.59 148.62 766.96 Pass: Major Risk Kuparuk 1 D Pad 1 D-34 1 D-34 V6 16985.65 9475.00 596.05 249.72 346.33 Pass: Major Risk Kuparuk 1D Pad 1D-34 1D-34L1 V1 16986.50 9475.00 596.13 248.68 347.45 Pass: Major Risk Kuparuk 1 D Pad 1 D-34 1 D-34L1 P61 V1 16986.50 9475.00 596.13 248.68 347.45 Pass: Major Risk Kuparuk 1 D Pad 1 D-37 1 D-37 V4 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L1 V1 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2 V3 Out of range Kuparuk 1 D Pad 1 D-37 1 D-37L2PB1 V1 Out of range Kuparuk 1 D Pad 1 D-39 1 D-39 V2 Out of range Kuparuk 1 D Pad Prelim: 1 D-13 Prelim: 1 D-13 VO Plan: Out of range Kuparuk 1J Pad 1J-03 1J-03 V10 266.61 275.00 281.12 5.07 276.05 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L1 V2 266.72 275.00 281.12 5.07 276.05 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2 V1 266.72 275.00 281.12 5.07 276.05 Pass: Major Risk Kuparuk 1J Pad 1J-03 1J-03L2PB1 V1 266.72 275.00 281.12 5.07 276.05 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109 V1 10385.93 8950.00 345.93 128.81 217.13 Pass: Major Risk Kuparuk 1J Pad 1J-109 1J-109PB1 V3 10385.93 8950.00 345.93 128.81 217.13 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a L1 VO Pla 249.92 250.00 260.66 5.60 255.06 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a L2 V0 Pla 249.92 250.00 260.66 5.49 255.17 Pass: Major Risk Kuparuk 1J Pad 1J-109 Plan 1J-109a VO Plan: 249.92 250.00 260.66 5.65 255.02 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115 V2 298.28 300.00 140.19 5.15 135.04 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1 V1 298.28 300.00 140.19 5.02 135.17 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB1 V1 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L1PB2 V1 298.28 300.00 140.19 526 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2 V2 298.28 300.00 140.19 5.02 135.17 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2PB1 V4 298.28 300.00 140.19 526 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115L2P62 V3 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P61 V1 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115P62 V1 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB3 V1 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-115 1J-115PB4 V1 298.28 300.00 140.19 5.26 134.93 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118 V7 323.48 325.00 79.15 6.45 72.70 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L1 V4 323.48 325.00 79.15 6.32 72.83 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118L2 V3 323.48 325.00 79.15 6.32 72.83 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118PB1 V2 323.48 325.00 79.15 6.56 72.59 Pass: Major Risk Kuparuk 1J Pad 1J-118 1J-118P62 V1 323.48 325.00 79.15 6.56 72.59 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127 V6 864.17 875.00 65.52 15.80 49.72 Pass: Major Risk ~RI~4~A~: ~ Halliburton Company~ Anticollision Report Company: ; Fietd; ° ' Ret'ereqce Site: AeferenceiVelli '~ Referencs WeIIpat6: Summary ConocoPhillips Alaska Inc. Kuparuk River Unit . Kuparuk iJ P2d'` PI~I11J'-122 Plan 1J<122 Dat~: 5/'16120p7 Time; 1 L'~3:04 Page: ' 2 Co-ordinate(NEj Reference: ~ 1li/el~: Plart 1J-122, True North Verdcal(T'Vll)Referepce:" ~ DOyof~ 141 {2$~$1} 909.~ DS;; Or2cle ~;. ' <_-----°°--'---------- Offstt Wellpatk -----____---------> i Reference Offset Cfr-Ctr No-Go'' Allowable ' Site Well ` WellpatN MD MD - DistanCe Area : Deviation Warning ` 'ft I ft ft! ft ft! Kuparuk 1J Pad 1J-127 1J-127L1 V2 864.17 875.00 65.52 15.67 49.85 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1PB1 V2 864.17 875.00 65.52 15.91 49.61 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V1 864.17 875.00 65.52 15.67 49.85 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V1 864.17 875.00 65.52 15.91 49.61 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P62 V1 864.17 875.00 65.52 15.91 49.61 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V2 302.95 300.00 21922 5.80 213.42 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 L1 V2 Plan 786.03 775.00 230.00 12.62 217.38 Pass: Major Risk Kuparuk 1J Pad 1J-133 Plan 1J-133 VO Plan: 1 683.06 675.00 228.71 11.47 217.24 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136 V1 311.77 325.00 280.73 5.62 275.11 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1 V2 311.77 325.00 280.73 5.47 275.26 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1P61 V2 311.77 325.00 280.73 5.62 275.11 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136~1PB2 V3 311.77 325.00 280.73 5.62 275.11 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136PB1 V4 311.77 325.00 280.73 5.62 275.11 Pass: Major Risk Kuparuk 1 J Pad 1 J-164 1 J-164 V3 273.10 275.00 188.72 5.40 183.32 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L1 V1 273.10 275.00 188.72 5.27 183.45 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-964L2 V2 273.10 275.00 188.72 5.51 183.21 Pass: Major Risk Kuparuk 1J Pad 1J-164 1J-164L2P61 V1 273.10 275.00 188.72 5.40 183.32 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V5 273.33 275.00 165.73 5.17 160.55 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V3 273.33 275.00 165.73 5.04 160.68 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166~1P61 V3 273.33 275.00 165.73 5.04 160.68 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2 V1 273.33 275.00 165.73 5.28 160.45 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2PB1 V1 273.33 275.00 165.73 5.28 160.45 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168 V5 250.00 250.00 152.47 5.01 147.45 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V3 250.00 250.00 152.47 4.88 147.58 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V2 250.00 250.00 152.47 4.88 147.58 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2PB1 V1 250.00 250.00 152.47 5.12 147.34 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V2 273.75 275.00 145.84 5.50 140.34 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L1 V1 273.75 275.00 145.84 5.37 140.47 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V1 273.75 275.00 145.84 5.37 140.47 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB1 V1 273.75 275.00 145.84 5.61 140.23 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB2 V1 273.75 275.00 145.84 5.61 140.23 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180 V3 237.59 250.00 248.33 4.63 243.70 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1 V2 237.59 250.00 248.33 4.47 243.86 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1PB1 V1 237.59 250.00 248.33 4.63 243.70 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180P69 V1 237.59 250.00 248.33 4.63 24370 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L1 VO Plan 296.24 300.00 320.17 6.23 313.94 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 L2 VO Plan 296.24 300.00 320.17 6.23 313.94 Pass: Major Risk Kuparuk 1J Pad Plan 1J-107 Plan 1J-107 V1 Plan: 1 296.24 300.00 320.17 6.36 313.81 Pass: Major Risk Kuparuk 1J Pad Plan 1J-111 Plan 1J-111 V1 Plan: 1 8989.20 9100.00 318.88 113.45 205.42 Pass: Major Risk Kuparuk 1J Pad Plan 1J-112 Kuparu k Plan 1J-112 W Lat VO P 308.99 325.00 200.37 6.05 194.32 Pass: Major Risk Kuparuk 1J Pad Plan 1J-119 (M15 P h~lan 1J-119 VO 28.00 99.00 59.94 No Offset Stations Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L1 V2 Plan 348.99 350.00 40.35 6.78 33.57 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 L2 V0 Plan 348.99 350.00 40.35 6.78 33.57 Pass: Major Risk Kuparuk 1J Pad Plan 1J-120 Plan 1J-120 V2 Plan: 1 348.99 350.00 40.35 6.93 33.42 Pass: Major Risk Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L1 VO Plan 10775.00 10775.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-122 Plan 1J-122 L2 VO Plan 10350.00 10350.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 513.18 525.00 16.79 10.33 6.46 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V2 Plan: 1 1377.09 1375.00 40.20 24.40 15.80 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V2 Plan: 1 1968.16 1925.00 89.34 37.39 51.95 Pass: Major Risk Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V2 Plan: 1 1457.19 1425.00 142.54 26.88 115.66 Pass: Major Risk Kuparuk 1J Pad Plan 1J-132 1J-132 V2 Plan: 1J-132 946.12 925.00 193.39 16.50 176.90 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 L1 V2 Plan 261.90 275.00 216.79 5.76 211.03 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 Plan 1J-162 V5 Plan: 1 261.90 275.00 216.79 5.81 210.98 Pass: Major Risk Kuparuk 1J Pad Plan 1 J-173 1 J-73 Kuparuk Producer 310.76 325.00 158.04 5.98 152.06 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V1 Plan: 275.20 275.00 166.86 5.95 160.91 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 VO Plan 275.20 275.00 166.86 6.06 160.80 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 L1 VO Pla 274.47 275.00 188.90 5.11 183.79 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan: 1J-176 VO Plan: 274.47 275.00 188.90 5.11 183.79 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V2 Pla 262.85 275.00 216.74 5.55 211.19 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 V2 Plan: 262.85 275.00 216.74 5.55 211.19 Pass: Major Risk Kuparuk 1J Pad Plan 1J-L14(BQ) Plan 1J-L14(BQ) VO Pla 3697.90 3425.00 324.13 89.93 234.20 Pass: Major Risk Kuparuk 1J Pad Plan 1J-115(BP) Plan 1J-L15 D Latera~ 9098.29 8350.00 112.29 133.98 -21.69 FAIL: Major Risk Kuparuk 1J Pad Plan 1J-Q14 (BM) 1J-Q14 B Lateral VO PI 659.41 625.00 321.26 10.86 310.40 Pass: Major Risk oR~~~~AL ~alliburton Company ~ Anticollision Report ,~ciu. ~:: r~uNawn rcrvc~ vnn Zeference Site: ; Kuparuk 1J Pad' Co-ordinate(NE) Reference: Well: Plan 1J-122, True NOrth ieference Well: Plan 1J-122 Vertical (TVD) Reference: Doyon 141 (28+$1) 109.OI ' ieference Wellpath: Pian 1J-122 i Db: Orac Summary <-______~_________ p[gset Wellpath ----- ------'------~ < Reference Offset Ctr-Ctr No-Gol Al[owable ! Site ' Well Wellpath MD MD Distance Area '' Deviation• Warning ft ' ft ft' ft' ft' Kuparuk 1J Pad Plan 1J-Q15(BO) 1J-Q15 D Lateral VO PI 719.14 675.00 358.15 12.18 345.97 Pass: Major Risk Kuparuk 1J Pad Rig 1J-135 Plan 1J-135 L1 VO Plan 530.38 525.00 257.74 8.60 249.14 Pass: Major Risk Kuparuk 1J Pad Rig 1J-135 Plan 1J-135 V0 Plan: 1 530.38 525.00 257.74 8.75 248.99 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-105 Plan: 1J-105 L2 VO Pla 295.81 300.00 360.27 6.30 353.97 Pass: Major Risk Kuparuk 1J Pad WSP-02 WSP-02 V4 337.69 350.00 241.88 5.77 236.10 Pass: Major Risk Kuparuk 1J Pad WSP-03 WSP-03 V1 398.84 400.00 184.00 9.79 174.21 Pass: Major Risk Kuparuk 1J Pad WSP-04 WSP-04 V1 340.23 350.00 123.77 5.53 118.24 Pass: Major Risk Kuparuk 1J Pad WSP-05 WSP-05 V1 485.49 500.00 69.12 11.56 57.56 Pass: Major Risk Kuparuk 1J Pad WSP-06 WSP-06 V1 663.51 675.00 19.91 16.34 3.58 Pass: Major Risk Kuparuk 1J Pad WSP-07 WSP-07 V1 791.24 800.00 30.08 22.98 7.10 Pass: Major Risk Kuparuk 1J Pad WSP-08 WSP-08 V2 908.78 900.00 78.66 27.55 51.11 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V1 975.39 975.00 131.05 22.31 108.74 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V1 1023.23 1000.00 176.49 23.40 153.09 Pass: Major Risk Kuparuk 1J Pad WSP-11 WSP-11 V1 1153.94 1150.00 237.24 25.14 212.10 Pass: Major Risk Kuparuk 1J Pad WSP-12 WSP-12 VO 1123.60 1100.00 294.79 25.23 269.56 Pass: Major Risk Kuparuk 1J Pad WSP-20 WSP-20 V1 299.25 300.00 221.77 6.34 215.43 Pass: Major Risk ~~~~~~~~~~.~_ _ . r i ~ ~ ~ ~ ~ ~ ~ ~ 1J-122 L2 (wp06) 1/4 Mile Pool Scan Sperry Drilling Services May 1, 2007 i ~ HALLIBURTON Drilling and Formatiion Evaluation ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Closest in POOL ~,.,~ .~..~ ~ O ...r ~ ~ ~ Closest A roach: Reference Well: 1J-12 2 L2 w 06 Plan Offset Well: 1 D -34 3-D ctr-ctr Distance. N~rizs~~~al ~~ ~. w•u~;M~<s ~" ";c.renc~ Meas. De th ncl. Angle RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (0°) omments Meas. De th ncl. An le RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E(+)/W(-) View VS (0°) omments y~,~~ ~ ~ ^~c .~~-+d 7550 9.57 58.99 665.908 954269.6 66000J 563.826 POOL Min Distance (797.98 ft) in POOL (10368.7 - 18031.58 MD) to 1D-34 (7883.33 - 8767.23 MD) 786.54 7.41 57.41 961.71 954244.1 65260 5012.22 POOL Min Distance (797.98 ft) in POOL (10368.7 - 18031.58 MD) to 1J-122 L2 (wp06) Plan (7883.33 - 8~67.23 MD) Closest A roach: Reference Well: 1J-12 2 L2 w 06 Plan Offset Well: 1J-109 3-D ctr-ctr Distance ~ 9~ .:Wu ~-,~1 ~=~~r ~ ~~a~d~ ~ I.`~~~ ~> ~~~ Meas. De th ncl. An le RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E+/W(- View VS 0° omments Meas. De th nG. An le RUE Azi. Subsea TVD Coords. - ASP N(+)/S(-) E+/W - View VS 0° omments 711.24 "r'1 ';i 'I "~xe>n 0368.7 7.41 76 592.183 947094.4 66103J 388.02 POOL Min Distance (1711.24 ft) in POOL (10368 - 18031.58 MD) to 1J-109 (10850 - 15160 MD) 0840.27 0.91 78.58 633.31 945810.9 67234.8 157.02 in istance (1711.24 ft) in POOL (10368 - 18031.58 MD) to 1J-122 L2 (wp06) Plan (10850 - 15160 MD) POOL Summary Template.xis 5I1I2007 2:18 PM ~RI~II~AL ORlGINAL 1~-122 rillinq Hazards ummarv (SEE WELL PLAN AND ATTACHMfNTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned rnud parameters, Gravels Increase mud weight, use weighted swee s. Hofe swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets um in out Intermediate Hole I Production Hole Nazard Risk Level Miti ation Strate Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo , LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in o~rt Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping driils, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWDtools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole fillin sheets , um in out, backre ~ ~ ~ ~ ~ ~ ~ ~ g (use of trip amin 9J-122 Drillrng Hazards Summary 5/23/2007 2:59:00 PM CemCaUE Pr~lrm~nary Job Ues~gn = f 3: ~/8" Sur~ace Preliminary Job Design based on limited input data. For estimate purposes only. ~ . ~ . Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 5/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@sib.com < TOC at Surtace Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,650' MD (1,500' TVD) < Top of Tai l at 3,404' MD < 13 3/8", 72.0# casing in 16" OH TD at 4,204' MD (2,265' TVD) Mark of Schlumberger Volume Calculations and Cement Svstems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 3,404' MD. Lead Slurrv Minimum pump time: 330 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x(80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x(1650' - 80') x 3.50 (250% excess) = 2311.2 ft3 0.4206 ft3/ft x(3404' - 1650') x 1.35 (35% excess) = 995.9 ft3 81.5 ft3 + 2311.2 ft3+ 995.9 ft3 = 3388.6 ft3 3388.6 ft3 / 4.45 ft3/sk = 761.5 sks Round up to 770 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 240 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x(4204' - 3404') x 1.35 (35% excess) = 454.2 ft3 0.8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = - 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 50~, Estimated BHCT = 71 `F. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative ~tage Volume Time ~bpm~ (bbll (min) (minl CW 100 5 50 10A 10A Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 33.3 Lead Slurry 7 610 87.1 120.4 Tail Slurry 6 97 16.2 136.6 Drop Top Plug 8.0 144.6 Water 5 20 4.0 148.6 Switch to Rig Pum s 5.0 153.6 Displacement 7 571 81.6 235.2 Slow Rate 3 20 6.7 241.9 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spaeer Properties: 10.5 ppg MudPUSH* II, P~ = 17-21, TY = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~ ~ ~ ~ ~ ~~ ~ C~mCAC7E Preliminary Job:Desic~n - , ~~ 9.82~" Ir~te~medi~te ~asin ~~ _ __-_ ~~ ~ ~ ~ ~ ~ ~ Preliminary Job Design based on limited input data. For estimate purposes only. ~ ~ ~. Vo~ume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation -(Ugnu C at 7266' MD, TOC at 6750' MD, 5068' MD annular length). Tail Slurrv Minimum thickening #ime: 340 min. (Pump #ime plus 120 min.) DeepCRETE C~ 12:5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 5068' x 1.25 (25% excess) = 1984.1 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1984.1 ft3 + 34.1 ft3 = 2018.2 ft3 2018.2 ft3/ 2.25 ft3/sk = 897.0 sks Round up to 900 sks BHST = 94~, Estimated BHCT = 60~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbll ~min) (min) CW 100 5 75 15A 15A Drop Bottom Plug 10.0 25A MudPUSH II 5 75 15A 40.0 Tail Slurry 6 361 602 100.2 Drop Top Plug 10.0 110.2 Water 5 20 4.0 114.2 Switch to Rig Pum s 5A 119.2 Displacement 7 800 114.3 233.5 Slow Rate 3 70 23.3 256.8 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH* II, P~ = 19-22, TY = 22-29 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. ~~~ Vf~~~ r a,_ ~ ~ ..•+~ ~ ~ 20" 94.0# x 34" Insulated Conductor, K-55, set at+~_ 80' 13318", 66#, TC " Shoe set @ 04' MD, 2265' ND Tubing String 4712" 12.6#, L-S0, IB 3.958" ID, 3.833" Drift 7" X 9SI8" ZXP Liner p„ Top Packer w/ Hold 4.75" ~~s Tubing, 41/2", 12.6#, IBTM, Special Drift to +/- 500' 3.875" DB Nipple, for Possible SSSV, +/_ 500' GLM, Camco KBMG, 41/2" X 1" GLM, Camco KBMG, 41/2" X 1" CMD Sliding Sleeve, w/ 3.81" DB Nipple, +/- 1 jt above seals ConocoPhillips West Sak 9-5/8" HBB Injector 1 J-122 Tri-Lateral Completion WP 06 r Casing Sealbore Receptaele, 20' Length / Lateral Entry Module(LEM) D-sand Window t 10368~ M~, 3701' ND 'D' Sand Lateral 4112" 11.6# L-80 Slotted Payzone ECP Liner EveryIOther Joint . ~ 1 .. i 4-112" Guide Shoe ~ 4112" Liner Shoe, 11.6il, L-80 BTC 7" Tieback Sleeve Set @ 18031' MD, 3778' ND ~4-112" bent muleshoe Seal Assembly 4.75" Seal OD ~ ~ Lateral Entry Module(LEM) .~.. ~~s Baker Oil Tools As Planned Lateral Entry Module (LEM) With Diverters and Isolation Lateral Access Diverter Laterel Isolation Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbore Drift) 'GS' ProTik tor Coil Connector fRunnmg/Retneving ~ (t 00' LengM) Snap In/Snap Out f P~artrve Locapng~ rBack Pressure Valve Collet (1.80' Length~ ~ ~ I I Lateral Isolation ~' ~Flow-Thru Swivel ~~ Seals (115' Length) Latenl ~iverter ~ Hydraulic ~ ~ Ramp ~ ' oisconnea ~ I ' N Mainbore I l d (1.50' Length) i ao a o i Diverter Sleeve '. ~GSSpear /~ ~ ~ (7.50' Length) Lateral lsolation 6.85 ft Approx. Seals OAL' I T' X 9-518" S I Bore Model'B'HOOKHanaer 3. "ID 7" X 9-518'• Packer wl Hol Assemblv .--- 7" X 9318" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Pmtile Automatic Alignment of LEM Positive latching Collet Indicates Correct Location ~ Seal Bore for Lateral Isolation - 3.68" ID ~ Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID ~ Isolation Seal Asembly 4.73" Seal OD 3.875" Seal ID / B-sand Window singseaibo at10779'MD,378TND ~B' Sand Late ral cepqcle / 20 ength ` 4-112" 11.6# L~0 Slotted Payzone ECP Liner Eve Other Joint ry Equipment Specification~ "> ~,, 4-112" Guide Shoe .: .n. . ,.,.. ,. ,« . .. X 9518" . 7" X 9-5/8" HOOK Hanger 4112" Liner Shoe, 11.6#, L-80 BTC Mainbore Driit: 7.00" Set ~ 18039' MD, 3645' ND Mainbore Drift, with diverter: 6.25" Seal Bores 7" Tieback Sleeve Lateral Drift, no diverter or LEM: 6.28" .68" ID 4-112" bent muleshoe Lateral Drift, wl diverter, no LEM: 5.12" 3.562" DB Nipple LaterallMainbore Diverter OD: 8.50" 4-112" 12. Tubin 3.833" ift -- _ ¢'IIZ" Laterai Entry Module 3.958" I '~\ ~ Mainbore Drift: 3.68" \ _ ,.... 7" X 9-518" 2 -.___ Mainbore Drift, wl isolation sleeve: 2.50" .__. Liner Top Packer ~~~ Seal Assembly .._._._.. . -- _, ~- '" "-~ --~-~ -- - Lateral DrRt, wl coil diverter: 3.00" with Hold Downs 4.75" Seal OD OD of Diverter and Sleeve: ~l- 3.60 ~A' Sand Undulating Lateral ~~~, Diverterand5leeveLength:+1-19' 7" X 9-5/8" Flex L k \ ~ 5-112" 15.5 # L-80 Slotted Liner Hanger I PackerAssembly at Liner Hange +l 10880' MD 3787 ND Liner Every Other Joint 5-~~2~~ Eccentric / GuideShoe t.S e- ~~~~ , .. - Casing Sealbore R tacle, ~ ~ j ~~~' 5-1/2" C sing Shoe, 15.5 #, L$0 BTC 20' Length ~~ Se [ ~ 18054' MD, 3990' ND 9-5/S" 40 # Casing, - et 98ake~ Xu ~es 2005. Thls document ma ~ n~ ~e oa~oea o~ m:o-m~e<a, io wnoie a. i~ n, io +o ro.ma~ n at 11818' MD, 3969' ND (84 deg) ~""` 9 yno pr Va y y ~ 9-52" TA-lafenl Completlon -In)actor any m s electronic or mec~anlcal, Inclutling photxopying, recortling, or Ey any Informatlon storaqe antl Datc: wawn ey: ReNSwn xo.: retrieval syshm now knovm or hereatler Invented, withoutwrltten permisslon fran Baker Mughes Inc. May 34, 3007 Mare D. Kuck 0 ~ ~ SHARON K. ALLSUP-DRAKE CONOCOPHILLIPS ATO 1530 700 G ST. ANCHORAGE AK 99501 PAY TO THE S~/~ T~ ~~ ORDEH OF ; ; ~ 1185 DATE ~S "` ~~ 56-1551/441 C~ ~C $ ~~o. d~ / ~_ ~~,p, o l ~a DOL- LARS "IJ "~.",~~~ JPMorganChase ~~ Valid Up To 5000 Dollars JPMorgan Chase Bank, N.A. Columbus, OH ~~ --~ --~~ - MEMO ----- ----------- ~ ~:044i155LL~' 2 ?47 90 7u' ~ .5 8 L 792 Li85 : ~ • ~'RANSI~IT'I'AL LETTER ~~IECKLIS'I' vvE~,L r~~NtE ,E'~L~ /~' /Z Z- - ~TU# 2a ~ - d ~l-~ Development ~Service Exploratory Stratigraphic Test Yon-Conventiona! Well Circie Appropriate Letter / Pacagraphs to be Included in Transmittal Letter ' CE-~CK I ADD-ONS ; T'EXT FOR APPE~OVAL LETTER ~ ; VVHAT ~ (OPTIONS) i ~ i APPLIES ~ ~ ~ ! ~ - ~ ~ ~ MliLTI LATER.AL ~ The permit is for a new wellbore segment of existing ! ~ i i ~ we[[ ; I (If [ast two digits in Permit ~to. , APt No. ~0- - - ' ; API number are ; ~ ~ ; between 60-69) ; Production should continue to be reported as a function of the i ; original 4PI number stated above. ~ ~ P[LOT HOLE i[n accordance with 20 A.4C 2~.00~(~, all records, data and (o~s ! ~ acquired for the pilot hole must be clearly differentiated in both i i ; ~vell name ( PF~ and API aumber ~ ; ~~~p_ - -_~ from records, data and lo~s ~ ~ ~ acquired for we(1 ~ ~ SPACING The permit is approved subject to futl comptiance with 20 AAC ~ ' EXCEPTION ; 2~.0». Approvat to perforate and produce / inject is contingent ~ ~ ,' I upon issuance of a conservation order approving a spacing i ; j ~ exception. assumes the ~ i i i liability of any protest to the spacing exception that may occur. i ~ ' ; DRY D[TCH ~ ; Al( dry ditch sample sets submitted to the Commission must be in ; ~ i SA!~IPLE I no ;reater than 30' sample intervals from below the permafrost or : ; ! I from where samptes are f rst caught and 10' sample intervats j ; ~ ~ i ~ through tar;et zones. , , ~ ; Please note the foliowing specia! condition of this permi*: ~ ' ~ Non-Conventional ( i production or production testing of coa! bed methane is not allowed ' i~~z« i ' for jname of well) until after ~Com~anv Name) has designed and ! : i , ! implemented a water wel[ testing program to provide baseline data ~ ~ ; on water quality and quantity. (Company Name) must contact the ~ ~ ' Commission to obtain advance approval of such water weil testing ; , ~ I ~ program. Rev: i!2~i06 C:`jody~transmittal_checklist Field & Pool KUPARUK RNER, WEST SAK OIL - 490150 Well Name: KUPARUK RIV U WSAK 1 J-122 Program SER Well bore seg ^ ______ PTD#:2o70700 Company CONOCOPHILLIPS ALASKA INC __ Initial ClassfType SER! PEND GeoArea 890 Unit 11160 On/Off Shore On Annular Disposal ^ Administration 1 Permitfeeattached____________________________________ ______ __Yes_ ____.__ ._._____ 2 Lease number appropriale_ _ _ _ _ _ _ _ _ _ _ _ Yes . _ _ _ _ _ _ Surface location and top_ injection interval in ADL 025661; TD_in ADL 025650_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 3 Uniquewell_nameandnumb_er --------- -- -- - -- - Yes- --- - - - - -------- -- -- --- --- - -- - ---- 4 Welllocat_edin.a_defined_pool___________ __________________ _________ Yes. ______KuparukRiver,West_Sa_kOilPoo1-490150,_goyernedby.C0406B_____,__,__________ 5 Well located proper diskanCe from drilling unitboundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ CO 406B, Rule 3; no restrictions as to well &p_acing ~xcept that no.pay shall be opened in a well closer _ _ _ _ _ _ _ 6 Well located proper distance from other welis_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . . _ _ _ _ than 500 feet to_an external.prope[ty line where ownership or la_ndownership changes_. _ _ _ _ _ _ . _ . . _ _ . _ _ _ _ 7 Su_fficient acreage_availablg in_drilling un_it_ _ _ _ _ , _ _ _ Yes _ _ _ _ . _ , Well is more than_ 500 feet from an extema_I property line_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 8 Ifdeyiated,is_weliboreplatincluded__________________________ ____ ___ Yes_ __. 9 Operator only aff_ected parky- - - - - Yes - - - - 10 Ope(atorhas_appro~riatebondinforce-- - ----- ----- --- Yes -- -- -- ------ -- - ----- -- -- -- ------ - -- ~ 11 Permit can be issued without conservation order Yes ( - - - Appr Date ~Z Petmikcanbeissued_w_ithoutadministrative_approval________________ _________ Yes. ____________________ -- SFD 5130/2007 ~ 3 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata a~thqrized by Inje~tion 0[der # (put 10# in_comments)_ (For_ Yes . _ _ . . _ _ Area Injection Order No._ 2B _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 15 All wells_within,il4_mile area of reyiew identified (For se_rvice well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ . _ _ . KRU 1 D-34,_KRU_ 1J=109 _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ -- -- -- ------- -- -- 16 Pre-produced injector: dur_ation_of prepCOduction less than 3 months_ (For_service well on_ly) _ _ Yes _ . _ _ , , . KRU 1J-122_a_nd late_rals will be pre-p(oduced on gas-lift for about 45 days__ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 17 _Nonconven, ga_s conforms t4 AS31.o5,030(j.1_.A),Q.2.A-D) _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ _ . _ _ -- Engineering 18 C~nductorstring.provided____________________ Yes_ ____________.__ 19 Surfacecasingprotectsall_known.USDWs__..._____ _ ___ NA__ ,_____Allaquifersexempted,40CFR.147.102(b~(3).._________________________________ 20 CMT_vol_adequate_to circul_ate_on conductor & surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . _ _ _ _ _..- 21 CMT.voladeguate_totie-inlongstnng#o_surfcsg___________________ _________ No._ ____._Any_hydrocarbonswillbecove[ed._,____.___.___..___.____,______ 22 CMT_willcoyer_all_known_productiyehorizon_s_________ ___________ _________ No__ ______Slotted_linercompletionplanned.___________________________ -- 23 CasingdesgnsadequatefotC,T,B&_permafrost----------------- ---...,._Yes ---- ------------- ---..-.------------------------------ -------------- 24 Adequate tan_kage_or reserue pii _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ Rig is.equipped with sleel_pits. _ No reserve_p_it_planned. All waste to_appr_oyed annulus_or disposal well(s), _ _ _ _ 25 If_a, re-drill, has_a 10-403 for abandonme_nt been approved _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ . _ ~ 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Proximity ~nalysis perfo[med, T[ayeling cylinder path calculaled, Gyros likely_in su_rface hole: _ _ _ _ _ _ _ _ _ . _ _ 27 lfdive[terrequired,doesitmeetregulations._._._. - Yes_ __________________________________..___._,_._________._._________________ Appr Date 28 Drilling fluid_program schematic_& equip list adequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _ Maximum expected fo[mation pressure 8,6_EMW_ Planned MW up to.9.1_ ppg, . , _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ TEM 6l10l2007 29 _B_OPEs,_d_otheymeetregulation----------------- Yes- ----------- --- --------.-.---------------------------------_--__- ---- yf (~~(~,,, ~ ,\' 30 BOPE_press rating appropriate; iest ko_(Put psig in comments)- - - - - - - - - - - - - - - - - - - - -Y_es - - - - - - - MASP calFulated at 1362psi. 3K st_ack arrangement and BOP_test planned.- - - . - - _ - - - - - - - - - - - - . - - , G ~Y 1 31 _C_hoke_manifoldcomplieswlAPI.RP-53(May84)___________________ ________ Y_es_ ________.______ 32 Workwilloccurwithoutoperationshutdown_____________________ __,..__._ Yes_ ___________ 33 Is presence of H2$ gas, prqbable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ . _ _ _ _ _ _ H2S has only been_reported in 1,1-166, nearly 2 miles di&tant._ Mud &hould preclude H2$ on_rig, Rig_h_as s~nsor. 34 Mechanical_condition of wells within AOR verified (For_ se[vice well only~ _ _ _ _ _ . _ _ Yes _ _ _ _ _ _ _ _ . and alarms. . ..2 wells in.AOR. Cementing_records satisfa_cto_ry_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Geology 35 Permit. can be issued wlo hydrogen_ sulfide measu[es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ ^ . --- _ _ . . _ _ To date W Sak welis from.l J-Pad measu_re 0 ppm H2S, with the single exception of 1J-166 which measured. , _ . 36 Data.presented on potential oyerpressu[e zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ , _ _ _ _ 25 ppm H2S. This well wil~ be 1.7 mi from ~1 J-166. _Expected reservoir pressure_is 8.6 ppg EMW, will be _ . _ _ _ Appr Date I 37 Seismic analysis of shallow gas_zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA _ _ _ _ _ _ _ drillQd with_9.0-9.1 p~g mud. No shallow gas_expected._ Mud_pro~tam notes use of 9,6 ppg _ _ _ _ _ . . . SFD 5l30120~7 38 Seabed condition surve _ rf_ off-sh_ore _ _ _ _ _ _ _ _ _ _ _ _ _ y~ ~ NA_ _ _ _ , _ _ . mud if h drates are encountered. Miti ation measures discussed_ in Drillin _Hazards $umma Y 9 9 ry~-- 39 Contact namelphone fo_r weekly_progress ieports [exploratory oNyj _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ . _ _ Geologic Engineering Public Date: Date Date West Sak A2 sand in ector. This will be the the main well bore for a trilateral, horizontal in ection well. SFD 1 1 Commissioner: Commissioner: Co mi ioner prs ~I~,~~ ~;~~, ~~3-~~ ~~2-~ a~ ~ ~ ~ Well History File APPE~IDIX Information of detailed nature that is not ~ particulariy geRnane to the Welf Permitting Process but is part of the history file. To improve the readability of the We~l History file and to sim.plify i~inding information, information of this nature is accumulated at the end of the file under APPENDIX. No special efifort has been made to chronologically _ organize this category of information. , ~ 1712200704200755N.txt Sperry-Sun Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue oct 02 16:08:28 2007 Reel Header Service name .............LISTPE Ddte . ...................07/10/02 Ori in ...................5T5 RC'.e~ Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/10/02 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 w-0005034903 P . ORTH G. WHITLOCK # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD ~ Scientific Technical Services ~ibrary. Scientific Technical Services 1J-122 500292335900 ConocoPhillips ,alaska, znc. Sperry ~rilling services 02-OCT-07 MWD RUN 3 MWD RUN 4 w-0005034903 w-0005034903 T. GALVIN T. GALVIN D. GLADDEN D. GLADDEN 35 11N lOE 1836 2347 109.00 81.00 Page 1 ao'~-D~a ~ 15~33 • 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 17122007042007SSN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3640.0 8.500 9.625 11928.0 ~ l. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE IS AN OPENHOLE SIDETRACK EXITING THE 1J-122 PB1 WELLBORE AT 3643'MD/2213~ND. 1J-122 PB1 COMPRISED MWD RUN 1, WHICH WAS DIRECTIONAL ONLY. THIS RUN TD'D AT THE 13 3/8~~ CASING POINT. THE CASING STUCK 446' OFF BOTTOM, NECESSITATING THE SUBSEQUENT OPEN-HOLE SIDETRACK. NO DATA ARE PRESENTED FOR MWD RUN 1/1J-122 PB1. 4. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP) . 5. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL 1J-122 WITH API#: 50-029-23359-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15109'MD/3961'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). $ File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Page 2 L~ 1712200704200755N.txt Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH GR 3608.5 FET 3630.0 RPD 3630.0 RPS 3630.0 RPM 3630.0 RPx 3630.0 ROP 3644.5 $ ~ all bit runs merged. STOP DEPTH 15071.5 15064.0 15064.0 15064.0 15064.0 15064.0 15109.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO MERGE TOP 2 3608.5 3 9721.0 4 11932.0 # REMARKS: MERGED MAIN PASS. $ MERGE BASE 9721.0 11932.0 15109.0 # ~ata Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn Optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam rtep code offset channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3608.5 15109 9358.75 23002 3608.5 15109 RPD Mw~ OHMM 2.69 2000 23.0923 22869 3630 15064 Page 3 ~ ~; 17122007042007SSN.txt RPM MwD OHMM 4.67 2000 19.2082 22869 3630 15064 RPS Mw~ OHMM 3.81 2000 16.8717 22869 3630 15064 RPx MwD OHMM 1.27 2000 15.1925 22869 3630 15064 FET MwD HOUR 0.12 104.12 1.09148 22869 3630 15064 GR MwD API 19 130.41 68.0667 22927 3608.5 15071.5 ROP MwD FT/H 1.3 504.03 219.626 22930 3644.5 15109 First Reading For Entire File..........3608.5 ~ast Reading For Entire File...........15109 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/02 Maximum Physical Record..65535 File Ty e ................LO Next Fi~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3608.5 9685.0 FET 3630.0 9677.5 RPx 3630.0 9677.5 RPS 3630.0 9677.5 RPM 3630.0 9677.5 RPD 3630.0 9677.5 RoP 3644.5 9721.0 $ # LOG HEADER DATA DATE LOGGED: 27-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9721.0 TOP LOG INTERVAL (FT): 3643.0 BOTTOM LOG INTERVAL (FT): 9721.0 BIT ROTATING SPEED (RPM): Page 4 ~ HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # # # # # # 1712200704200755N.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet Data rteference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... ~atum specification Block sub-type...0 69.4 79.3 ~ TOOL NUMBER 132484 77613 12.250 3640.0 Other 9.50 49.0 9.1 150 4.9 3.800 72.0 2.540 111.0 5.000 72.0 3.000 72.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP NtwD020 FT/H 4 1 68 28 8 First Last Page 5 ~ ~ 1J1220070420075SN.tXt Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3608.5 9721 6664.75 12226 3608.5 9721 RPD MWD020 OHMM 2.69 2000 13.8095 12096 3630 9677.5 RPM MwD020 OHMM 5.07 51.95 11.6633 12096 3630 9677.5 RP5 Mwo020 OHMM 3.81 1301.51 11.377 12096 3630 9677.5 RPx MwD020 OHMM 1.27 45.01 9.60062 12096 3630 9677.5 FET MwD020 HOUR 0.12 104.12 0.744482 12096 3630 9677.5 GR MWD020 API 19 118.52 63.2932 12154 3608.5 9685 ROP MwD020 FT/H 6.45 504.03 226.4 12154 3644.5 9721 First rteading For Entire File..........3608.5 ~ast Reading For Entire File...........9721 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/02 Maximum Physical Record..65535 File Type ................~0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/02 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......STSLIB.002 comment rtecord FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9678.0 11888.0 RPS 9678.0 11888.0 RPx 9678.0 11888.0 RPM 9678.0 11888.0 RPD 9678.0 11888.0 GR 9685.5 11895.5 RoP 9721.5 11932.0 $ # LOG HEADER DATA DATE LOGGED: 29-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11932.0 Page 6 ~~ ~' 17122007042007SSN.txt TOP LOG INTERVAL (FT): 9721.0 BOTTOM LOG INTERVAL (FT): 11932.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 77.6 MAXIMUM ANGLE: 85.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132484 EWR4 ELECTROMAG. RESIS. 4 77613 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 3640.0 # # # # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: # Data Format Specification Record D1td Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units......... .Feet ~ata Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth Units. . .. .. ..... Datum Specification Block sub-type...0 other 9.50 43.0 9.0 50 4.5 3.800 72.0 2.460 115.0 5.000 72.0 3.000 72.0 Name Service Order Units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP ~WD030 FT/H 4 1 68 28 8 Page 7 ~ ~ 17122007042007SSN.txt First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9678 11932 10805 4509 9678 11932 RPD Mw~030 OHMM 5.14 61.16 13.6154 4421 9678 11888 RPM Mw~030 OHMM 4.79 72.11 13.6885 4421 9678 11888 RPS MWD030 OHMM 4.47 70.85 12.7945 4421 9678 11888 RPx MwD030 OHMM 4.03 45.78 10.5621 4421 9678 11888 FET Mw~030 HOUR 0.16 31.3 1.12052 4421 9678 11888 GR MWD030 API 28.72 124.04 80.6265 4421 9685.5 11895.5 RoP Mw~030 FT/H 8.25 406.01 209.796 4422 9721.5 11932 First Reading For Entire File..........9678 ~ast Reading For Entire File...........11932 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 oate of Generation.......07/10/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/10/02 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE RPM RPX RPD FET RPS GR ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 11888.5 11888.5 11888.5 11888.5 11888.5 11896.0 11932.5 SURFACE SOFTWARE VERSION: STOP DEPTH 15064.0 15064.0 15064.0 15064.0 15064.0 15071.5 15109.0 Page 8 04-JUL-07 Insite ~ ~ 1J12200704200755N.txt DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 15109.0 TOP LOG INTERVAL (FT): 11932.0 BOTTOM LOG INTERVAL (FT): 15109.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: $7.2 MAXIMUM ANGLE: 92.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119546 EWR4 ELECTROMAG. RESIS. 4 145654 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 11928.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (s): 59.0 MUD PH: .O MUD CHLORIDES (PPM): 18000 FLUID LOSS (C3): 4.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 129.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ..........0 ~ata specification slock Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata rteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 ~epth units. . .. .. ..... Datum Specification Block sub-type...0 Name Service Order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MWD040 HOUR 4 1 68 20 6 Page 9 ~ ~ 1J122007042007SSN.tXt GR MWD040 API 4 1 68 24 7 ROP MWD040 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11888.5 15109 13498.8 6442 11888.5 15109 RPD MWD040 OHMM 4.68 2000 47.3653 6352 11888.5 15064 RPM MWD040 OHMM 4.67 2000 37.4176 6352 11888.5 15064 rtPS Mw~040 OHMM 4.54 2000 30.173 6352 11888.5 15064 RPx MwD040 OHMM 1.48 2000 29.0639 6352 11888.5 15064 FET MwD040 HOUR 0.17 91.11 1.73205 6352 11888.5 15064 GR MWD040 API 33.17 130.41 68.4588 6352 11896 15071.5 ROP MwD040 FT/H 1.3 450.6 213.509 6354 11932.5 15109 First Reading For Entire File..........11888.5 ~ast Reading For Entire File...........15109 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/10/02 Maximum Physical Record..65535 File Type ................LO Next File Name...........5T5LIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/10/02 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................5T5 LIS Writing ~ibrary. scientific Technical services Reel Trailer service name .............LISTPE Date . ...................07/10/02 Ori 9in ...................STS RCC'I Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LIS Writing Library. Physical EOF Physical EOF Scientific Technical services Page 10 ~ ~ 17122007042007SSN.txt ~nd of ~IS File Page 11