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206-064
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Date:Monday, October 17, 2022 10:00:56 AM Attachments:image002.png image003.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Sunday, October 16, 2022 1:55 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com> Subject: LPP/SSV Returned to Service on Well 1J-170 on 10/16/2022 Good afternoon Jim, The low-pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the “Facility Defeated Safety Device Log” on 10/16/2022, as the well was shut in post-diagnostics work. The LPP had been defeated on 10/14/2022 after a significant injection pressure reduction (due to well communication with an offset producer) could not satisfy the LPP. This notification is in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, October 14, 2022 12:03 PM To: 'Regg, James B (DOA)' <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Regg, James B (OGC) To:AOGCC Records (CED sponsored) Subject:FW: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Date:Friday, October 14, 2022 1:31:11 PM Attachments:image002.png Jim Regg Supervisor, Inspections AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907-793-1236 From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Friday, October 14, 2022 12:03 PM To: Regg, James B (OGC) <jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs <n1140@conocophillips.com>; CPF1 Ops Supv <n2067@conocophillips.com>; NSK Operations Superintendent <n2073@conocophillips.com>; Braun, Michael <Michael.Braun@conocophillips.com>; Abbas, Sayeed <Sayeed.Abbas@conocophillips.com>; Krysinski, Marina L <Marina.L.Krysinski@conocophillips.com>; NSK West Sak Prod Engr <n1638@conocophillips.com> Subject: Defeated LPP/SSV on CPAI Well 1J-170 on 10/14/22 Good afternoon Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was defeated today, 10/14/2022, when the wellhead injection pressure dropped below LPP setpoint as a result of assumed communication with an offset producer. We plan to leave the injector online as we conduct diagnostics on the nearby producers. The well is currently injecting at our recommended rate of 1000 BWPD and wellhead pressure is at 85psi. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the “Facility Defeated Safety Device Log.” The AOGCC will be notified when the LPP/SSV function is returned to normal, in accordance with “Administrative Approval No. CO 406B.001.” Please let me know if you have any questions. Thank you, Will Parker Production Engineer – GKA (CPF1-West Sak) ConocoPhillips | Alaska, Inc Office: 907.265.6239 (x7234) | Mobile: 406.200.2448 Will.Parker@ConocoPhillips.com 1170 Regg, James B (CED) 20610 From: NSK West Sak Prod Engr <nl638@conocophillips.com> Sent: Friday, January 24, 2020 4:43 PM 7 / To: Regg, James B (CED) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv, CPF1 &2 Ops Supt; Braun, Michael (Alaska); Autry, Sydney; Mowrey, Andrew F Subject: LPP/SSV Returned to Service on CPAI Well 11-170 Jim, The low pressure pilot (LPP) on well 1J-170 (PTD# 206-062, 206-063, 206-064) was returned to service and removed from the "Facility Defeated Safety Device Log" today, 1/24/2020, as the injection pressure increased above the LPP setpoint after a sustained injection period. The well is currently injecting 1350 BWPD at 210 psi wellhead pressure. The LPP had been defeated on 12/16/2019, after wellwork was completed to open up injection to a low pressure zone. This notification is in accordance with "Administrative Approval No. CO 4068.001." Please let me know if you have any questions. Marina Krysinski / Toon Changklungdee West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 • Prip 266 -06'1- Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Wednesday,April 11, 2018 2:52 PM To: 'Peirce,John W' Subject: RE: [EXTERNAL]RE: 1J-170L2 RPPG D MBE 10-403 Approval The email approval also needs to be with the approved sundries when the job is conducted. From: Peirce,John W<John.W.Peirce@conocophillips.com> Sent:Wednesday,April 11, 2018 2:50 PM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]RE: 1J-170L2 RPPG D MBE 10-403 Approval Victoria, Thanks for approving the change from Fullbore pumping to pumping the job down CT. I can attach this email to the 10- 404 when we report the 1J-170L2 Coil Tubing RPPG job pumping. John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office SCANP U From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.govj Sent:Wednesday,April 11, 2018 2:38 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]RE: 1J-170L2 RPPG D MBE 10-403 Approval John, The change in procedure outlined below is approved changing from full bore treatment to utilization of CTU for the RPPG treatment. Please include this approval with the approved sundry. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp a(�alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov 1 • • From: Peirce,John W<John.W.Peirce@conocophillips.com> Sent:Tuesday,April 10,2018 11:22 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject: Re: 1J-170L2 RPPG D MBE 10-403 Approval Re: 11-170L2 RPPG D MBE 10-403 Approvals Hi Victoria, 10-403's were approved to Fullbore RPPG Slurry in 1J-170L2 to seal D MBE to 1J-166L2 (10-403's attached below for reference), but 11-170L2 wellbore volume to D MBE is 142 bbls. A Fullbore RPPG option puts 4473 lbs of RPPG (at 0.75 ppg) in the well before RPPG slurry hits the MBE. That's really late into slurry pumping. I won't get a treating pressure response develop until over 5000 lbs RPPG is pumped away. That is a lot of RPPG pumping.Thus, I have redrafted the RPPG pumping procedure to pump this job down Coil Tubing as a better option. If I use CT—50 bbl volume and park Nozzle at 6636' (above all slots),then volume to MBE =91 bbls, so Lead RPPG slurry hits MBE after 2866 lbs RPPG slurry enters CT. I see treating pressure developing much sooner and have less RPPG volume to pump before getting target treating pressure going to Flush. This shortens the job, saves RPPG product (which is still a rare commodity), and probably leaves less RPPG in the well to FCO later. RPPG slurry mixes at"'3 times concentration of Crystal Seal, so average RPPG job of 5000 lbs at 0.75 ppg= 159 bbls Slurry. Thus, in the future I may keep fullbore RPPG jobs for wellbore volumes< 100 bbls as my rule of thumb. Since AOGCC approved 10-403's to 'Fullbore' pump RPPG into 1J-170L2, would you require that I resubmit 10- 403's for a Coil job procedure? I drafted my proposed Coil Tubing pumping procedure (attached below). I assume AOGCC may prefer to void the approved fullbore 10-403's to replace them with new 10-403 approvals, or perhaps it would be easier to just swap the proposed work procedure on the currently approved 10-403's for the fullbore job. I can handle this either way. I'm still working on optimizing how to best pump these jobs, so this is part of the process. We should be pumping RPPG in 1J-170L2 along with a couple other RPPG jobs in late Q2. Critical path items are waiting on RPPG restock and 1 or 2 more job procedures I need to write. We pumped RPPG at 0.75 ppg down CT twice in late April 2017 with no issues. I tended to start going to fullbore jobs to simplify pumping, but on the flip side we probably need to retain better operational control of jobs in bigger volume wellbores by pumping RPPG down CT. Please advise me on the best or easiest way to handle getting Sundry Approvals for 1J-170L2 Coil Tubing RPPG D MBE treatment. 11-166L2 is offset producer to MBE from 11-170L2. Please call me if you have any questions. I'm OOTO this afternoon then back in the AM. Thanks, John Peirce Sr Wells Engr 2 CPAI Drilling&Wells • • (907)-265-6471 office 3 OF T2yt • • \��\�yyysA THE STATE Alaska Oil and Gas F�►;,-s=���, of® LA c KA Conservation Commission 333 West Seventh Avenue Anchorage,GOVERNOR BILL WALKER Alaska 99501-3572 OF P Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov John Pierce . Sr. Wells Engineer iCkt414E1) ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-170L2 Permit to Drill Number: 206-064 Sundry Number: 318-013 Dear Mr. Pierce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French 4 t Chair DATED this 36 day of January, 2018. • RBD9l S f:3 - 1 2018 EIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION JAN 1 z 2018 APPLICATION FOR SUNDRY APPROVALS 7---S (l 5a/4/ 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate ❑ Repair Well ElAQttinEl Suspend ❑ Perforate Other Stimulate El Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well. ❑ Alter Casing ❑ Other: RPPG MBE Trtmt 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 206-064 • 3.Address: Stratigraphic ❑ Service 0 . 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-23310-61 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 I KRU 1J-170L2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25660 " Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12,678' _ 3,499' ' 12678 " 3499 ' 1500psi NONE 6820 Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 108' 108' Surface 3,011' 103/4 3,041' 2,146' • Intermediate 6,383' 7 5/8 6,410' 3,649' Liner 6,098' 51/2 12,671' 3,499' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7896-7980 3650-3653 4 1/2 L-80 6,383' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=ZXP Liner Top Packer • 6353 MD and 3391 TVD PACKER=ZXP Liner Top Packer '6491 MD and 3417 TVD PACKER=ZXP Liner Top Packer . 6931 MD and 3498 TVD SSSV: =NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 t 14.Estimated Date for 3/1/2018 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ 0 WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG 0 i GSTOR El SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com A —2�' / �I�Q Contact Phone: (907)265-6471 Authorized Signature: 1// Date: p • COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: rg 0 i s Plug Integrity El BOP Test 0 Mechanical Integrity Test 0 Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No EZ Spacing Exception Required? Yes ❑ No Subsequent Form Required: L(' ff Eil/ RSDMS L F— i LteIO rte APPROVED SI t I •7� t P Approved by: COMMISSIONER THE CSI N I Date: fsi i/h2. I I� t//bn �L J/z�/l s� R I G I COMMI A i. Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 mot3ths from the date of approval. Attachments in Duplicate .. KUP IN 1J-170 Iv ConotPhillips , A well Attri Max Angle aO TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(.) MD(ftKB) Act Btm(ftKB) conocophllllps 500292331000 WEST SAK INJ 92.23 8,139.31 12,479.0 L ... Comment 925(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-170,1/10/2018 10:3e;11 AM SSSV:NIPPLE Last WO: 31.31 6/29/2006 Vemcal schemabc.(achd) )Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SET TYPE II DIVERTOR pproven 2/17/2016 HANGER;22.51 1,1 Casing strings ,.�,11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread CONDUCTOR 20 19.124 28.0 108.0 108.0 94.00 H-40 WELDED " Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread SURFACE 103/4 9.950 30.2 3,041.1 2,1464 45.50 L-80 BTC Casing Description (in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread 1111. INTERMEDIATE INTERMEDIATE 75/8 6.875 27.1 7,894.0 3,649.6 29.70 L-80 Buttress -A-A.CONDUCTOR,28.0-108.0- I _ Thread NIPPLE;508.9 Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread D LINER LEM 41/2 3.950 6,353.0 6,521.3 3,422.5 IBT I Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 0 Item Des Com (in) SURFACE,30.2-3,041.1 6,353.0 3,390.8 79.37 PACKER ZXP LINER TOP PACKER 4.950 GAS LIFT;3,604,3 6,372.0 3,394.3 79.47 SBR 190-47 CASING SEAL BORE RECEPTACLE 4.750 6,391.6 3,397.9 79.35 XO BUSHING CROSSOVER BUSHING 3.950 6,396.9 3,398.8 79.32 HANGER LEM ABOVE HOOK HANGER 3.980 glik 6,407.4 3,400.8 79.25 HANGER LEM INSIDE HOOK HANGER 3.980 GAS LIFT;5,175.3 6,475.1 3,413.7 78.91 BENT JT 3.950 Mr 6,518.0 3,421.9 79.04 SEAL ASSY BAKER SEAL ASSEMBLY 4.000 SLEEVE-C,6,300.9 ( y1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINE D LINER HH 41/2 3.476 6,423.9 6,625.3 3,442.0 11.60 L-80 BTC Liner Details Nominal ID LOCATOR,6,358.3 Top(ftKB) Top(TVD)(ftKB) Top Teel C) Item Des Com (in) SEAL ASsv;6,360.0 =_ 6,423.9 3,403.9 79.15 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 5.600 - a (OUTSIDE CSG) ' 6,522.8 3,422.8 79.05'ECP BAKER PAYZONE EXTERNAL CASING PACKER 3.930 6,553.0 3,428.5 79.13 BENT JT 3.950 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread DIVERTOR 72;6,409.0 , - B LINER LEM 4 1/2 3.476 6,491.4 6,973.6 3,506.3 11.60 L-80 IBT IreI Liner Details I Nominal ID Top(ftKB) Top)TVD)(ftKB) Top In1) Item Des Com (in) 6,491.4 3,416.8 78.96 PACKER ZXP LINER TOP PACKER 5.750 6,510.4 3,420.4 79.01 SBR CASING SEAL BORE 4.750 i 6,530.1 3,424.2 79.07 XO BUSHING CROSSOVER BUSHING 3.950 6,812.9' 3,475.3 79.96 HANGER LEM ABOVE HOOK HANGER 3.950 6,823.6 3,477.2 79.96 HANGER LEM INSIDE HOOK HANGER 3.688 D LINER LEM,6,353.0-6,521.3 a. 6,8962 3,490.5 78.59 NIPPLE CAMCO DB-6 NIPPLE 3.563 16,927.6 3,496.9 77.82 BENT JT 3.950 1 6,970.3 3,505.7 78.73 SEAL ASSY BAKER SEAL ASSEMBLY 3.950 Casing Description OD(in) ID(in) Top(ftKB) Set Depth)ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread A LINER 41/2 3.476 6,931.0 12,470.0 3,701.2 11.60 L-80 BTC . Liner Details D LINER HH;6,423.9-6,625.3 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) 11 }, 6,931.0 3,497.6 77.73 PACKER "ZXP"LINER TOP Packer 5.500 ISO SLEEVE;6,818.0 ' 1, 6,950.2 3,501.6 78.19 NIPPLE "RS"Packoff Nipple 4.870 FISH;6,820.0 I! ,I 1, 6,953.0 3,502.2 78.26 HANGER Liner Hanger 5.510 l` 'I'!I 6,962.8 3,504.2 78.53'SBE BAKER SEAL BORE EXTENSION 4.750 i 6,982.5 3,508.0 79.06 XO BUSHING CROSSOVER BUSHING 3.930 B LINER;6,823.5-12,550.0 Tubing Strings Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(11,95 Grade Top Connection TUBING 41/2 3.958 22.5 6,382.7 3,396.2 12.60 L-80 Completion Details 0 Nominal ID it Top(ftKB) Top(TVD)(ftKB) Top Incl(') Item Des Com (in) i 22.5 22.5 0.00 HANGER Vetco Gray Tubing Hanger 4.909 1 508.9 508.2 6.84 NIPPLE Camco DB Nipple 3.875 iit 6,308.9 3,382.6 79.12 SLEEVE-C Baker CMD Sliding Sleeve(CLOSED 5/27/2009) 3.810 B LINER LEM;6,491A-6,973.6 =we II 6,358.3 3,391.8 79.39 LOCATOR Baker Locator 3.875 6,360.0 3,392.1 79.40 SEAL ASSY Seal Assembly 3.875 Other In Hole(Yllireiine retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl INTERMEDIATE;27.1-7,894.0 Top(ftKB) (MB) C) Des Corn Run Date ID(in) 6,409.0 3,401.1 79.24 DIVERTOR TYPE 2 DIVERTER 3.68"X 18.54 1/18/2016 2.500 SLOTS;7,696.0-7,980.0-- _ T2 6,818.0 3,476.2 79.96 ISO SLEEVE TYPE 1 ISOLATION SLEEVE SET IN B LEM 8/10/2008 SLOTS;8,281.0-9,000.0 1111 III 6,820.0 3,476.5 79.96 FISH Centralizer 3 BOTTOM HALF OF CENTRALIZER 3/17/2007 ARMS,3 ROLLERS,3 ROLER AXELS-LOST 3/17/2007 BELOW DIVERTER-EXACT LOCATION SLOTS,9.258.69,732.0 a UNKNOWN 1 SLOTS;10,030.0-10,590.0 1 . SLOTS;10890.611,354.0 PI al SLOTS;11,657.612,003.0 SLOTS;12,175.612,435.0 A LINER;6,931,0-12,470.0 KUP I. 1J-170 ConocoPlhillips 3 411, Alaska.Ino. Gonot4 Blips •., 1J-170,1/10/2018 103812 AM Veraoal schemalielactual) HANGER;22.5 ,�' Perforations&Slots r�7�I Shot IP Dens • .. . .. .' 1 T .-. u,,. Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (MO) Zone Date ft) Type Corn 7,896.0 7,980.0 3,649.7 3,653.5 WS A2,1J- 6/9/2006 32.0 SLOTS ALL SLOTS THIS 170 WELLBORE_ —A.A.CONDUCTOR;28.0-108.0- Alternating slotted/solid :_. pipe 0.125 x 2.5"x 32 NIPPLE;508.9 spf @ 4 Circumferential t adjacent rows,3" Centers staggered 18 • deg.,3 ft.non-slotted ends SURFACE;30.2-3,041.1 GAS LIFT;3,604.3 8,281.0 9,000.0 3,653.5 3,651.3 WS A2,1J- 6/9/2006 32.0 SLOTS 170 9,258.0 9,732.0 3,653.3 3,650.4 WS A2,1J- 6/9/2006 32.0 SLOTS 170 GAS LIFT;5,175.3 10,030.0 10,590.0 10,890.0 11,354.0 3,649.0 3,645.5 WS A2,1J- 6/9/2006 32.0 SLOTS 170 3,651.2 3,657.5 WS A2,1J- 6/9/2006 32.0 SLOTS SLEEVE-C;6,308.9 170 11,657.0 12,003.0 3,664.9 3,671.9 WS A2,1J- 6/9/2006 32.0 SLOTS • 170 LOCATOR;6,350.3 � 12,175.0 12,435.0 3,679.6 3,699.5 WS A2,1J- 6/9/2006 32.0 SLOTS 170 SEAL ASSY;6,360.0 - — s� Mandrel Inserts I St ti on Top(TVD) Valve Latch Port Size TRO Run N Top MKS) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,604.3 2,393.7 Camco KBG-2- 1 Gas Lift DMY BK-5 0.000 0.0 9/22/2006 DIVERTOR 72;6,409 01R 1R I 2 5,175.3 3,052.7 Camco KBG-2- 1 Gas Lift DMY BK-5 0.000 0.0 9/23/2006 1R Notes:General&Safety End Date Annotation 7/1/2006 NOTE:MULTI-LATERAL WELL:1J-170(A-SAND),1J-170L1(B-SAND),1J-170L2(D-SAND) 8/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 x D LINER LEM;6,353.0-6,521.3 , s D LINER HH;6,423.96,625.3 I' ISO SLEEVE;6,818.0 411 1 FISH;6,820.0 I 0 LINER;6,823.5-12,550.0 EA a F. -} B LINER LEM;6,491 4-8,973.6 NE INTERMEDIATE,27.1-7,894.0 SLOTS;7,896.0-7,980.0 SLOTS;8,281.0-9,000.0 SLOTS;9,258.0-9,7320 SLOTS;10,030.0-10,590.0 SLOTS;10,890.0-11,354.0 SLOTS;11,657.0-12,003.0 SLOTS;12,175.0-12,435.0 A LINER;8,931.0-12,470.0 L KUP I1J-17012 r'` Ili 11;COi'10G0P11��ip5 Well Attribute Max Angle TD Alaska,Ince Wellbore APIUW1 Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) CanocoPhillips 500292331061 WEST SAK INJ 92.98 7,063.76 12,678.1 L ... Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1a-170L2,1/10Mw610:38:56AM SSSV:NIPPLE Last WO: 31.31 6/29/2006 V. schematic(Wimp. .. - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PERF ZONES osborl 5/15/2013 HANGER;22.5 I\'.',':..,�I Casing Strings I liii . Casing Descr ption OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread D LINER 4 1/2 3.476 6,573.5 12,671.5 3,498.8 11.60 L-80 BTCt� �Liner Details -�h CONDUCTOR;28,0108.0- iz Nominal ID NIPPLE;508.9 Top ftKB Top(ND)ftKB Top Incl Item Des Corn (in) 6,573.5 3,423.3 84.44 SLEEVE -BAKER'FIR'SETTING SLEEVE 2.000 SURFACE;30.2-3,041.1 6,631.3 3,4282 85.80 XO Reducing CROSSOVER 5.5x4.5" 3.930 GAS LIFT;3,604,3 Perforations&Slots Shot Dens GAS LIFT;5175.3 Top(TVD) Btm(ND) (shots/ �® Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,637.0 7,110.0 3,428.6 3,432.1 WS D,1J- 6/25/2006 32.0 SLOTS ALL SLOTS THIS SLEEVE-C;6,308.9 170L2 WELLBORE_ Alternating slotted/solid pipe 0.125"x 2.5"x 32 6.358.3 - spf @ 4 Circumferential LOCATOR; sEALA ;6,360.0 — adjacent rows,3" Centers staggered 18 deg.,3 ft.non-slotted DIVERTOR 72;6,4090 II ends D LINER LEM;6,353.0-6,521.3 INTERMEDIATE;27.1-7,894.0 ' --- 7,362.0 7,835.0 3,426.4 3,426.9 WS D,1J- 6/25/2006 32.0 SLOTS 170L2 1 8,093.0 8,728.0 3,429.9 3,425.5 WS D,1J- 6/25/2006 32.0 SLOTS 170L2 8,983.0 9,449.0 3,431.2 3,430.7 WS D,1J- 6/25/2006 32.0 SLOTS — — 17012 9,702.0 10,213.0 3,426.5 3,430.4 WS D,1J- 6/25/2006 32.0 SLOTS 17012 SLOTS;6,637.0-7,110.0 10,461,0 11,095.0 3,430.7 3,438.8 WS D,1J- 6/25/2006 32.0 SLOTS 17012 11,354.0 11,868.0 3,444.4 3,460.9 WS D,1J- 6/25/2006 32.0 SLOTS 17012 12,117.0 12,550.0 3,478.9 3,493.7 WS D,1J- 6/25/2006 32.0 SLOTS 17012 12,592.0 12,635.0 3,495.9 3,497.5 WS D,1J- 6/25/2006 32.0 SLOTS SLOTS;7,362.0-7,635.0 — 17012 !— Notes:General&Safety End Date Annotation 7/1/2006 NOTE:MULTI-LATERAL WELL: 1J-170(A-SAND),1J-170L1(B-SAND),1J-170L2(D-SAND) III 8/14/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 II SLOTS;8,093.08,728.0 a a I SLOTS;8,983.0-9,449.0 ■ Ili■ SLOTS;9,702.0-10,213.0 111 i I 1 SLOTS;10,461.0-11,095.0 ■ SLOTS;11354.0-11,868.0 .( 1 r I SLOTS;12217.0-12,550,0 MI SLOTS;12,592.0-12,6350 III D LINER;6,573.5-12,671,5 1J-170L2 to 1J-166L2 RPPG Treatment of D MBE West Sak 1J-170L2 is a D sand horizontal injector lateral constructed with 4.5", L-80 liner located at 6409' - 12671' RKB. The D lateral contains slotted joints alternating with blank joints over the entire liner length. On 10/10/15 an MBE occurred in 1J-170 while the 1J-170L1 B lateral was isolated by an Iso-Sly (due to a B MBE identified 8/1/08 at -8060' RKB by a B lateral IPROF). Mainbore IPROF's were performed in late 2015 that indicated a D MBE was likely. An IPROF of 1/5/18 was run in the 1J-170L2 D lateral to 12621' RKB and identified a D MBE at -9350' MD about half way down the lateral. Currently 1J-170 has a D Diverter set, and a B Iso-Sly set, but the A sand lateral is open. It is proposed that the D lateral be perforated near the D MBE and that a fullbore RPPG treatment be performed to seal the D MBE at -9350' RKB. Proposed Procedure: Coil Tubing: 1) Reconfigure 1J-170 for a D MBE treatment as follows: a) Pull D Diverter at 6400' RKB b) Pull B Iso-Sly at 6818' RKB c) Set DB Plug in DB Nipple at 6896' RKB d) Reset B Iso-Sly at 6818' RKB e) Reset D Diverter at 6400' RKB 2) RIH with 2" run OD pelf gun to shoot 5' of large hole perfs, 6 spf, 60 deg phasing, in 4.5" slotted liner at +/- 9350 - 9355' RKB (target) to perforate over the D MBE area at -9350' RKB. POOH with gun. Verify all shots fired. Fullbore Pump RPPG Treatment to Seal D MBE: 3) Shut-In 1J-166 offset producer to the MBE -24 hrs before RPPG job, and then put 1J-170L2 on PWI at 500 - 1000 BWPD to reestablish injection through D MBE to 1J-166L2. RU mixing van & pumping equipment on 1J-170. SI PWI to 1J-170L2 and then proceed to fullbore pump RPPG slurry at steady established rate in range of 2 - 3 bpm. Mix slurry in Seawater by adding 1 -4 mm mesh RPPG to make -0.75 ppg slurry concentration on-the-fly, while fullbore pumping slurry down 1E-1J-170L2 to D MBE located at 142 bbls down the wellbore. Continue pumping at steady rate and slurry concentration until WHIP reaches -800 psi, and then swap from RPPG slurry to 100 bbls Seawater spacer, followed by 41 bbls Diesel FP (to 2000' TVD), to leave RPPG slurry -1 bbl underdisplaced to MBE, followed by Shutdown. Wait 48 hrs for swelling RPPG particles to fully crosslink together in the D MBE to form a very stout amalgamated non-flowing gel before returning 1E-166 to production. Coil Tubing: 4) RIH with jet swirl nozzle & tag RPPG top. If needed, jet RPPG to deep as possible with Diesel, to prevent stuck CT, while injecting RPPG & Diesel from liner to MBE &/or formation. POOH. RD CTU. Place 1J-170L2 on PWI to evaluate D MBE treatment results. JWP 1/11/2018 1� CJ 6; 1 "ci 6 x' >, U O 5 E t o L NN L 'Q O a-• (7O?NZ 2 c U O > III m u° a o a c °',73 o v > ,_ Q a a CO Q ( CD M O O CO CO {-+ C Q N K O CI L. co C C C C L J ru 7 7 7 7 ' - c -C M to vs Q a) E u OL > -0 N F- O v O c *-' u ro O W0 0 0 0 0 0 C ,- 0 1_ J J J J J J 0.0 0 .ryCLLL.ILLWWWW 0 N' C U `+- I- LL LL LL LL LL LL *., 9J U) 91 '0 a o > s v O , < a Z Z Z Z Z Z u U N O v ., LL LL LL LL LL LL IY ^ JO > TO +u E .+ > 4- 9) C — r O _0 F u 01 O ` vt a ai u _ t) O C o ro r>o • in Z o a 0 co o 0 74 • .0LL LL LL LL � d d ),, ," .. a o o c a o 1 u cc m; aavc.) aa \ Z F ri gN 0 co Lu Uus ol z \ Q co O 41 "a -t 0 41 L 1.o cb w O; e L ? ' -o rd z 0x9 .,- U P. J O J J O O C cc ce ca c7 v, 62 cu cu 2 2 ago *f cc cc CC LC CC CC W W W W W W 0 of L" > > > > > > (XCea X iXCe Lo 2 Y Y Y Y Y j 9Lrai).; Y — aaaaaaDCe 4- a ° ilin Y Y Y Y Y -..... ....4.4 O Fe�7 i's 00 9) o D o 0 0 0 0 o CC X n . 0 0 0 CV O o 0 0 0 0 o d Y - LU' 5 a av [// `) 0 Liu a 0 0 0 a 0 C O Ca) z O rx0 N WQ < 00000ooil H C v a 0 oh n r� EI 00 CCt+1 O M N N MII " O 1`N M M O O M M 0 U N Cs/1 N N (.1 N N L _O O a) M M 07 d GL N 00001111 N N O O N N 0 0 ,- 0 0 •i 00 0 0 0 0 1,4 0 N . Doiv C In In 11') l() Y') Q. U CID GI- an E F I I ( I ' . ' I I a) ccw > U �. w o U * Q N CL i O z7 ♦- N O) r_, N J O 07 N N @ N 7 a N z t:, 0n O N O O Y ++ N an r is. H F ` a C Cl. Q O N to r 7 N N m Z GL (0 Oto •'� ctij Q U n C f0 v, CD F- .c E -k.... d f0 .O co a O CID a 'a d • WELL L® TRANSMITTAL o O PROACTIVE DIAgNOSTIC SERVICES, INC. 11 '6° DATA LOGGEr, MP� 3A4/2o1G. CI M.K.BE;iWD�, NOGG To: AOGCC Makana Bender 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 schte4E© APP 0 $ 2016 1) Injection Profile 19-Jan-16 1J-170 Color Log /CD 50-029-23310-61 2) Signed : ��'c'' 6...e...0ceeet, Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. p~ Q ~ - ~~ 4- Well History File Identifier III 111111 II III II I / II III ~~~~~~ ~~ (~ ~~~ ~~~ Organizing (done) ~ wo-sided ^ Rescan Needed RESCAN DIGITAL DATA ~ OVERSIZED (Scannable) ^ Color Items: r~iskettes, No.' ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other.: BY: Maria Date: ~ fs/ Project Proofing III 111111 IIIII II III BY: Maria Date: ©CJ /s/ Scanning Preparation ~ x 30 = + ~ =TOTAL PAGES _ (Count does not include cover sh t) BY: Maria Date: ~..$ /s/ Production Scanning III II'III IIIII II III Stage 1 Page Count from Scanned Fite: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Pre aration: ~ES NO BY: Maria Date: ~/ag ~ C7 /s/ ~ r f p 1 Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II') II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Quality Checked III II I) II III (I'i III 10/6/2005 Well History Fiie Cover Page.doc ,~ ,~. :4 ...~ r+ Y ~~~ II r ~. r ~.~. ,,.; ~ ~~ xs ~Y' MICROFILMED.. 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc "~,~ !!~ • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION :APR ~ ART OF SUNDRY WELL OPERATIONS 1. Operations Perform d: on it well ~ Rug Perforations ['! Stimulate ~ Other ~ WINJ to WAG '.~;ptriC>l11~6F Conversion Iter Pull Tubing r Perforate New Pool ~ Waiver ~ Time Extension Change Approved Program Operat. Shutdow n ~ Perforate ~ Re-enter Suspended Well 2.Operator Name: 4. Current Well Status: `5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~" 206-064 3. Address: Stratigraphic ~ Service ~ .API Number: P. O. Box 1 0360, Anchorage, Alaska 99510 50-029-23310-61 7. Property De 'nation: 8. Well Name and N\mber: ADL 25660 & 24709 1 J-170L2 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 12678 feet Plugs (measured) None true vertical ~ 3499 feet Junk (measured) None Effective Depth measured 12678 feet Packer (measured) 6360 true vertical 3499 feet (true vertucal) 3396 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20 108 108 0 0 SURFACE 3011 10.75 3041 2146 0 0 INTERMEDIATE 6383 7.625 6410 3649 ~ , ._, 0 LINER D-SAND 6098 5.5 12671 3499 0 0 Perforation depth: Measured depth: Slotted & Blank liner fr 7110-12117' True Vertical Depth: 3423-3369' ._~~~i. ;~:_, ~' ~ `: ` <u;~ E#'- Tubing (size, grade, MD, and TVD) 4.5, L-80, 6383 MD, 3392 ND Packers &SSSV (type, MD, and TVD) Packer -Seal Assemby, EC @ 6360 and 3396 ND SSSV =Nipple @ 509' MD, 8' 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 0 440 1283 627 Subsequent to operation 0 2101 0 788 741 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ~ Development ~ Service ~~, Well Status after work: Oil ~` Gas r" WDSPL Daily Report of Well Operations X GSTOR ~ WAG ~ GASINJ r WINJ ~ SPLUG 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: 309-063 Contact Bob Christensen/Darrell Humphrey Printed Name obe D Christens n Title Production Engineering Specialist Signature Phone: 659-7535 Date e / 7~ ~® 2 ~°~ ~ YL~ is Form 10-404 Revised 7/2009 RBDMS APR ~ Submit Original Only • • 1J-170L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/05/10 Conversion WIND to WAG . ~ KUP 1J-170L2 ~ ~ ~ ~ ~~ D TD On~O l lp$ [ AI I K ~ II Attributes Wellbore API/UWI Field Name x Well Status Inc! (°) An le & M MD (RKB) Act Btm (RKB) ll , aS ~a 500292331061 WESTSAK INJ 92.98 7,063.76 12,678.1 Comment H2S (ppm) Oate Annotation End Date KB-Grd (R) Rig Release Dat ~~~ SSSV: NIPPLE 0 7!1/2008 Last WO~. 31.31 6/29/2006 Well COnfi -1J-1 ]OL2 5/25120 Schematic-Actua 0971.02.42 AM l Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason: Show Sleeve @ 6309' Closed Imosbor 5/25/2009 HANGER, 23 Casin Stnn s -' - - - - - - - - - - - ~ - - - -' - Casing Description String 0... String ID ... Top (RKB) Set Oepth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd LINER D-Sand 4 1/2 4.000 6,573.5 12.671.5 3,498.8 11.60 L-80 BTC Liner Details Top Depth CONDUCTOR, (ND) Top Inc! 6 Top (RKB) (RKB) (°) I tem Deetriptl on Comment ID (Ir NIPPLE , 509 6,573.5 3,423.3 84.43 SETTING "HR" Setting Tool 2.0( SLEEVE SURFACE. Perforatlon$ & Slot$ 30-3.041 Shot GAS LIFT, Top (ND) Btm (ND) Oens 3.604 Top (RKB) Btm (RKB) (RKB) (ftK8) Zone Date (sh... Type Comment 6,637 12,635 3,428. 2 3,497.5 WS D, 1J-170L1 6!25/2006 32.0 SLOTS ALL SLOTS =Alternating slotted/solid pipe 0.125" x 2.5" x 32 cns uFT, s,1]s spf a~ 4 Circumferential adjacent rows, 3" Centers staggered 18 deg., SLEEVE-~, ft. non-slotted ends 6,309 LOCATOR, 6.356 Notes: General & Safe SEAL A6,360~ t ,:, End Date Annotation SLOTS, 6,637-12.635 IStnToo IRKBI (RK6) I(°) Make Model O) Serv I Type Type ~~~I TRP Run Run Date Com... LINER D-Santl, 6.5]3-12.fi]1 TD l1 J-1 ]OL2), • • ~~ ~ ~- ~~~ ~u~ 6~ ~ E-~; ~ ~ ~ ~ ~ ~-~~ ~~ F~~ ~ ~ ~`~~ e ~ ~~ ~ ~ ~ " ~ " ~ ~~~ ~ ~~, ~ } ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~' ~ ~ ~ ~ SEAN PARNELL, GOVERNOR ; ~'.,` tH ~:~ ~_~ ~~ ~~; ~ .~ ~~ !~~,~ ~ ~~ ~ ~ ~.~ ~~..- ~ ~ ~ f ~-7~~ DIL tusi/ Vrv-7 ~ 333 W. 7th AVENUE, SUITE 100 CO1~T5ERQATIOI~T COMI-IISSIOI~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 P FAX (907) 276-7542 Mr. M.J. I,oveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 _ _ .~ oCo~ Re: Kuparuk River Unit, West Sak Pool, 1J-170L2 ~b ~ Sundry Number: 309-063 Deax Mr. Loveland: ~~~~~`"' ~~~ J~~ 2~fl~ 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, `t'~ Cathy . Foerster Commissioner ~ DATED this ~6 day of October, 2009 Encl. • • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, October 07, 2009 7:50 AM To: Dave Roby; Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: FW: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1 E-102 & 1 J-170L1 Attachments: Picture (Metafile); Picture (Metafile)^`--'~ ~ ~ ~ IA ~~ ~~ "'"~ i ~ ,~ 1 Dave, et al, Here is some information regarding a call I got yesterday on MBE events and isolations in these segments. Have the sundries to convert been approved? Tom From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.coml Sent: Tuesday, October 06, 2009 5:28 PM To: Maunder, Thomas E (DOA) Cc: Hollar, Eric Andrew; Pierson, Chris R; NSK Well Integrity Proj; NSK Prod Engr & Optimization Supv Subject: Update of Wsak VRWAG Pilot Project & additional 10-403 information for wells 1E-102 & 1J-170L1 Tom, As the startup of the Wsak VRWAG Pilot Project approaches (estimated commencement date of 11/15/09), I have been asked to review the 10-403 Sundry applications submitted in February of this year. Below are the records pertaining to zone isolations due to Matrix Breakthrough Events (MBE) on wells 1 E-102 and 1J-170L1 that were not included in the 10-403 submittals. Well 1E-102 MBE to offset Producer 1E-121 Date Well 1E-102 PTD# 204-231 10/25/2006 BRUSH DB NIPPLE @ 6060' RKB. SET 3.562 DBP PLUG @ 6060' RKB. SET P-PRONG INSIDE DB PLUG BODY @ 6060' RKB (13/8 FISH NECK-43" OAL ). (( B-SAND IS ISOLATED )). JOB COMPLETE. Well 1J-170L1 MBE to offset Producer 1J-166 -- - Date eft 1J-170L1 PTD# 206-063 8/10/2008 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. Please provide direction as to what is needed to move the process forward. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907)659-7000 (924) This email may contain confidential information. If you receive this e-mail in error, please notify the sender and delete this email immediately. 20" 91.5# x 34" Insulated Conductor, K-55, set at +/- 80' 11" x 5" Vetco Gray MB 228 Wellhead Tubing, Special Drift to +/- 500' MD 508' MD - 3.875" DB Nipple, for Possible SSSV 3604' MD -GLM, Camco KBG-2, 4-112" X 1" 5175' MD -GLM, Camco KBG-2, 4-112" X 1" ConocoPhillips West Sak 7-5/8" Injector 1 J-170 Tri-Lateral Completion 10-314", 45.5#, BTC ~ _ _- - 6308' MD - CMD Sliding Sleeve, wl 3.81" DB Nipple Shoe set ~ 3016' MD, 2145' TVD, 66 deg 6371' MD -Casing Sealbore Receptacle, 20' Tubing String _ _ ~ Length 4-1/2" 12.6#, L-80, IBTM ' //'' ~ ~ ~ 3.958" ID, 3.833" Drill MD -Lateral Entry Module(LEM) .~ 6396 ~ ~ ~Q D-sand Window 'D' San d Lateral 6353' MD - 5-112" X 7518" Seal ~ Assembly at 6409' MD, 3413' TVD 4-112" 11.6# L-80 Slatted ZXP Liner Top Packer wl 4.75" Seal OD Liner Every Other Joint 6522' MD -Baker 5-%" ECP Hold Downs Bottom ~ ~ 4-112" Eccentric 6382' MD ~ / ~ Guide Shoe / ~ 4.1/2" Liner Shoe, 11.6#, L-80 BTC / / \ i Set ~ 12671' MD, 3499' TVD '- 6573' MD - 5-112" Tieback Sleeve 4-112" X 7SI8" Seal Bores Model'B' HOOK Hanger 3.68" ID 6407 MD 6491' MD - 5-112" X 7518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module (LEM1 Assembly -- 5-112" X 7518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile ./ 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 4.75'oSeaIROD 3 875e Seal ID 6510' MD-Casing Sealbore Receptacle 20' Length Seal Assembly 4.75" Seal OD Bottom ~ 2'MD-Lateral Entry Module(LEM) i~\`(..~ B-sand Window Q~ ~~JV .` at 6584' MD, 3434'.TVD ~ 'B' Sand Late .~ j `M1~~~ ~ 4-112" 11.6# L-80 Slotted T+ Liner Every Other Joint , 3-112" Bent 4-112" X Sea res_ _ `~ 6858' MD -Liner 3.68" Swivel ~' ~ 96'MD-3.562" ___ 4-112" 12.6# 7ubin~_- ___ - -- ----- DB Nipple 3.833" Drift 3.958" ID /~ 5-112" X 7SI8" ZXP ~ % Liner Top Packer ~ ~ . with Hold Downs / `~, i 5-112" X 7518" Liner Hangerl Packer Assembly at Flex Lock 6931' MD \ Liner Hanger 6962' MD -Casing Sealbo Receptacle, 20' Length As Completed B IKUQ IES Tiukcr Oil Tools Lateral En try Module (LEMI With Dive rters and Isolation Lateral Access Diverter Lateral Isolation DiverMr GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbor e Drift) 'GS' Prohle for Coil Connector JRUnning/Retneving \ (1.00' Length( Snap In/Snap Out /~POSitive Locating Back Pressure Valve - Collet ('1.60' Length) ~ Lateral lsola0on-"' -Flow-Thru Swivel • Seals ; (1.25' Length( ~ Lateral Diverter i ~ ~' ' --Hytlraulic ~ Ramp Disconnect Isolation/ Mainbore ~ (1.50' Length) 1 Diverter Sleeve ,, _ ~ GS Spear ~ ~ ~ (1,50' Length( Lateral Isolation ~ I . i 6.BS h Approx. Seals h l l ~ OAL' u ,ay be required in highly deviated n annlicatinns fF' annrnz lenathl. 15.5' Diverter Length 18.5' Sleeve Length V 12" Guide Shoe l2" Liner Shoe, 11.6#, L-80 BTC Set ~ 12550' MD, 3552' TVD Seal Assembly 4.75" Seal OD Bottom ~ 6973' MD ~ !!"ti ~ „_ 'A' SandSand Undulating Lateral 4-112" 11.6# L-80 Slotted ~ Liner Every Other Joint 4-112"Eccentric / Guide Shoe Equipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.66" LaterallMainbore Diverter OD: 6.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +I- 3.89" Diverter and Sleeve Length: +1-18.5' 4-1/2" Casing Shoe, 11.6#, L-80 BTC Set ~ 12470' MD, 3702' TVD 7-5/8" Casing, L-80, BTCM, Set at © Baker Hughes Zaas. This document may not be reproduced or dlsMbuted, In wnole or in part, In anyfortn or by ~ 7894' MD, 3649' TVD (85 deg) any means electronic or mechanical, Inelutling phobcopying, recording. or by any Intormatlon storage and retrieval system now known or hereaRer Invented. wltltou[ written permission Rom Baker Hughes Inc. ~JJ I ~ ~ • • ConocoPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~ECEIVED FEB Z 7 2009 Alask,~ pii g Gas Cona. Co ~n~~or~pe mmissio~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sak injection well 1J-170 (206-062), 1J-170L1 (206-063), 1J-170L2 (206-064) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, i'~ ,.°'~~~ MJ veland ConocoPhillips Well Integrity Projects Supervisor Enclosures ~~CC~C1Vr_u FEB 1 7 2009 ~~ • STATE OF ALASKA • , , ,,` ALASKA OIL AND GAS CONSERVATION COMMISSION AI85k8 Q1~ & Ga3 COnS. COtnmtSSlQn b' 1~ APPLICATION F O R S UND R Y A PPROV A L Anchorage 20 AAC 25.280 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ~ Perforate ^ 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, Inc. Development ^ Expioratory ^ 206-064 • 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-61 ' 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 Q 1J-170L2 • 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660 8~,Z686'r~~~,~Z~~ RKB 109' ' Kuparuk River UniU West Sak Oil Pool • 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Jotal Depth ND (ft): ~ Etfective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): r26~8 ~,3y~j ;.«•~? Casing .(4 Length Size MD ND Burst Collapse CONDUCTOR g0 20" 108 108' SURFACE 3013 10-3/4" 3041 2146' Intermediate 7866 7-5/8" 7gg4 3649' D sand Liner 6097 5.5"x4.5" 12671 3499~ Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted & Blank liner fr 7110-12117' 3432-3369' 4.5" L-80 6382.65' Packers and SSSV Type: Packers and SSSV MD (ft) Packer - Seal assy, ECP 6360, 6523 No SSSV - Nipple 508 13. Attachments: Description Summary of Proposal 0 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: c-`~ ~, L"/ ~ C Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: WAG ~• 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/Per Klein Title: Well Integrity Project Supervisor ~ Signature ~~ ~~~~./~ Phone 659-7043 Date ~j~ ~~ G''J " Commission Use Onl Sundry Number: ~ Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ~ BOP Test ~ Mechanical Integriry Test ~ Location Clearance ^ Other. ~~rl ~~ 0~2./`.c.~i~ah /K 4cc.o~~ ~~ ~ /11 ~ ~-r Z, 6, ayK Subsequent Form Required: ~ ~ -" ~~~ APPROVED BY ~ / ~ ~~ ~ Approved by: COMMI COMMISSION Date: Form 10-403 Revi~d 06/2006 '¢;`; ~ ~~,~~ ll~(~,~~" ~r~.'~ Su'b~1'it in Duplicate ! ~7~~1 •~ 'Z • !? - O"~ 1 J-170 • DESCRIPTION SUMMARY • OFPROPOSAL ConocoPhillips Alaska, Inc. 1J-170 (PTD 206-062) & 1J-170L1 (PTD 206-063) & 1J-170L2 (PTD 206-064) Sundry Notice 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-170 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-170 was drilled and completed in June 2006 as a pre produced trilateral injection well and converted to a water only injector in October September 2006 The well was drilled with a 20" conductor to 108'. The surface hole was drilled with a 13.5"" bit and cased with 10-3/4"" casing to a TD of 3041'. The casing was cemented in place with 462 bbl of lead cement (Arctic set) and 79.5 bbl of tail cement (Deepcrete). Bumped plug on calculated displacement volume and the floats held. Good cement returns were seen, 120 bbl to surFace. The intermediate hole was drilled with a 9-7/8" bit and cased to 7894' with 7 5/8" casing. The casing was cemented in place with 185 bbl Deepcrete cement. Bumped plug on calculated volume and good returns were mentioned. The top of cement is confirmed at 3036' 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 1J-170 2. Injection well 1J-170 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-170 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. 2009 WSAK EOR Pattern Targets ~ ~ f ~ '~ 1 • C^ 1 E-102 ~ . ~" ~} ~ . ~~ , ,. .. : , ,/'~ ~ ~ f~ _.._ _ ___ . y~ ' I r~ ~ _ ` ,~ R; ~~ ... 1 J-170 l~~ ~ ~ ~ ~-- .... ~ . 1 , ' ~,~ ~ ~r~-j ~~r 1 ~ }~ • ~- 1 E-117 ~ :~,. -~ -- ~, II ' ~ r. F'- ~ . ` ~ _.~ ~ y ~ ----~ ~~\ .~... ~ 2' S 4. t. t -- • 5 ~ "~ S-==_' -_: :7 ~ ~ ~- ~ ; ~ i r r. ~ a .. ~ , r -= ~` ! ~ ~Ir __--. a ~, ~ - __ ` , ~ _, ' ' ' - . ,,.._ ~ -,.,~'~,-. . "=,, = - _ __ -- ' ~ ~, ~ `~ - _ ~ _ ~ ~ : _ ., ~ - . - - - Y y + ` ' * a ~ L ~ ---- - . ~S ~ ~\ . . - , L r . ~- ~ ~ -_ 1 ~ ~ T t __ ` • y ` ~ r ' ~ ~ . a y /1 ~~ . ',;' r q _ .. - -_-.; . . ~ ~ i . . _ . , .- r _ . ~~ . ~ a~. .. ~. ~ - .~. ~ ~ " - ~ ~~~- 1 J-122 ~ : r fi . ii ~ ~ ~ j >. P ` ' 9 , ~~ _ ~ ' . _, , ~ I / , . • ~~ l ' ~- . _ . ~a y '• i ~- ~ w. ~ ~ ~~- ~ ~ . . - i ~' ~ r ~ - - ~ J ~ ~ ' . _ ~ i ~~ ' ~ ~ ~ ~ : ~ _ , . ~„~.~., ---- eorz a~ed vw~~ ~ -- W`' NGtz W011 ~ €, q - - ,~„s ~„~~ ,~. ' ~ - ' . ' ~ ' - Oltser KRU 'iJMell ; „ ~ w ' ' y1f" 1tiW{or Seaing Fautts ~~~ .-i,~.' ~ i - W'~ Faviti ~ - • GL ProCucar - P d ~ .,~; I - no ut~ ~ 51 Producar al ~ ~ '. + P ar-c! A I ~ Y. ~ ~ . ~ In~Ct4k' ~ "`.~ ; tE-702 1Nt rn= BufMer ~ I ~ ~ ~8N! tf4 Tfi BllM~f ~ ~ r , ~ ~ N RCw 114 rn~ Buf'M~` f _ Q Row 'If4 m~ SuM~t ~~VI~LPi ~ ~ .... (]/11kSlt!L+,pi6tiAd8/y ~ ~. ~P/4.'~6U1'lfj81f~1 ~ ~ Gas? Interval 5,924-5,742 1J-170 Cement Top interval 3,135-2,954 Tops •Interval between 6,920' and 2,950' logged • "micro" debonded near shoe •"Micro" debonded pattern continues upwards but improves slightly •Top of cement on log @3036' •570' of cumulative cement bond with 0-20% "micro" debonding Log UG C 4,57~ UG B 5,06: UG A 5,34E K13 5,73f D 6,41( ~ c c~ ~z c~c W c ~ w~ ~C A ~ }I ~~ ~ ~ f` !J u Bottom interval 6, 924-6, 750 /* i Conoco~illips • Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone (907)659-7535 ~ ~ ~F~c 659-7314 August 21, 2007 ,~ ~. t ti i~~, Tom Maunder, P.E. `'" Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 . Q. ~j~'' Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has set a blanking sleeve in the Lateral Entry Module (LEM) of one West Sak multilateral injection well. Enclosed you will find 10-404 Reports of Sundry Well Operation for ConocoPhillips Alaska, Inc. for 1J-170, 1 J-170L1, and 1 J-170L2. These reports record the setting of an LEM isolation sleeve in the L1 lateral water injection well. If you have any questions regarding this matter, please contact-myself at 659=7535. Sincerely, 5~~.1y••• ~~~~ryry{{ {y{yFF' jQ`~ }}bb __ ` SS . n Robert D. Chistensen Attachments ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other O et B-sand Iso Sleeve Alter Casing ^ Pull Tubing ^ Perrorate 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: ConoCOPhilllps Alaska, InC. Development ^ Exploratory ^ 206-064 , 3. Address Stratigraphic ^ Service^ 6. API Number. P. O. Box 100360., Anchorage, Alaska 99510 50-029-23310-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' 1J-170L2 8. Property Designation: 10. Field/Pool(s): ADL 25660; 25661 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12678' feet true vertical 3499' feet Plugs (measured) Effective Depth measured 12678' feet Junk (measured} true vertical 3499' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE 3013' 10-3/4" 3041' 2147 INTERMEDIATE 3.55' 7-5/8" 7894' 3652' SLOTTED LINER 6098' 4-1/2" 12672' 3499' Perforation depth: Measured depth: 6637-12635' true vertical depth: 3428'-3498' ff Tubing (size, grade, and measured depth) 4-1/2", L-80, 6382.6 5' MD. ~ SO~. ~~~'~ ~ Packers &SSSV (type & measured depth) Packer = ZXP Liner top Pkr, Baker Payzone External Casing Packer Packer = 6353', 6523' SSSV =NIP SSSV = 509' 12. Stimulation or cement squeeze summary: yC~ . 7 Intervals treated (measured) i Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 917 1564 672 Subsequent to operation 991 612 348 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well .Operations _X 16: Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt N/A contact Bob Christensen /Vacant Printed Name be .Christe sen title Production Engineering. Technician Signature Phone 659-7535 Date ~ ~ / Form 10-404 Revised 04/2004 Submit gin. n y ` ` 1J-170L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/10/08 PULL B-SAND DIVERTER AND SET B-SAND ISOLATION SLEEVE AT 6818'. JARS RAN ON FIRST RUN, NOT NEEDED. HIPP TRIPPER RUN TO ENSURE ISOLATION SLEEVE SET. q • • WLLL L®G T' SI~I'I"Y'AL 'T®: 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-170+PB1+PB2+Ll+L2 AK-MW-4406587 July 18, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-170+PB 1+PB2+L 1+L2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 5 0-029-23 310-00, 60, 61, 70, 71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 5 0-029-2 3 310-00, 60, 61, 70 Digital Log Images 50-029-23310-00,60,61,70,71 ~ ,,,~~~~ ~~~ ~ ~ ~~~~ ~. 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO-THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage~:Alaska 99518 Anchorage, Alaska 99508 n. ~i _ , ,~ „ , Date: Signed: ~ ~ ~~ ~~.~ ~~G-ova rC~°~a~ ~~~ ~~e ~ol0-0~3 1(0~~~ '~ " ~ ~ 1,~ DATA SUBMITTAL CO PLIANCE REPORT 6/25/2008 Permit to Drill 2060640 Well Name/No. KUPARUK RIV U WSAK 1J-170L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23310-61-00 MD 12678 TVD 3499 Completion Date 6/28/2006 Completion Status 1-OIL Current Status 1WINJ C UIC Y ~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey %~Yes ~,., ~- DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments mRpt 14044 LIS Verification Open 8/22/2006 ,rE~D C Lis 14044 Induction/Resistivity 3004 12620 Open 8/22/2006 GR, FET, Res, ROP rED D Asc Directional Survey 6371 12678 Open 8/22!2006 Well Cores/Samples Information: Name ADDITIONAL INFORM~IILON Well Cored? Y ~'~ Chips Received? ~'F-~~ Analysis '~#~k- Received? Comments: Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Y N Formation Tops N ~ - Compliance Reviewed By: ~= Date: ~ ~: V, ~~ ~~~ ~ _ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS _ f ~.~ ~~iPE"?~~I~u~Bt#/1 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~ Prod to WINJ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ . Waiver ^ Time Extension ^ Change Approved Program.. ^ Operat. Shutdown^ Perforate ^ Re-enterSuspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ F~cploratory ^ 206-064 / 3. Address: Strati ra hic g p ^ Service ^~ 6. API Number:. P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-61 7. KB Elevation (ft): 9. Well Name and Number. RKB 109' 1J-170L2 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25661 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12678' ~ feet true vertical 3499' feet Plugs (measured) Effective Depth measured 12678 feet Junk (measured) true vertical 3499 ~ feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 2932' 10-3/4" 3041' . 2146' L2 WINDOW 1' 7-5/8" 6410' 3401' INTERMEDIATE 7785' 7-5/8" 7894' 3650' D-SAND LINER 5T 5-1/2° 6631' Perforation depth: Measured depth: 6637-12635' true vertical depth: 3428'-3498' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6383' MD. Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 509' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~'"~ ~~~ (,~~'~ ~ ~ ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 2206 ~ 4003 3 1269 222 Subsequent to operation 21 ~ 875 1612 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 ^~ WDSPL^ 17. !hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 306-296 contact Bob Christensen /Bob Buchholz Printed Name O rt D. Ch istensen Title Production Engineering Technician Signature ~ Phone 659-7535 Date iD j ~T ~ ~.23.~ Form 10-404 Revised 04/2004 ~ ~ ~ ~ w~~ `Submit O ' ' al Only 1J-170L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date .Event Summary 09/09/06 Well shut in for Producer to Injector conversion 10/02/06 Commenced Water Injection Service ~ ;` ~ ~~ ,~ ~ ~ ~ n"y A ;~ ~~,~ > FRANK H. MURKOWSKI, GOVERNOR $a. ~, n,~~ ~~ O~ ~ ~ ~~ 333 W. 7"' AVENUE, SUITE 100 COI~TSERQAR`IO1~T COMI~'IISSIOI~T ~ / ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170L2 Sundry Number: 306-296 Dear Mr. Christensen: 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. DATED this.~~ay of September, 2006 Encl. ~~~ STATE OF ALASKA ~~ ~~` ALASKA OIL AND GAS CONSERVATION COMMIS~~s AUG 2 ~ ~®® APPLICATION FOR SUNDRY APPRl4~.laS 6 20 AAC 25.280 ~ ~ - <, S ~~. 1. Type of Requesf: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ r Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ~j~~~c~-- ~Zy Change approved program ^ PuII Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ~ c~ ~~C~b ~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-064 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23310-61 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 chang es: Spacing Exception Required? YeS NO ~ 1J-170L2 . 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660, 25661 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 TVD (ft): Plugs (measured): Junk (measured): 12678' 3499' 12678 3499 Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2932' 10-3/4" 3041' 2146' L2 WINDOW 1' 7-5/8" 6410' 3401' INTERMEDIATE 7785' 7.5/8" 7894' 3650' D-SAND LINER 57' 5-1/2" 6631' 3428' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6637'-12635' 3428'-3498' 4-1 /2" L-80 6383' Packers and SSSV Type: Packers and SSSV MD (ft) no packer ev~ccx~ 1p©~ ~ ~~~3 SSSV= NIP SSSV= 509' 13. Attachments: Description Summary of Proposal 0 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: October 1, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name RObert D. ChrlSt@r1Ser1 Title: Production Engineering Technician Signature Phone 659-7535 Date. Q~~r 6 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ 0~, Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~lS SF~~ sEP ~ ~ Zoos Subsequent Form Required: ~( , APPROVED BY ~~ ~0~ Approved by: MISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 { K ~ ~ ~~ ~. Submit in D~}plicat~•3a,o6 1J-170L2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- , lateral Well 1 J-170L2. This well was pre-produced fora 64 day period in order to recover Oi{ based drilling fluids prior to putting the well on injection. Lateral 1 J-170L2 will provide pressure support for the West Sak D sands. The 10-3/4" Surface casing (3041' and / 2146' tvd) was cemented with 560 sx AS Lite followed by 180 sx DeepCrete. The 7-5/8" Intermediate casing (7894' and ! 3649' tvd) was cemented with 460 sx DeepCrete. The injection tubing/casing annulus is isolated via ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 6353' and / 3391' tvd. This well also contains a Lower B sand 5-1/2" x 7-5/8" ZXP Liner Top Packer located @ 6491' and / 3417' tvd. The top of West Sak D sand was found at 6410' and / 3401' tvd. The top of West Sak B sand was found at 6826' and / 3478' tvd. The top of West Sak A sand was found at 7829' and / 3645' tvd. ~,:: ~r~nac~~i~lli~s ~~~ska} 1~~> 1J-170L2 TuelNC (os3a3, API: 500292331 oD4soo,ID3ssel ''f, SSSVT e: NIPPLE suRrACE (0-3041, Annular Fluid: OD.10750, WC4,:.W) _..... oefe:e.,..e 1 ....~ oar ovo Descri NGS • KRU 1 J-170L2 Tubing String,- TUBING _. - _ Size To I B o ttom I ND Wt Grade I } Thread _ _ _ _ _ 4500 0 6383 3396 _ 12.6)0 L-80 j IBTM Perforations Summary -- Interval N D Zone Status Ft ~ ~ --- SPF_ _ _Date I Type Comment _ 6637 12635 3428 348 WS D 5998 32 625/2006_ SLOTS Alternating slotted/solid pipe <:>::::: '.Gas Lift M andrelsNalves (~ ~66i •~~ _ St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv _ Mfr Cmnt 1 3604 2394 CAMCO KBG-2-1R GLV 1.0 BK-5 0.188 1502 7/14/2006 2 5175 3052 CAMCO KBG-2-1R OV 10 BK-5 0.313__ 0 7/14/_20.0.6 ,~ ~ ~ ~ Other (plugs, equip., etc.) -COMPLETION .-_ ;>:%:~: ~ ~ ~ ~ I Deoth I ND I Tvoe Descriotion ~ I __~ Other lu s, a ui ., etc.) - D-SAND LEM Death ND Tvoe I Descriotion ~ ID IMERMEDIATE (0-7694, OD7 625, wczs 7a~ rwNCfR (saza~a.~o, oD 7 ezs( wR (sa.~o-eb7a, oD asoal sEAL (esle~esle, cD 4740( ,,,,,,,,, sL~vE (e~7a Fv7s, oD s soot PSAM LIFER a E (Fb74e631, ...f. ODSWO, Wt15.50) EUSHIN^i (6631-66~, OD:S 890) Pzrf (6 6 37-1263 6) ~ ;>::• ,.: ~;, D-SAM LINER (f933-12671, 1 rI ~'. srloE 112670-tz671, co awol _~'~'''' ` ''' II:~ 6397 3399 HANGER ABOVE HOOK HANGER 3.980 6407 3401 HANGER INSIDE HOOK HANGER 3.980 6518 3417 SEAL BAKER SEAL ASSEMBLY 4.000 Other ( De th plugs, ND equip., etc.) - D-SAND LINER DETAIL (PLOP 8~ DROP IN OPEN HOLE) T e Descri ion _ ID 6424 3403 HANGER BAKER MODEL B1 HOOK HANGER FOR LEM 4.500 6430 3404 PUP 3.958 6523 3417 CSG PACKER BAKER PAYZONE EXTERNAL CASING PACKER 4.500 6574 3423 SLEEVE BAKER'HR' LINER SETTING SLEEVE 4.950 6596 3425 Bent Joint BENT JOINT BLANK CASING 4.950 6631 3428 BUSHING CROSSOVER BUSHING 5.5" TO 4.5" LINER 3.950 6633 3428 PUP CROSSOVER PUP JOINT 3.958 12670 3499 SHOE SILVER BULLET ECCENTRIC GUIDE SHOE 3.958 __ __ _ _. - -- - General Notes ~ ~~ac~.a~~~~ ~~.3 i~'C:3ANICAL INTEGRITY RDPORT ~ _ ~~ =..G r....,~~.,~. Cement Volumes :~ Amt. Liner Cs~ '-lbC~~ DV `~~ Cmt Jol to cover oers ~-~c~-~~~ Co`~~~~ ~~ ~~~~U`sC~~(oSx~ _ eoretiCal TOC L`.~(`~ 15.5 "~~~ ~`45~, ~~Ce~:c~~~C~v~rcCe~cF~ j~~~ r-. r n ~ LL DAT~_ TD : ?~.. TVD ; ?BTD : ?ID I'VD C a s i~ g : ~-=~~' Shoe : 'Z~`~'1t~ ~~~ TVD ~ DV : ~ ~ ?~ ~ b.~T~-D _;:,er : Shoe : ~ T`JT ; :CP . i-~ ~'iD t -~'~ ~ ' _' „ .P a c is e r b 3 ~S 3 uD T VD ; Set a ~ `t o. SEc.,,` C~. _ole Site C "-! and Perfs ~ to ~~~., ~`=,C'r'.~?~=C~.L !.NTEGRTTY - ??..RT #I cnnulus Press Test: _? Cor,.~ents 15 min :; 0 min '~'CHANIC~~., INTEGRTTY - PART #Z ~ ~~sW~~`S . c~ U '~ J U ~~ f f 7 d 30 OPER ~ FIELD ~'~~L ~ZV ~~ h ALL NUMB F.R ~J `_' i ~,~ - `'~.~~°'~ s ~~ ~~ Cement Bond Log (Yes or No) ~ In AOGCC File CBL Bvaluation, gone above perfs '~~,,~~~~~ 3t~~cc:~~~ vJE~.~ Production 'Log: Type CONCLUS ~ OI1S Part ; 1 ?art. T 2 : ~~ i ~~~~~-~~ a~~ Evaluation r1 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Co. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs Juiy 19, 2006 1J-170, PBI, PB2, L1 & L2, AK-MW-4406587 1 LDWG formatted CD Rom with verification listing(s). API#: 50-029-33100-00, 70, 71, 60, 61. awl e o Lt e t-o ~c1~ c~ c~- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TI3E ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Ancho~r+age,Al/asCka 99518 Dat~UG 2 2 2006 aka Qil & c;as Cons. Anchorac,~ Signed: ~ ~~ ~~lb • • 07-Aug-06 AOGCC Ceresa Tolley 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1J-170 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 6,371.85' MD Window /Kickoff Survey: 6,409.00' MD (if applicable) Projected Survey: 12,678.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date o~~ ~-~a ~S ~ (e Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ao~- ~ u~~ ~'E~EIV'ED STATE OF ALASKA ~ ~~~~~ ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT~w~YI~ls®fi emission 1a. Well Status: Oil ^ Gas Plugged Abandoned ^ Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other _XX Pre-produced Injector 1b. Well Class: n~ t3Cag~ Development ^/ Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillipsAlaska,lnc. 5. Date Comp., Susp., orAband.: June 28, 2006 12. Permit to Drill Number: 206-064! 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~ ~ _~~ 006 g• 13. API Number: 6 50-029-23310-61 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2489' FEL, Sec. 35, T11N, R10E, UM 7. Date TD Reached: June 23, 2006 14. Well Name and Number: 1J-170L2 At Top Productive Horizon: 1970' FSL, 670' FEL, Sec. 34, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKg 15. Field/Pool(s): Kuparuk River Field Total Depth: 2368' FNL, 557' FEL, Sec. 27, T11 N, R10E, UM 9. Plug Back Depth (MD + 7VD): 12678' MD / 3499' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 y- 5945614 Zone- 4 10. Total Depth (MD + TVD): 12678' MD / 3499' TVD 16. Property Designation: ADL 25660, 25661 TPI: x- 555260 y- 5945755 Zone- 4 Total Depth: x- 555318 - 5951977 Zone- 4 11. Depth where SSSV set: nipple @ 509' 17. Land Use Permit: ALK 470 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permaf r ost: 4574' MD e ~ 21. Logs Run: IfLO~ /O~ /~ /~'~b/ ,~ ~ TVp $'g•dro GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 62.6# H-40 28' 108' 28' 108' 42" 395 sx AS 1 10.75" 45.5# L-80 28' 3041' 28' 2146' 13.5" 560 sx AS Lite, 180 sx DeepCRETE 7-5/8" 29.7# L-80 28' 7894' 28' 3649' 9-7/8" 460 sx DeepCRETE 5.5" x 4.5" 15.5# / 11.6# L-80 6574'/6633' 6631'/12671' 3423' 3499' 6.75" slotted liner 23. Pertorations open to Production (MD + TVD of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore slotted liner from 7110'-7362', 7835'-8093', 8728'-8983', 9449'-9702', 10213'-10461', 11095'-11354', 11868'-12117' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED none 26. PRODUCTION TEST Date First Production July 18, 2006 Method of Operation (Flowing, gas lift, etc.) Pre-produced gas lift oil -shares production with 1J-170 and 1J-170L1 Date of Test 7/20/2006 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1521 GAS-MCF 615 WATER-BBL 0 CHOKE SIZE 5 Bean GAS-OIL RATIO 438 Flow Tubing Not available Casing Pressure 1360 Calculated 24-Hour Rate -> OIL-BBL 2535 GAS-MCF 1111 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". ~Of11C"`"" ~uLCjjpi~ ~aTF NONE S ~~. AUG ~ ~ 20D6 Vf -i ®~ Form 10-407 Revised 12/2003 O ~ ~ ~ I ~ ~ ~ CONTINUED ON REVERSE AFi~ ,dD(p ,~ ~1~~oG G r ~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1J-170L2 Top West Sak 6410' 3499' West Sak D 6410' 3401' N/A 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: David Nugent @ 265-6862 Printed Name nd Thomas Title: Greater Kuoaruk Area Drillino Team Leader Signature ~ a Phone Date ~~ ~ ( ,,[_ ~ ~ Prepared by Sharon Allsup-Drake ~i/fiGTf ~~J~ -S INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, salt water disposal, water supply for injection, observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: the Kelly Bushing elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12!2003 'rte'` ConocoP~iiips Time Log Summary Welk ic.w tYetx Fteperbng Time Loys j i Date From To Dur S De th E Depth~Phase Code Subcode T CON1 05/25/2006 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Move rig to 1J-170. 05/26/2006 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Cont. to move rig from 1J-184 to 1J-170, Lay mat boards, spot pits, um s, motor & broiler com lexes. 03:00 03:30 0.50 0 0 MIRU MOVE PSIT P Spot rock washer 03:30 04:30 1.00 0 0 MIRU MOVE PSIT P Spot pipe sheds 04:30 09:00 4.50 0 0 MIRU MOVE OTHR P Work on rig pre-acceptance checklist. Install service lines, prepare pits to take on water. Assemble mud pump lines, assemble skate, level pipe shed. Berm rock washer. ACCEPT RIG @ 08:00 hrs. 09:00 12:00 3.00 0 0 SURFA DRILL PULD P PJSM: P/U 5" DP from shed and rack back in derrick. total of 78 'oints. 12:00 13:00 1.00 0 0 SURFA DRILL PULD P Cont to P/U DP and 6 stands of HWDP with 'ars and rack back. 13:00 13:30 0.50 0 0 SURFA WELCT BOPE P Perform diverter test. AOGCC Jeff Jones waived witnessin at 09:30 hrs. 13:30 14:30 1.00 0 0 SURFA DRILL PULD P Clean rig floor. P/U BHA from beaver slide. 14:30 15:30 1.00 0 0 SURFA DRILL PULD P Make up monels, bit and stablizer. 15:30 16:00 0.50 0 0 SURFA DRILL CIRC P Flood mudlines and conductor. 16:00 17:30 1.50 0 0 SURFA DRILL RURD P PJSM. Rig up gyro. 17:30 20:30 3.00 108 222 SURFA DRILL DRLG P Make up Bit #1 & Mud Motor, Spud well @ 17:30 hrs, Drill f/ 108' to 222' with 2 std's HWDP. 525 gpm, 550 psi, 60 r m, 0 for ue, 8K on bit. 20:30 23:00 2.50 222 222 SURFA DRILL TRIP P POOH, Change Motor bend to 1.83, P/U MWD and RIH to bottom. 23:00 00:00 1.00 222 254 SURFA DRILL DRLG P Drill from 222' to 254' @ 500 gpm, 900 psi, 40 rpm, 0 torque, 60 ROP, 8K on bit. 05/27/2006 00:00 12:00 12.00 254 966 SURFA DRILL DRLG P Drilled 13.5" hole from 254' to 966' MD. ART=4.15, AST=2.18, ADT=6.33 PU=77K, S0=76K, ROT=79K, TOon=3, TQoff=1 Jar hours=8.38 hrs, Max Gas=47 btu Byro depths: 253, 347, 440, 530, 621, 713, 816 _ ~. ~ ___~ ~_ _ ._.~_e ~.~._ _ --- ~ _ ~ i~~~ 1 of ~7~~~ ---- -_ Time Logs Date From To Dur 5 epth_ E. Depth Phase Cocie Subcode T ~,OM - - - 05/27/2006 12:00 22:30 10.50 966 2,110 SURFA DRILL DRLG P Drilled 13.5" hole from 966' to 2110' MD, 1771 TVD 570 gpm, 1550 psi on btm, 1400 psi off btm, 6K TQ with pumps on PU=93K, S0=76K, ROT=89K with pumps on Jar hours=16.25 22:30 22:45 0.25 2,110 2,110 SURFA DRILL CIRC P Circ to clear BHA 22:45 00:00 1.25 2,110 1,835 SURFA DRILL REAM P Monitor well: Static. BROOH from 2110 to 1835 @ 700 gpm, 2000 psi, 45 rom, 4-5 TQ 05/28/2006 00:00 01:45 1.75 1,835 723 SURFA DRILL REAM P Cont to BROOH from 1835' MD to 732' MD. ROT at 40 rpm, 168 spm, 1900 si. 01:45 03:00 1.25 723 0 SURFA DRILL TRIP P POOH on elevators to surface. 03:00 03:30 0.50 0 0 SURFA DRILL OTHR P Drain motor, grade bit, turn motor to 1.15 de .Orient to MWD. 03:30 05:00 1.50 0 2,110 SURFA DRILL TRIP P RIH to 2020' wash and ream to 2110' MD at 520 gpm, 123 spm, ROT 10 r m, TQ=3K. 05:00 12:00 7.00 2,110 2,759 SURFA DRILL DRLG P Drilled from 2110' to 2759' MD, 2031' TVD. ART=2.48, AST=1.52, ADT=4.0 PU=100K, S0=72K, TQon=8K, TQoff=4-6K Max Gas=1732 BTU @ 2642' MD, 1982' TVD. Jar hrs=20.25 12:00 14:45 2.75 2,759 3,050 SURFA DRILL DRLG P Drilled from 2759' to 3050' MD, 2149' TVD. ART=0.4, AST=0.67 ADT=1.07 PU=100K, S0=72K, TQon=8K, TQoff=SK Max Gas=67 BTU Jar hrs=22.22 14:45 15:15 0.50 3,050 3,050 SURFA DRILL CIRC P Circ and condition mud. 15:15 18:00 2.75 3,050 1,186 SURFA DRILL REAM P Monitor well and BROOH from 3050' MD to 1186' MD at 700 gpm, 40 fpm, 2000 si, 100 r m, 5-8K. 18:00 19:30 1.50 1,186 163 SURFA DRILL TRIP P Pull last 4 stds of DP on elevators, LD ghost reamer and 3 stds HWDP. Rack back last 3 stands of HWDP & 'ars. 19:30 21:00 1.50 163 0 SURFA DRILL PULD P LD collars, MWD, motor and bit. 21:00 23:30 2.50 0 0 SURFA CASIN( RURD P Clear and clean rig floor. RU to run 10 3/4", 45.5#, L-80 BTC casin . 23:30 00:00 0.50 0 0 SURFA CASIN( RNCS P Dummy run landing joint. 05/29/2006 00:00 05:15 5.25 0 3,041 SURFA CASIN( RNCS P PJSM, Pick up 10-3/4" Shoe, 2 jts 10-3/4", 45.5#, L-80, BTC casing, Float collar and check floats- OK, Run 10-3/4" Casing to 3007' (Pumped down f/ 1707' to 1825'), Make up hanger and land casin 3041. 05:15 06:15 1.00 3,041 3,041 SURFA CASIN( CIRC P Circ btm's up at rate of 6 bpm @ 350 si. e ----~--- --- ~~ ~ ~ a~~ '~ of 27 Tim~Loc~s_ ~, Date From To Dur She th EDe th Phase Code Subcode T QOM _ 05/29/2006 06:15 06:45 0.50 3,041 3,041 SURFA CEMEf~ RURD P Lay down Franks fill up tool, Make up Dowell cement head. 06:45 08:30 1.75 3,041 3,041 SURFA CEMEf~ CIRC P Continue to Circ. & Cond. mud for cement at rate of 7.0 bpm @ 4000 psi, Reciprocate pipe 10'-Mud prior to circ.= Wt. 9.4 ppg, Vis 278, PV 35, YP 58, Mud after= Wt. 9.1 ppg, Vis 44, PV 16, YP 5, Held PJSM with all hands and Dowell 08:30 11:15 2.75 3,041 3,041 SURFA CEME~ CIRC P Turned over to Dowell and cemented 10 3/4" csg, pumped 10 bbls of CW 100 at 8.3 ppg, pressure tested lines to 3,500 psi, then pumped an additional 40 bbls of CW 100 (50 bbls total), then pumped 50 bbls of 10.5 ppg mudpush w/ red dye, dropped btm plug, began mixing and pumping Arcticset lead slurry, pumped 462.4 bbls (560 sxs) of lead cement at 10.7 ppg and 4.63 yield with additives, ave 7.0 bpm at 200 psi, followed with 79.5 bbls (180 sxs) of DeepCrete tail cmt at 12.0 ppg and 2.47 yield with add., ave 6.9 bpm at 435 psi, reciprocated csg 10' and had full returns, shut down and dropped top plug and Dowell pumped 20 bbls fresh water then turned over to rig. Rig displaced cement with 261.0 bbls (2592 stks) of 9.1 ppg mud, displaced cmt at 7.0 bpm, initial circ pressure 600 psi, max pressure 900 psi, slowed rate to 3 bpm and bumped plug on calc displacement, pressured up to 1300 psi, held 5 min, checked floats and held, CIP @ 11:15 hrs, had full returns during job and had 120.0 bbls of 10.7+ ppg cmt back to surface, reciprocated csg until 112.5 bbls cmt around shoe.- then pipe became tight, st wt up 165K, do wt 86K, Landed casing with Shoe @ 3,041.12' and Float collar 2,954.08'. 11:15 12:00 0.75 0 0 SURFA CEME~ RURD P Check float equipment, R/D cement e ui ment. 12:00 13:00 1.00 0 0 SURFA CEMEt~ RURD P Cont to R/D cmt equipment, clear and clean ri floor. 13:00 17:00 4.00 0 0 SURFA WELCT NUND P Flush stack & N/D diveter with Crain. 17:00 18:30 1.50 0 0 SURFA RIGMN SVRG P Change out saver sub. 18:30 20:00 1.50 0 0 SURFA WELCT NUND P N/U wellhead & test to 5000 psi for 10 min. NU BOPE. 20:00 21:30 1.50 0 0 SURFA WELCT BOPE P RU BOPE test equipment. Time Logs Date From To Dur S. ~e nth E. De th Phase Code Subcode T COf~~1 05/29/2006 21:30 00:00 2.50 0 SURFA WELCT BOPE P Start BOPE test with top set #1, #12, #13, #14, M/Kill, 4" dart valve, 2nd test: 4" TIW, HCR kill, #9, #11, 3rd: test lower IBOP, #5, #8, #10.4th test Upper IBOP, #4, #6, #7. 5th test: 5" TIW, #2. 6th test HCR choke, 5" Dart, 7th test annular w/ 4" DP, mania) choke, all test 250 fow, 3000 psi high. Jeff Jones waived witnessing 5/28/06 12:30 hrs. 05/30/2006 00:00 02:15 2.25 0 0 SURFA WELCT BOPE P Cont to test BOPs to 250 psi low, 3000 psi high. Test top rams w/ 5" DP, blind rams, lower pipe rams w/ 7 5/8", annular w/ 7 5/8".Accumulator test=inita13000 psi, close 1800 psi, 200 psi attained 42 sec, full pressure in 3 min 21 sec, 5 bottle nitrogen avers a 2250 si. 02:15 02:45 0.50 0 0 SURFA WELCT OTHR P Set wear ring bushing. 02:45 03:45 1.00 0 0 SURFA DRILL OTHR P PJSM. RU short bails, elevators, inspect top drive. C/O heads on iron rou h neck. 03:45 06:45 3.00 0 0 SURFA DRILL TRIP P PJSM. RIH with 4" DP and rack back in derrick. 78 'oints 26 stands . 06:45 09:45 3.00 0 0 SURFA DRILL TRIP P PJSM. RIH with 87 joints 4" DP and rack back in derrick. 09:45 10:30 0.75 0 0 SURFA DRILL PULD P Clear and clean rig floor. P/U BHA from Beaver slide. 10:30 12:00 1.50 0 26 SURFA DRILL PULD P M/U 9 7/8" BHA: bit, motor, C/O roughneck heads to 5" for picking up MWD. 12:00 13:30 1.50 26 1,000 SURFA DRILL PULD P M/U float sub, stabilizer, MWD, NMFC, 'ars, HWDP, GR. 13:30 14:30 1.00 1,000 2,951 SURFA DRILL TRIP P TIH and tag float collar at 2,951' MD. 14:30 15:30 1.00 2,951 2,951 SURFA DRILL CIRC P Circ and condition mud for casing test. 15:30 16:00 0.50 2,951 2,951 SURFA CASIN( DHEQ P Test casing to 3000 psi for 30 mins on chart. 16:00 17:15 1.25 2,951 3,070 SURFA DRILL REAM P Wash and ream to shoe at 3,041', drill out shoe track plus 20' of rat hole to 3,070' MD. 17:15 17:45 0.50 3,070 3,070 SURFA DRILL CIRC P Circ and condition mud and R/U for LOT. 17:45 18:30 0.75 3,070 3,070 SURFA DRILL LOT P Perform LOT on chart at 10 spm, 56 strokes, 5.6 bbls. at 3041' MD, 2,146' TVD w/ 600 psi, 9.0 ppg = 14.4 ppg EMW 18:30 00:00 5.50 3,070 3,755 INTRM1 DRILL DRLG P Drill from 3,070' to 3,755' MD, 2,463' TVD AST=1.62, ART=1.14, ATD=1.67 hrs PU=112K, So=65K, ROT=82K, TOoff=S-7K Jar hrs=2.76 hrs I _ _ I Time Lis Date --- From To D ur 5. epth E, De~th - - - Phase Code Subcode T - -- --- - `OM 05/31/2006 00:00 12:00 _ 12.00 _ __ 3,755 5,007 _ INTRM1 DRILL DRLG _ P Drill from 3,755' to 5007' MD, 2981' TVD AST=4.97, ART=,4.97 ATD= 7.24hrs PU= 128K, S0= 65K, ROT= 85K, TQoff= 7K, TQon= 8K Jar hrs =31.94 hrs 600 gpm, 2000 psi, WOB=S-30K, ROT=85 rpm Pumped sweep at 4586' with 15% increase in returns. 12:00 00:00 12:00 5,007 5,947 INTRM1 DRILL DRLG P Drill from 5,007' to 5,947' MD, 3,313' TVD AST=7.04, ART= 3.37, ATD= 10.41 hrs PU= 116K, S0= 79K, ROT= None to maintain directional work, TQon= 6K Jar hrs = 42.35 hrs ECD=10.04, Max Gas = 59 btu 500 gpm, 85 rpm, W0B=5-30K, 2250 psi Added 2% lubricants at 16:00, 5300' MD 06/01/2006 00:00 12:00 12.00 5,947 6,747 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 5,947' to 6,747' (800') 3,463' TVD, WOB 10-35K, RPM 85, 600 gpm @ 2100 psi, Up 117K, Dn 72K, Rot 87K, TQ 8K on/ 5-7K off, Ave ECD's 9.89 ppg, Max gas 137 Units, Concretions 6,150' to 6,170', 6,510' to 6,530'. 12:00 00:00 12.00 6,747 7,814 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 6,747` to 7,814' (1,067') 3,643' TVD, ART= 7.25 hrs, AST= 2.42 hrs, ADT= 9.67 hrs, WOB 15-25K, RPM 85, 625 gpm @ 2675 psi, Up 121 K, Dn 71 K, Rof 87K, TQ 7K on/ 5-7K off, Ave ECD's 10.41 Max as 88 Units. 06/02/2006 00:00 02:00 2.00 7,814 7,900 INTRM1 DRILL DDRL P Directional Drill 9-7/8" hole f/ 7,.814' to 7,900' (86') 3,650' TVD, ART= 1.05 hrs, AST= 0.62 hrs, ADT= 1.67 hrs, WOB 10-30K, RPM 90, 650 gpm @ 2400 psi, Up 121 K, Dn 71 K, Rot 87K, TQ 6-8K on/ 5-7K off, Ave ECD's 10.01 Max as 89 Units. 02:00 03:15 1.25 7,900 7,900 INTRM1 DRILL CIRC P Pump Hi-vis Weighted sweep &Circ hole clean at rate of 600 gpm @ 2200 psi, 90 RPM - No increase in cuttings from swee . 03:15 09:45 6.50 7,900 3,040 INTRM1 DRILL REAM P Monitor well, Back Ream out of hole f/ 7,900' to 3,040' at rate of 40/45 ft/min. w/ 650 gpm @ 2350 psi & 90 RPM, TQ 6-7K. Hole in ve ood sha e. 09:45 10:30 0.75 3,040 3,040 INTRM1 DRILL CIRC P Pump Hi-vis weighted sweep &Circ hole clean with 3 Btm's u . 10:30 15:00 4.50 3,040 0 I NTRM1 DRILL PULD P Pump dry job, POOH & Lay down all 5" drill pipe, HWDP, Jars, Down load MWD tools, La down BHA. ~ ~.~_.__e__~~~ e _- - - - _m ~~~~ ~~~~f ~?7 - - Tirne Logs -- Date From To Dur 5. ~ e th E._Depth _Phase _ Code Subcode T ~;~M ~ 06/02/2006 15:00 16:00 1.00 0 0 INTRM1 DRILL PULD P Clean & clear rig floor of all drill tools. 16:00 17:30 1.50 0 INTRM1 CASIN ( RURD P Rig to Run 7-5/8" casing. 17:30 00:00 6.50 0 4,360 INTRM1 CASIN ( RNCS P Run 7-5/8" Shoe (1.51'), 2 jts 7-5/8", 29.7#, L-80, BTCM (87.36'), Float Collar (1.28'), 22 jts csg (937.91'), 1- Pup jt (6.18'), 1- Window jt. (43.04'), 8 jts csg (337.47'), 3- Pupjts (37.37'), 1- Windowjt (42.15'), Continue running to a total of 100 jts to 4,360' at 23:59 hrs., Circ Btm's up at shoe @ 3,030' with no problems at rate of 6 bpm @ 350 si. 06/03/2006 00:00 02:45 2.75 4,360 7,894 INTRM1 CASIN( RNCS P Continue to run 7-5/8" casing f/ 4,360' to 7,894' (Tagged Btm with extra joint #184 & la ed down same . 02:45 03:45 1.00 7,894 7,894 INTRM1 CEME~ PULD P RD Franks fill up tool and MU Dowell's cement head. 03:45 06:00 2.25 7;894 7,894 INTRM1 CEMEt~ CIRC P Circ and Cond mud for cementing, Circ at 6.5 bpm at 425 psi, Up 195K, Dn 80K, Initial MW out, 9.3+ ppg, 56 vis, PV 12, YP 23, Conditioned mud to final MW of 9.0 ppg, 39 vis, 7 PV and 12 YP, Held PJSM with Dowell, ASRC vac truck drivers and rig crew on cementin cs while circ hole. 06:00 08:30 2.50 7,894 7,894 INTRM1 CEME~ CIRC T While priming up Dowell cement unit one of the engines had a fuel pump failure. Wait on another cement unit while continuing to circ & condition mud_ Time Logs Date From To Dur b- e th E. De th Phase Code Subrode T :OM - - _; 06/03/2006 08:30 11:00 2.50 7,894 7,894 IN l`f-ZM1 CEMEI ~ DISP P -- - Dowell pumped 10 bbls CW 100 at 8.3 ppg at rate of 4.6 bpm @ 185 psi, Pressure tested lines to 3,500 psi, Then pumped 65 add. bbls of CW 100 at rate of 4.5 bpm @ 190 psi, Dropped btm plug, Pumped 75 bbls of MudPush at 11.0 ppg at rate of 4.6 bpm @ 230 psi, Followed by 184.9 bbls, (460 sxs - 25% over calculated) of DeepCrete cmt at 12.5 ppg, 2.25 yield with additives, ave 4.5 bpm at 205 psi, Reciprocated pipe 30' with full returns. Drop top plug and Dowell kicked top plug out with 5 bbls fresh water. Rig displaced cement with 9.0 ppg. OBM, Bumped plug on talc displacement after pumping 353.2 bbls OBM (Total of 358.2 bbls) {96% pump eff.) ave 7 bpm while displacing cmt, Initial pressure 300 psi, Max pressure 1150 psi, Slowed pump rate to 3 bpm 750 psi) with 10 bbls left to pump and bumped plug to 1300 psi, ck floats and held. CIP at 11:00 hrs. 6/3/06. Reciprocated pipe until 87.3 bbls cmt was around shoe when hole began getting tight and stopped reciprocating, landed csg with Shoe @ 7,894.00', Float Collar @ 7,803.85', Calc TOC @ 4,167', Had full returns thru out job. Well static after shut down. 11:00 12:00 1.00 0 0 INTRM1 CEME~ PULD P Rig down Dowell cement head, Vacuum out OBM from cut off stub. 12:00 12:30 0.50 0 INTRM1 CASIN< NUND P Nipple down well head and raise stack, Set casing slips w/ 155K on indicator - tention 75K. 12:30 16:30 4.00 0 0 INTRM1 CASINC NUND P Cold cut 7-5/8" casing, Remove cut off, Install pack off, Nipple up well head & stack, Test pack off and flange break to 3800 psi f/ 10 min- OK, Install wear bushin . 16:30 18:00 1.50 0 INTRM1 DRILL PULD P Bring 4" Lo-Tad's to rig floor, Rig to pick up 4" drill pipe, Pick 21 joints 4" XT-39 HWDP. Note; Perform infectivity test on 7-5/8" x 10-3/4" annulaus with 9.0 ppg mud, 450 psi, 2149' TVD= 13.0 ppg EMW. Flush annulus with total of 141 bbls fresh water at rate of 2.0 bpm @ 760 si. e _ ~ e~ ~ ~=~~ r ~~'f ~? Time Lomas _ - _ _ -- -_ _ Dafe From To Dur S_ e~h_E Ue_pth Phase Code Subcode T__ QOM ____ ~ 06/03/2006 18:00 19:00 1.00 INTRM1 DRILL PULD P Pick up 51 jts 4" XT-39 drill pipe from pipe shed. Note; Rig little red senrixce and freeze protect 7-5/8" x 10-3/4" annulus with 85 bbls diesel at rate of 1.8 bpm @ 800 si. 19:00 21:00 2.00 INTRM1 DRILL PULD P POOH installing 4" Lo-Tad's and rack back 17 stands in derrick. 21:00 00:00 3.00 INTRM1 DRILL PULD P Pick up 99 joints 4" XT-39 drill pipe with WWT Sliders installed from pipe shed. 06/04/2006 00:00 03:15 3.25 3,720 0 INTRM1 DRILL PULD P . POOH and stand back 33 stands 4" D.P. with Sliders and install 1-Lo Tad per stand, Stand back 7 stands 4" HWDP. 03:15 03:45 0.50 0 0 INTRM1 DRILL PULD P Clear & Clean rig floor. 03:45 07:00 3.25 0 0 INTRM1 DRILL PULD P Rig & Pick up 15 stands Hybrid Push Pipe (2-jts 4-3/4" Spiral DC's & 1-jt HWDP), POOH and stand back 15 stands Push Pi e. 07:00 10:45 3.75 0 360 INTRM1 DRILL PULD P PJSM, Pick up BHA #4 - 6-3/4" Bit #3, 4-3/4" 5200 Geo Pilot, MWD tools, Stab's, Flex collars & HWDP, Break in Geo Pilot. 10:45 12:30 1.75 360 2,160 INTRM1 DRILL TRIP P Pick up 60 jts 4" Drill pipe from pipe shed. 12:30 15:00 2.50 2,160 7,803 INTRM1 DRILL TRIP P RIH w/pipe from derrick to 7,790', Screw into top dive, Pump down and to float collar 7,803'- OK. 15:00 15:30 0.50 7,803 7,803 INTRM1 DRILL CIRC P Circ Btm's up for 7-5/8" Casing test. 15:30 16:45 1.25 7,803 7,803 INTRM1 RIGMN SVRG P Cut & Slip drilling line 86', Service top drive & Drawworks, Check saver sub. 16:45 17:45 1.00 7,803 7,803 INTRM1 DRILL DHEQ P Rig & Test 7-5/8" Casing to 3000 psi for 30 min.- OK. 17:45 20:00 2.25 7,803 7,920 INTRM1 CEME~ DRLG P Drill out float collar @ 7,803', Cement & Shoe 7,894', 20:00 20:15 0.25 7,900 7,920 INTRM1 DRILL DDRL P Drill 20' new hole to 7920' MD / 3,651' TVD. 20:15 21:00 0.75 7,920 7,920 INTRM1 DRILL LOT P Rig & perform LOT with 8.7 ppg mud, 3650' TVD, 1184 si = 14,9 EMW. 21:00 00:00 3.00 7,920 8,270 PROD1 DRILL DDRL P Drill ahead with Sperry-Sun Geo Pilot f/ 7,920' to 8,270' MD / 3,668' TVD, ADT= 1.71 hrs., WOB 7-8K, RPM 110, 300 gpm @ 2650 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max as 62 units, Ave ECD's 10.2 06/05/2006 00:00 00:30 0.50 8,270 8,367 PROD1 DRILL DDRL P Drill w/Geo Pilot f/ 8,270' to 8,367' MD (97'), ADT= .56 hrs., WOB 5-7K, RPM 120, 306 gpm @ 2600 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 ~~_~~.._~ ~ .~~_. '~~~aa 3 ~ r ~7 ~ ~ ~_ ~_ ..._~ ___-__ ~ Time Logs ~ Date From To Dur 5 e~th E- Depth_Phase Code___ Subcode T_ QOM __ 06/05/2006 00:30 02:30 2.00 8,367 8,367 PROD1 DRILL WOOR NP Circ at rate f/ Geologist to evaluate to s with Anchora e. 02:30 03:45 1.25 8,367 8,514 PROD1 DRILL DDRL P Drill w! Geo Pilot f/ 8,367' to 8,514' MD (14T), ADT= .56 hrs., WOB 12-15K, RPM 100, 270 gpm @ 2250 psi, Up 125K, Dn 54K, Rot 84K, Tq on 6K/6K off, Max gas 62 units, Ave ECD's 10.2 03:45 04:30 0.75 8,514 8,514 PROD1 DRILL REAM NP Evaluate for Geologist -Back ream f/ 8,514' to 8,365' for possible Sidetrack - Chan e of Ian & Return to Btm. 04:30 10:45 6.25 8,514 9,281 PROD1 DRILL DDRL P Drill w/ Geo Pilot f/ 8,514' to 9,281' MD / 3,634' TVD (767'), ADT= .4.53 hrs., WOB 8-12K, RPM 130, 313 gpm @ 2875 psi, Up 135K, Dn 52K, Rot 86K, Tq on 6.5K/7K off, Max gas 132 units, Ave ECD's 10.7 _ 10:45 12:15 1.50 9,281 7,887 PROD1 STK TRIP NP Monitor well- OK, POOH on elevators to 7,887' for SideTrack. 12:15 13:00 0.75 7,887 7,940 PROD1 STK KOST NP Orient Geo Pilot & Trench f/ 7,887' to 7, 940'. 13:00 16:30 3.50 7,940 7,990 PROD1 STK KOST NP Time drill f/ 7,940' to 7,990', ADT= 2.0 hrs w/ 100 RPM 300 m 2600 si. 16:30 00:00 7.50 7,990 8,657 PROD1 DRILL DDRL NP Drill w/Geo Pilot f/ 7,990 to 8,657' MD / 3,652' TVD (3,652'), ADT= 6.18 hrs.., WOB 5-12K, RPM 130, 313 gpm @ 2600 psi, Up 130K, Dn 65K, Rot 84K, Tq on 6K/6K off, Max gas 144 units, Ave ECD's 10.3 06/06/2006 00:00 05:30 5.50 8,657 9,206 PROD1 DRILL DDRL NP Drlg f/ 8657' to 9206'MD / 3650' ND ADT= 5.34 hrs, PU wt 138k, SO wt 55k, Rot wt 85k, Troq on bttm 7k, off bttm 7.5k 05:30 06:00 0.50 9,206 9,206 PROD1 DRILL CIRC NP Circu -Geologist evaluate logs 06:00 12:00 6.00 9,206 9,875 PROD1 DRILL DDRL P Drlg f/ 9206' to 9875' MD ADT 3.48 - Pumped Wt/HiVis sweep @ 9527 MD with NO % increase in cuttings. Up wt and Dn wt showing large increases on T&G model. Rig engineer checking all data to make sure it is correct. PU wt 150k, SO wt Ok, Torq off bttm 7k, on bttm 7k, MAx Gas 102, ECDs 10.88, Jar hrs total 99.65 12:00 13:30 1.50 9,875 10,159 PROD1 DRILL DDRL P Drlg f/ 9875' to 10,159' MD / 3646' TVD - PU wt 165k, SO wt Ok, Rot wt 84k, Torq on bttm 7k, off bttm 7k -ADT 1.15 hrs 13:30 13:45 0.25 10,159 10,159 PROD1 DRILL CIRC T Circu - MWD computer reboot- Locked u 13:45 15:30 1.75 10,159 10,397 PROD1 DRILL DDRL P Drlg f/ 10,159' to 10,397' MD / 3646' TVD. ECDs Model still showed T&D with large increases on Up wt and NO do wt. Decission was made to make wiper trip to the shoe to evaluate hole conditions. _ .-~ r~~ ~a 3 ~f ~7 ____ ~ ____ t ~ _ ~ _ - _ - Time Lois l Date _ Frorn To Dur S __ ~~ E. Depth Phase Code Subcode T CUM 06/06/2006 15:30 15:45 0.25 10,397 10,397 PROD1 DRILL CIRC P Circu- Pump sweep & condition hole for wi er tri -Zero toolface on GeoPilot 15:45 19:00 3.25 10,397 7,894 PROD1 DRILL REAM P Wiper Trip - BROOH f/ 10,397' MD to 7894' MD(7.625" shoe) PR 310 GPM, RPMs 85 - No roblems seen. 19:00 20:15 1.25 7,894 7,894 PROD1 DRILL CIRC P Pump 30 bbl Wt/HiVis sweep -Rot & Recip string - PR 310 gpm, RPMs 85- Sweep to surface saw 5% increase in cutting. Up wt 170k, Dn wt 70k in casin . 20:15 20:45 0.50 7,894 7,940 PROD1 DRILL TRIP P TIH -Pump down 3 stds -orient tool thru kick off area @ 7940' -Entered new well bore without an roblems. 20:45 21:45 1.00 7,940 10,111 PROD1 DRILL TRIP P TIH on elevators to 10,111' 21:45 22:15 0.50 10,111 10,396 PROD1 DRILL REAM P Wash & Ream 10,111' to 10,396' MD - PR 310 m, RPMs 80, PP 2800 si 22:15 00:00 1.75 10,397 10,558 PROD1 DRILL DDRL P Top Drive up @ Std #106, Orient Geo Pilot, Drlg f/ 10,397 to 10,558' MD ! 3649' TVD - PR 310 gpm, PP 3000 psi, RPMs 125, WOB 6-8k, Torq 7k on bttm. ADT= .76 06/07/2006 00:00 00:30 0.50 10,558 10,558 PROD1 DRILL CIRC T Made several attempts to get GeoPilot to respond to signal - No responce - Monitorwell -Static 00:30 02:00 1.50 10,558 7,870 PROD1 DRILL TRIP T POOH on elevators 10,558' to 7870' MD with no roblems 02:00 02:30 0.50 7,870 7,780 PROD1 DRILL OWFF T Observe well for flow -Pump dry job 02:30 05:00 2.50 7,780 360 PROD1 DRILL TRIP T POOH on elevators 7,870' to 360'. Displ for trip =actual 66 bbls, calculated 60.2 05:00 05:30 0.50 360 90 PROD1 DRILL TRIP T Stand back 2 stds HWDP w/Jars and 1 std NMFDCs 05:30 06:00 0.50 90 90 PROD1 DRILL SRVY T Down Load MWD 06:00 07:00 1.00 0 0 PROD1 DRILL PULD T L/D BHA #4 - FS, Stab, MWD, Smart Sub, DM, NM Geo flex, Geopilot & bit.. Bit looks good -grade 1 -1 will run back. 07:00 07:45 0.75 0 90 PROD1 DRILL PULD T PU & MU BHA #5 -GeoPilot, Bit, NM Geo Flex, DM, Smart Stb &MWD 07:45 08:30 0.75 90 90 PROD1 DRILL SRVY T Up Load MWD 08:30 09:15 0.75 90 360 PROD1 DRILL PULD T Con't MU BHA#5 - PU FS, Stab, 1 std NMFDCs, 2 stds HWDP w/jars - Break in GeoPilot bearings -Shallow test MWD 80SPM = 1200 psi -good ulse. 09:15 12:00 2.75 360 7,403 PROD1 DRILL TRIP T TIH on elevators f/ 360' to 7,403' MD , U wt 110k, Dn wt 70k 12:00 13:30 1.50 7,403 9,020 PROD1 DRILL TRLP T TIH on elevators f / 7,403' to 9,020' Floor crew doing visual check on WWT SS and Lo Tads on trip in) observed no problems. @ 9020' encountered tight hole, No SO wt. ~® m _~ ____ ~a~~ ~ ct ~~ -Time Lis _ Date From To Dur _ _ 5._ ?epth E_ __~th Phase Code_ Subcode T QOM _ 06/07/2006 13:30 17:00 3.50 9,020 10,558 PROD1 DRILL REAM T Wash & Ream f/ 9020' to 10,558' MD . PR 300 gpm, 50 RPMs, Torq on bttm 7-8k, PP 2700 si, 17:00 17:15 0.25 10,558 10,558 PROD1 DRILL SRVY T Orient and Set Tool deflection 17:15 00:00 6.75 10,558 11,168 PROD1 DRILL DDRL P Drlg f/ 10,558' to 11,168' MD / 3660' TVD, PR 310 gpm, RPMs 120, PP 3000 psi, WOB 7-9k, Stage up ROP timed out to clean hole from 100 - 125 fph PU wt 160 k/, SO wt 0 k, Rot wt 84 k Torq on bttm 6 k, off bttm 7 k Max gas 80 units, ECDs 10.92ppg Total jar hrs 107.34 @ Midnight - 99 WWT SS & 50 Lo Tads in hole. 06/08/2006 00:00 08:00 8.00 11,168 11,915 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ Geo Pilot f/ 11,168' - 11,915' MD / 3667' TVD, ADT 5..93 hrs, PR 310 gpm, PP 3100, RPMs 130, WOB 5-14 k, *"" Geologist reported they had deflected out of zone*"'` 08:00 09:00 1.00 11,915 11,267 PROD1 DRILL REAM T BROOH for Side Track t/ 11,267' MD , FR 300 m, RPMs 110, Tor 7 k 09:00 10:00 1.00 11,267 11,280 PROD1 DRILL KOST T Set Up for side track, Trench f/ 11,267' to 11,280' MD / 3656' TVD,. PP 2900 si, RPMs, Tor 7 k 10:00 12:00 2.00 11,280 11,284 PROD1 DRILL KOST T Time drlg for sidetrack. f/ 11,280' to 11,284' MD ADT 1.37 hrs # of T&D tools in hole, 99 WWT SS and 50 4" Lo Tads @11,915'MDPUwt154k,SOwtOk, Rot wt 85k, Tor on bttm 7 k, off bttm 8.5 k 12:00 14:30 2.50 11,284 11,304 PROD1 DRILL KOST T Con't Time drlg f/ 11,284' to 11,304' "*" Departure Point 11, 285' MD / 3656.69' TVD 14:30 16:00 1.50 11,304 11,358 PROD1 DRILL DDRL T Drlg 6 3/4" hole w/Geo Pilot f/ 11,304' MD to 11,358' MD. Pump 35 Bbl wt/hi-vis sweep while drilling ahead @ 11,358' MD. 250 gpm, 2750 psi, 120 rpm, and 80-90 fph until sweep past MWD tool (1500 stks), then increase rate to 310 gpm, 3000 psi, 125-135 fph, 130 rpm ... sweep brought back 20% increase in cuttin s. 16:00 21:45 5.75 11,358 11,915 PROD1 DRILL DDRL T Drlg 6-3/4" hole w/ Geo-Pilot f/ 11,358' MD to 11915' MD. SPR @ 12,006' MD, 3673' TVD, MW = 8.7+, MP#1 @ 25 spm = 660 psi, @ 35 spm = 830 psi, MP#2 @ 25 spm = 660 psi, @ 35 s m = 830 si ~ F'~ae 1'i ~12'y Time Logs -- - -- - - - ', Date __ From To Dur 5. epth E Depth Phase_ _ Code Subcode T COM 06/08/2006 21:45 00:00 2.25 11,915 12,006 PROD1 DRILL DDRL P Drlg 6-3/4" hole w/ Geo-Pilot f/ 11,915' MD to 12,006' MD (3,673' TVD). ADT = 8.81, PU = 165, SO = 0, Rot wt = 84, TQ On = 8k, TQ Off = 9k, Max Gas = 110 units, ECD = 11.34, Jar Hrs = 123.45. #/Lo-TADs in Hole = 50, Su er-Sliders = 99 06/09/2006 00:00 05:00 5.00 12,006 12,479 PROD1 DRILL DDRL P Drlg 6 3/4" hole w/ GeoPliot f/ 12,006' to 12,479' MD / 3703' TVD,= "A" Lat TD - ADT 4.19 hrs PU wt 170k, SO wt 0 k, Rot wt 90k, Torq 8 k, MAx gas 69 units, ECDs 11.42 ppg, Jar Hrs 127.64 PR 310 gpm, PP 3200 psi, RPMs 120-130 05:00 06:15 1.25 12,479 12,479 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep on last stand down -Circu BU 06:15 06:30. 0.25 12,479 12,479 PROD1 DRILL OWFF P Record SPR -Observe Well- Static 06:30 .12:00 5.50 12,479 8,757 PROD1 DRILL TRIP P BROOH f/ 12,479' to 8757' MD. FR 310 gpm, RPMs .120. Pull slow and steady +/- 45 fpm. No problems encounted. 12:00 13:00 1.00 8,757 7,790 PROD1 DRILL TRIP P PJSM- Con't BROOH f/ 8757' to 7790' MD. PR 310 gpm, RPMs 120. Slowed to 100 RPMs at shoe. 13:00 14:00 1.00 7,790 7,790 PROD1 DRILL CIRC P Pump Wt/Hi Vis sweep -Circu and recip csg until clean, PR 310 gpm, RPMs 100, Recip 90'- 0% excess cuttin on BU 14:00 18:00 4.00 7,790 12,479 PROD1 DRILL TRIP P RIH- Fill DP every 2000' -Tight @ 10,720' -Break Circu and PD f/ 10,691' to 10,788'. Con't RIH to Bttm with no problems on elevators. Wash & Ream 12,372' to 12,479' - PU wt 170k, SO wt 45k, Rot wt 85k 18:00 20:00 2.00 12,479 12,479 PROD1 DRILL CIRC P Pump sweep -Circu & Condition hole PR 310 gpm, RPMs 120, Recip DP 90' - Circu until clean at shakers. 20:00 21:00 1.00 12,479 12,479 PROD1 DRILL CIRC P . Change out to SFOBM -Displace to SFOBM from 12,479' to 6600' (200' above B lat window) -Last 20 bbls dis lacement is d 'ob. 21:00 00:00 3.00 12,479 8,885 PROD1 DRILL TRIP P POOH - SLM - Ck and Servive WWT SS. Sliders were moved do one space for wear protection to pipe. Had to re lace 1 element sleeve. 06/10/2006 00:00 01:30 1.50 9,144 7,887 PROD1 DRILL TRIP P Con't TOH f/ 9144' MD to 7887' MD - WWT SS were inspected and move down 1 position to minimize pipe ex osure to wear. 01:30 01:45 0.25 7,887 7,887 PROD1 DRILL SFTY P Observe well at 7-5/8" csg shoe - STATIC __ - -- - -- - - _ - - - --- Time Logs __ -- - - -- - - __ _- -- , Date From To Dur 5. epth E Depth Phase Code Subcode T (OM 06/10/2006 01:45 04:15 2.50 7,887 6,243 PROD1 DRILL. TRIP P Con't TOH f/ 7887 to 6243' MD WWT SS were inspected and moved down 1 position to minimize pipe exposure to wear. -Replaced 1 bad sleeve due to wear. -inspected total 90 WWT SS - All Lo Tads appeared to be in good shape -minimal wear. 50 total in strin . 04:15 06:15 2.00 6,243 360 PROD1 DRILL TRIP P Con't TOH f/ 6243' to 360' 06:15 06:45 0.50 360 360 PROD1 DRILL TRIP P BHA #5 -Stand back 2 std HWDP w/ 'ars and 1 std of NMFDCs 06:45 07:30 0.75 360 90 PROD1 DRILL SRVY P Down Load MWD -'"` Note"" Due to comm problem tool had to be laid down before data could be down loaded. After tool was LD in the shed the data was exstracted "OK" 07:30 08:15 0.75 90 0 PROD1 DRILL PULD P Con't LD BHA #5 - LD stab,NM Flt sub, TM HOC, PWD, SP 4 w/ Gm & Rec, Smart stab, DM HOC, NM sht DC, Geo- ilot 5200 Sr# 4 & bit 08:15 08:30 0.25 0 0 PROD1 DRILL PULD P Clear all tools from rig floor -Clean rig floor 08:30 09:15 0.75 0 0 PROD1 RIGMN SVRG P PJSM -Slip & Cut drill line (85.5' cut) 09:15 10:15 1.00 0 0 COMPZ CASIN( RURD P PJSM - RU to run 4.5" slotted liner 10:15 12:00 1.75 0 756 COMPZ CASIN( RUNL P Run 4.5" slotted liner in "A" lat per detail -Run 18 ~ts. 12:00 14:30 2.50 756 5,550 COMPZ CASIN( RUNL P PJSM - Con't Run 4.5" slotted liner in "A" lat. per detail. Total jts ran 127, 68 jts slotted and 59 jts blank + 1 blank shoe 'oint. 14:30 16:00 1.50 5,550 5,590 COMPZ CASIN( PUTB P PU Liner HangerAssy - 7.625' X 5.5" HRD ZXP LTP, RS packoff seal nipple, Flex Lock LH, 190-47 CSB Ext, XO bushing w/ 3.93" ID -See running detail for full data -Install PAL mix - RD Csg Tools & clear off all un-needed equip from rig floor. Up wt 77k, SO 60k, Rot wt 67k, Torq 2k 16:00 17:30 1.50 5,590 7,871 COMPZ CASIN( RUNL P TIH w/ Liner on DP to shoe -Fill DP @ 7871' - Up wt 100k, SO wt 65k, Rot wt 78k, Tor 3k 17:30 22:00 4.50 7,871 12,470 COMPZ CASIN( RUNL P TIH f/ 7871' to 12,470' -Had to rotate thru several spots, @ 10,045', 10,330', 10,830' 11,080', 11,180', 11,595', 11,614'. 50 RPMs, Max torq seen 8 k. @ 12,470 = UP wt 180k, SO wt 70k - Brk circu. 22:00 22:30 0.50 12,470 12,470 COMPZ CASINC CIRC P Drop & Circu setting ball to seat. - PR 3 bpm, 550 psi, Slow to 2 bpm for last 500 stks. Ball on seat Time Logs --- --__ _ - - _ - Dat~ From To Dur 5. epth E De th Phase Code Subcode T CAM 06/10/2006 22:30 00:00 1.50 12,470 12,470 COMPZ CASIN( RUNL P Ball on seat -Pressure up to 1800 psi, Set liner hanger, apply do wt 20k, Increase pressure to 3000 psi to set packer, Pressure test packer do back side to 1000 psi on chart and hold for 10 min. "OK" Pick up and expose dog sub. Apply do wt w/dog sub to confirm liner set. "OK" Top of Liner @ 6931' M D, 06/11/2006 00:00 02:00 2.00 6,990 0 COMPZ CASIN( RUNL P TOH f/ 6990' with liner setting tool - Hole fill Calcu 55 bbls, Actual 61 bbls - Settin tool all com lete. Worked well 02:00 02:45 0.75 0 0 COMPZ CASIN( RUNL P Service Brk &UD Baker Liner running tool 02:45 03:15 0.50 0 0 COMPZ RIGMN SVRG P Service Rig and Top Drive 03:15 03:45 0.50 0 0 COMPZ CASIN( RURD P Clear all tools from rig floor and clean u work area. 03:45 05:30 1.75 0 0 COMPZ EVALVt~ RURD P RU Schlumberger wire line to run CBL on 7.625" interm. 05:30 06:30 1.00 0 0 COMPZ EVALV~ RURD P PU wireline tools from unit to rig floor. RU sheave 06:30 07:30 1.00 0 0 COMPZ EVALVI~ PULD T Trouble shoot wireline tractor. 07:30 12:00 4.50 0 0 COMPZ EVALV~ ELOG P Start in hole with USIT CBL logging tools. Ran to 5940' (76.4*) without tractor. Tractor in f/ 5940' to 6915' MD- Lo u 1400 ft/hr noon 4400' 12:00 13:30 1.50 0 0 COMPZ EVALVI~ ELOG P Con't logging up from 4400' to 2950'. Cmt appears good up to 3700'-. And diminishes from there to 3050' MD. 13:30 14:30 1.00 0 0 COMPZ EVALVI~ PULD P LD wireline tools - RD Logging unit and tools 14:30 16:30 2.00 0 0 PROD2 DRILL PULD P PJSM - PU Mill and Whipstock assy. Usin 35k shear bolt. 16:30 17:00 0.50 0 0 PROD2 DRILL SRVY P PU Super Slim MWD and orient to WS. PU Bum er sub 17:00 18:00 1.00 0 0 PROD2 DRILL SRVY P Up Load program MWD 18:00 18:30 0.50 0 210 PROD2 DRILL TRIP P TIH w/ 2 stds Hybrid push pipe & shallow pulse test @ 393' MD, 6 bpm, 850 si "OK" 18:30 19:00 0.50 210 1,651 PROD2 DRILL TRIP P Con't TIH with whipstock assy to 1651' 19:00 19:30 0.50 1,651 1,651 PROD2 DRILL PULD NP CO 2 joints of 4" DP with galled threads 19:30 21:30 2.00 1,651 5,430 PROD2 DRILL TRIP P Con't TIH 5430' (fill pipe @ 3394' & break circu 5430' 21:30 22:15 0.75 5,430 5,520 PROD2 DRILL SRVY P MADD pass f! 5430' to 5520' for tie in of K-13 logs assuring proper depth. Orient TF to 10-15*L) during this rocess 22:15 23:00 0.75 5,520 6,894 PROD2 DRILL TRIP P Con't TIH to 6863' PU single to space Kelly to mill window. Up wt 144k, SO wt 87k - ~---..~._.. ~_ ~. ~.e ® m-- --- ~_vv ~~c,;~ 9~ ~f ~7 ~ I-- ----~ __ - _ - - - Time Loc s - - - - Date From _ To Dur _ __ b ~~pth E DEpth_Phase __Cod~ Subcode T COf~1 _ 06/11/2006 23:00 00:00 1.00 6,894 6,931 PROD2 DRILL MILL P Orient & Set Whipstock @ 7* Left - Good indication of positive shear. No Go tagged up on depth. @6931' MD After shear window starter mill @ 6826' TOW 06/12/2006 00:00 10:00 10.00 6,826 6,855 PROD2 DRILL MILL P Mill window for "B" sand lat. TOW 6828' MD, Bttm OW 6842'. Full guage 6 3/4" hole to 6855'. UP wt 135k, DN wt 86k, Rot wt 100k, Tor 5-5.5k 10:00 10:15 0.25 6,855 6,855 PROD2 DRILL MILL P Work Mill thru window 3 times - No roblems or for noted. 10:15 11:15 1.00 6,855 6,855 PROD2 DRILL CIRC P Pump Wt/ Hi Vis sweep to recover and clean out metal cuttings - 250 gpm, 1900 psi, 50 rpms. Noted very good recove ma nets. 11:15 12:00 0.75 6,855 6,855 PROD2 DRILL CIRC P Flow ck well -Pump dry job - Blow do to drive 12:00 12:15 0.25 6,855 6,855 PROD2 DRILL SFTY P PJSM -Discuss TOH and all expected hazards 12:15 14:30 2.25 6,855 6,855 PROD2 DRILL TRIP P TOOH w/Milling asst' - UD bumper sub 14:30 15:00 0.50 6,855 6,855 PROD2 DRILL SRVY P Dn Load MWD -Monitor well "Static" 15:00 16:00 1.00 6,855 6,855 PROD2 DRILL PULD P UD MWD & Milling asst'. Mills look good. Top mill ck "Full Guage" -Clear tools from ri floor 16:00 16:30 0.50 6,855 6,855 PROD2 WELCT BOPE P Set Test Plug -Fill BOPs and Choke Manifold w/water - MU floor valves and test manifold 16:30 17:30 1.00 6,855 6,855 PROD2 WELCT BOPE P Pull wear bushing & flush stack with cleanin tool - UD tool -Drain stack 17:30 21:30 4.00 6,855 6,855 PROD2 WELCT BOPE P Test BOPs and Choke Manifold -Test all components 250 psi Low and 3000 psi High. Make sure complete test is charted. All components tested good. See BOP test sheet for detail. Pull test plug. Install wear bushing - UD all testin tools and clear floor. 21:30 22:45 1.25 6,855 6,855 PROD2 DRILL PULD P PU BHA # 7 w/ Geo Pilot per Sperry. Sun detail w/ MDW.'""` Note'"'* We are running the new Baker/Hughes HCR - 5052 box u bit. 22:45 23:30 0.75 6,855 PROD2 DRILL SRVY P Program MWD -Monitor well (Static) 23:30 00:00 0.50 PROD2 DRILL TRIP P PU Flt sub - TIH w/ BHA #7 06/13/2006 00:00 00:15 0.25 PROD2 DRILL SFTY P PJSM for Trip in hole, Discussed Hazzards & Communication with all hands. 00:15 00:45 0.50 PROD2 DRILL DHEQ P Break in Geo Pilot bearings, Surface test MWD &Geo Pilot "Geo Pilot Failed". 00:45 02:30 1.75 60 PROD2 DRILL PULD T POOH, Down load MWD, Break bit, Lay down Geo Pilot, Pick up new Geo Pilot, Make u bit, U load MWD. i. 'd~ ~1~-.~?`.~i ~ ~ ~ ti~ Togs ..Date From To Dur STe ,th _E Depth Phase Code Subcode T_ COM 06/13/2006 02:30 03:00 0.50 60 453 PROD2 DRILL DHEQ T RIH to 453', Break in Geo Pilot bearings, Shallow test MWD tools - OK 03:00 05:00 2.00 453 6,736 PROD2 DRILL TRIP P RIH f/ 453' to 6,736' (Filled pipe @ 2695', 5028' 05:00 05:15 0.25 6,736 6,864 PROD2 DRILL REAM P Run thru window @ 6,828', Ream down to 6,864' w/ 264 gpm @ 1900 si, 60 RPM, TO 6K. 05:15 05:30 0.25 6,864 6,864 PROD2 DRILL SFTY P PJSM on Drilling and Making connections. 05:30 12:00 6.50 6,864 7,217 PROD2 DRILL DDRL P Drill f/ 6,864' to 7,217' MD 3,505' TVD (353'), ADT= 4.82 hrs, WOB 8/12K, RPM 120, Up 125K, Dn 60K, Rot 84K, Tq 6K on / 6K Off, Max gas 48 units, ECD's 10.2 ppg, Concretions 6916', 6923', 6941', 6944'. 12:00 12:15 0.25 7,217 7,217 PROD2 DRILL SFTY P Held PJSM with crew on Making connections and Pinch oints 12:15 00:00 11.75 7,217 8,667 PROD2 DRILL DDRL P Drill f/ 7,217' to 8,667' MD 3,510' TVD (1,450'), ADT= 8.84 hrs, WOB 10/12K, RPM 120, Up 135K, Dn 60K, Rot 85K, Tq 6-7K on / 6K Off, Max gas 92 units, ECD's 10.9 ppg, Concretions 8068'-8081', 8083'-8089', 8206'-8215', 8628'-8634'. 06/14/2006 00:00 00:15 0.25 8,667 8,667 PROD2 DRILL SFTY P Held PJSM with crew on hazard reco nition of tasks. 00:15 09:00 8.75 8,667 9,440 PROD2 DRILL DDRL P Drill f/ 8,667' to 9,440' MD 3,515' TVD (773'), ADT= 10.31 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 54K, Rot 84K, Tq 7K on / 8K Off, Max gas 125 units, ECD's 10.9 09:00 09:30 0.50 9,440 9,440 PROD2 DRILL CIRC T Circ hole clean for trip due to ROP Dro and unable to build an le. 09:30 11:30 2.00 9,440 7,219 PROD2 DRILL TRIP T Monitor well, POOH on elevators f/ 9,440' to 7,219' -Began pulling 25K over. 11:30 12:00 0.50 7,219 7,122 PROD2 DRILL REAM T Back Ream out of hole f/ 7,219' to 7,122' w/ 313 gpm @ 2300 psi & 120 RPM. 12:00 12:15 0.25 7,122 7,122 PROD2 DRILL SFTY T PJSM with crew on back reaming out of hole and related hazards. 12:15 12:30 0.25 7,122 6,760 PROD2 DRILL REAM T Back Ream out of hole f/ 7,122' to 6,929' w/ 313 gpm @ 2300 psi & 120 RPM, Pull to 6,760' thru window @ 6,828'-OK, Pum d 'ob. 12:30 14:30 2.00 6,760 30 PROD2 DRILL TRIP T POOH, Stand back BHA, Break Bit, Monitor well- OK. Note; Found Bit to have rin ed out in nose row. 14:30 15:00 0.50 30 30 PROD2 DRILL TRIP T Down load MWD tools. 15:00 15:30 0.50 30 30 PROD2 DRILL PULD T Change out GeoPilot & Make up Bit #5. 15:30 16:30 1.00 30 30 PROD2 DRILL TRIP T Program MWD tools, Change out float. j"~t - a t~ >s ,?7 . Time Logs ', Date __ _ From To Dur S_e th E. Depth Phase Code Subc_od_e T 'OM __ 06/14/2006 16:30 17:00 0.50 30 539 PROD2 DRILL TRIP T RIH w/ BHA to 539', Break in GeoPilot bearin s & Shallow test Tools- OK. 17:00 22:30 5.50 539 9,440 PROD2 DRILL TRIP T RIH to 6,960' (Filled pipe @ 3161' & 6736'), RIH to 9,440' - Wash & Reamed bridges @ 6960' to 7015', 7460' to 7510', 7606' to 7992', 8186' to 8282', 8863' to 9440'- Reamed w/ 300 m & 120 RPM. 22:30 00:00 1.50 9,440 9,590 PROD2 DRILL DDRL P Drill f/ 9,440' to 9,590' MD 3,505' TVD (150'), ADT= 1.00 hrs, WOB 8/12K, RPM 130, 310 gpm @ 2950 psi, Up 140K, Dn 54K, Rot 82K, Tq 6K on / 6K Off, Max gas 51 units, ECD's 11.1 06/15/2006 00:00 00:15 0.25 9,590 9,590 PROD2 DRILL SFTY P PJSM, Discussed hazard assessment of tasks. 00:15 12:00 11.75 9,590 10,315 PROD2 DRILL DDRL P Drill f/ 9,590' to 10,315' MD 3,501' TVD (725'), ADT= 9.21 hrs, WOB 10/15K, RPM 120, 313 gpm @ 2800 psi, Up 135K, Dn 50K, Rot 80K, Tq 7K on / 6K Off, Max gas 88 units, ECD's 10.75 ppg, Concretions= 9888'-9902', 9986'-10000', 10008'-10021', 10043'-10050', 10055'-10063', 10066'-10070', 10082'-10092', 10288'-10300', 10311'-10315'. 12:00 12:15 0.25 10,315 10,315 PROD2 DRILL SFTY P PJSM for Drlg ahead/Hazard reco nition 12:15 00:00 11.75 10,315 11,462 PROD2 DRILL DDRL P Drill f/ 10,315" to 11,462' MD 3,514' TVD (1,147'), ADT= 8.47 hrs, WOB 8/14K, RPM 130, 310 gpm @ 3,000 psi, Up 145K, Dn 40K, Rot 85K, Tq 7.5K on / 7K Off, Max gas 151 units, ECD's 11.42 ppg, Concretions= 10,450' - 10,455 - 10,898' - 10,902' - 10,908' - 10,910' - 10,915' - 10,918' - 10,929' - 10,934' - 11,060' - 11,066' - 11,196' - 11,205'. Total concretion foota e = 34' 06/16/2006 00:00 12:00 12.00 11,462 12,602 PROD2 DRILL DDRL P Drill 6-3/4" hole from 11,462' - 12,602' MD (3,552' tvd). ADT = 8.82 hrs. Pump 30 bbl hi-vis sweep at 12,561'. Concretions at 11,593 - 595', 11,870 - 872', 11,954-956', 12,030-038',12,193-207'. Total daily foota a of concretion drl = 28'. 12:00 12:15 0.25 12,602 12,602 PROD2 DRILL SFTY P PJSM for BROOH. 12:15 13:00 0.75 12,602 12,602 PROD2 DRILL CIRC P Circ sweep out at 310 GPM and 125 rpm, while reciprocating, with 5 excess cuttings. Survey. Monitor well - static. 13:00 20:30 7.50 12,602 6,736 PROD2 DRILL REAM P BROOH from 12,602' - 7,026'. POOH to inside of 7-5/8" csg to 6,736'. Monitor well -static. , tee _ ~ ~s ~~ ~~ ~.~__~ e.__ ~ F`2;,~ ~i ~::f~7 - - - -- - ___ -- Time Logs Date From To Dur e th E De th Phase Code_Subcode T ~OM - - ---- 06/16/2006 20:30 22:45 2.25 6,736 6,639 PROD2 DRILL CIRC P Pump 35 bbl Hi-Vis sweep. CBU 3x at 310 GPM and 80 rpm, while reci rcatin i e from 6,736-6,639'. 22:45 00:00 1.25 6,736 6,639 PROD2 DRILL OTHR P Cut and slip 70' of drill line. 06/17/2006 00:00 01:15 1.25 6,639 6,639 PROD2 DRILL OTHR P Change out Top Drive Saver sub. 01:15 03:00 1.75 6,639 9,733 PROD2 DRILL TRIP P RIH to 9,733' until ran out of down wei ht. 03:00 06:45 3.75 9,733 12,602 PROD2 DRILL REAM P Rotate at 90 rpm and wash in hole to 12,602' with 300 GPM, 2,700 psi and 7K ft-Ib of for ue. 06:45 08:30 1.75 12,602 12,602 PROD2 DRILL CIRC P Rack back stand in derrick and PU single jt from shed. Pump 30 bbl weighted Hi-Vis sweep at 12,591' with 130 rpm, 300 GPM, 3,200 psi, and 8,000 ft-Ib TO. Increase in returns of 15%. 08:30 09:15 0.75 12,602 12,602 PROD2 DRILL CIRC P Displace B-Lateral hole to 8.7 ppg, 60/40 SFMOBM with 281 bbl, while rotating at 130 rpm, with 300 GPM and 7,500 ft-Ib of TQ. 09:15 12:00 2.75 12,602 8,379 PROD2 DRILL TRIP P Monitor well -static. Pump dry job. LD single. PU=165K, S0=0. POOH to 8,379' with hole takin ro er fill. 12:00 12:15 0.25 8,379 8,379 PROD2 DRILL SFTY P PJSM for POOH and LD BHA 12:15 14:30 2.25 8,379 359 PROD2 DRILL TRIP P Continue to POOH to HWDP at 359' (15K overpull at 6,830'). Monitor well - static. 14:30 15:00 0.50 359 0 PROD2 DRILL PULD P Flush MWD tools with 15 bbl of new LVT base mineral oil and stand back in derrick. 15:00 16:00 1.00 0 0 PROD2 DRILL PULD P Download MWD. 16:00 16:30 0.50 0 0 PROD2 DRILL PULD P Break bit, LD Geo-Pilot and MWD. Clear ri floor. 16:30 17:30 1.00 0 0 COMPZ DRILL PULD P PU/MU whipstock retrieving assembly. 17:30 20:00 2.50 0 6,791 COMPZ DRILL TRIP P RIH filling DP at 3,282'. Continue RIH to 6,791'. PU=130K, S0=70K. Break ci rc. 20:00 21:00 1.00 6,791 6,740 COMPZ DRILL OTHR P Wash and latch onto whipstock at 6,833'. Work and jar free. Maximum overpull = 85K (PU=215K). Jar free with PU=195K, POOH one stand to 6,740' with PU=140K. 21:00 22:00 1.00 6,740 6,740 COMPZ DRILL CIRC P Circ bottoms up with max gas = 41 units. Monitor well -static. Pum slu . 22:00 00:00 2.00 6,740 2,280 COMPZ DRILL TRIP P POOH 06/18/2006 00:00 01.:00 1.00 2,280 60 COMPZ DRILL TRIP P Continue POOH 60' with whipstock. 01:00 03:00 .2.00 60 0 COMPZ DRILL PULD P LD BHA, whipstock and trip anchor, with No-Go seal assembl . I ~ t t'-~lae~ ~~~ Gi ~~ _.__,.,_, ,_„_,,,-_r,_ -- . ...,..-..-...._... ,_- ~,.~__ - -_ --- Time Logs _ Date From To Dur 5. epth E De tp h Phase Code Subcod~ T ~OM ~ 06/18!2006 03:00 03:30 0.50 0 0 COMPZ CASIN( RURD P Clear and clean rig floor. RU casing e ui . 03:30 03:45 0.25 0 0 COMPZ CASIN ( SFTY P PJSM for running 4-1/2" liner. 03:45 06:45 3.00 0 5,726 COMPZ CASIN( RNCS P RIH with 132 joints R3, 4-1/2", 11.6 lb/ft, L-80, BTC Blank/Slotted liner, with Hydroform centralizers on stop collars in the center of each joint. Tor ue rin s run in 'oints 55-132. 06:45 08:45 2.00 5,726 5,727 COMPZ CASIN( OTHR P MU liner swivel assembly, slimhole MWD, hook hanger and orient. PU = 75K, SO = 60K. 08:45 12:00 3.25 5,726 11,304 COMPZ CASIN( RUNL P RIH to 193' and shallow test MWD - good test. Continue RIH with liner and tag up on A-lateral at 6,976'. PU, orientate and pass through window on second attempt. RIH to 11,304'. PU=125K, S0=65K. 12:00 12:15 0.25 11,304 11,304 COMPZ CASIN( SFTY P PJSM for running liner. 12:15 13:00 0.75 11,304 12 COMPZ CASIN( RUNL P ContinueRlHw/liner to 12,465' (PU=160K, S0=40K). Broke circulation with 130 GPM at 1,200 si. 13:00 14:30 1.50 12,465 12,550 COMPZ CASIN( RUNL P Work liner to 12,560' with Hook 8' past window at 6,834'. PU, orient hook and work torque out of string. Set hook with all appearances of proper hook. PU with 35K in string weight loss. Shoe set at 12,550' and and TOL at 6,823' md. Monitor well -static. 14:30 17:30 3.00 12,550 0 COMPZ CASIN( RUNL P POOH with wet string. 17:30 18:30 1.00 0 0 COMPZ CASIN( OTHR P Pull and inspect liner running tool - okay. Clean rig floor. PU small handlin tools. 18:30 19:30 1.00 0 0 COMPZ CASIN( RURD P LD running tool and MWD. LD handling tools. 19:30 20:00 0.50 0 30 COMPZ CASIN( PUTB T PU casing tools and seal assembly for Hook hanger verification run. RD casin tools. 20:00 23:30 3.50 30 6,748 COMPZ CASIN( OTHR T RIH with seal assembly to 6,748' (PU= 130K, S0= 75K . 23:30 00:00 0.50 6,748 6,823 COMPZ CASIN( OTHR T Tag top of liner at 6,822.77'. 06/19/2006 00:00 01:00 1.00 6,823 6,930 COMPZ CASIN( OTHR T Tag top of liner at 6,822.77', Made 7 attempts to get inside TOL- No Good, Rotate at 10 RPM to get inside liner- . OK, RIH & Tag top of Hook Hanger @ 6,823' -OK w/Tail of seals 6,930'. 01:00 03:30 2.50 6,930 114 COMPZ CASIN( OTHR T POOH, pump dry job, continue POOH. 03:30 04:30 1.00 114 0 COMPZ CASIN( OTHR T LD BHA for hanger verification run. 04:30 06:30 2.00 0 743 COMPZ CASIN( PUTB P RU casing equipment, MU DB nipple, PU/MU LEM/ZXP assembl . 06:30 07:00 0.50 743 743 COMPZ CASIN( RURD P RD casing equipment. ~ tt L d _ ____ ~ a ~~ _~ ~.a ~~~ i ~ ~f ~~.. ~.._._.. ,.__ ,_ _..._.__ -,__ _,_~ ~ _____ Time Logs - - --- - -_ - - _- --- I D~te __ From To Dur___ S: epth E- Depth Phase Code Subcode T - ~OM_ - -- - - 06/19/2006 07:00 10:00 3.00 743 6,973 COMPZ CASIN( RUNL P RIH and Stab into A-lateral seal bore recepticle to 6,973'. Top of liner at 6,491' All measurements on depth Up 127K, Dn 80K, Observed LEM latch into position {Set 30K down on LEM), Pull test LEM to 10K over- OK, Reset 30K down on LEM. 10:00 11:00 1.00 6,973 6,973 COMPZ CASIN( RNCS P Drop ball and pump down at 127 GPM, 600 psi. Ball went on seat at 520 strokes. Pump and stage up to 4,000 si. Set acker. 11:00 11:15 0.25 6,973 6,973 COMPZ CASIN( OTHR P Pressure test ZXP to 1,000 psi for 5 minutes. 11:15 12:00 0.75 6,973 6,500 COMPZ CASIN( CIRC P CBU at 6,500' at 254 GPM and 1,500 si max as = 28 units . 12:00 12:15 0.25 6,500 6,500 COMPZ CASIN( SFTY P PJSM on POOH. Monitor well -static. 12:15 14:30 2.25 6,500 100 COMPZ CASIN( OTHR P POOH with running tools. 14:30 15:00 0.50 100 0 COMPZ CASIN( OTHR P LD running tools, clear rig floor. Monitor well -static. 15:00 15:30 0.50 0 0 PROD3 STK PULD P PU mills and whipstock. 15:30 17:00 1.50 0 150 PROD3 STK PULD P MU mills and whipstock assembly pinned with 35K shear bolt. PU/MU MWD and bum er sub. Orient MWD. 17:00 18:00 1.00 150 150 PROD3 STK OTHR P Upload MWD. 18:00 18:30 0.50 150 457 PROD3 STK TRIP P RIH to 457' and shallow pulse test MWD at 280 GPM and 900 si. 18:30 20:45 2.25 457 5,663 PROD3 STK TRIP P RIH w/ whipstock. Fill DP at 3,358'. Break circ at 5,663' 20:45 21:30 0.75 5,663 5,671 PROD3 STK OTHR P MAD pass across K-13 from 5,581'-5,671' md, and orient to 14 deg left. 21:30 21:45 0.25 5,671 6,437 PROD3 STK TRIP P RIH to 6,437'. PU 120K, S0= 78K. Break circulation. 21:45 22:30 0.75 6,437 6,410 PROD3 STK WPST P Orient whipstock to 20L, shear with 40K and set to at 6,409.5' tmd . 22:30 00:00 1.50 6,410 6,412 PROD3 STK .MILL P Mill window 6,409.5 - 6,412' at 100 RPM, 235 GPM and torge = 4-6,000 ft-Ib. 06/20/2006 00:00 06:30 6.50 6,412 6,452 PROD3 STK MILL P Continue milling window from 6,412'-6,422' with 230 GPM, 1,650 psi and torque = 3-5,000 ft-Ib. Drill to 6,452' with 6-3/4" guaged hole to 6,442'. Work mills through window and dress off same. 06:30 09:00 2.50 .. 6,452 92 PROD3 STK TRIP P Monitor well -static. POOH to 92'. 09:00 09:15 0.25 92 92 PROD3 STK PULD P LD BHA, XO and bumper sub 09:15 10:00 0.75 92 92 PROD3 STK OTHR P Download MWD. 10:00 10:30 0.50 92 0 PROD3 STK PULD P Continue LD BHA, MWD, Mills. Upper f ull ua e 6-3/4" mill in ua e. _ ~ ~ ~ ~_W _-__. s? ~:~~ ~~1 ~~t Ef~~ ~____-~~~~___ _V_ _ ~__.____ e Logs ~ Date From To_ __ _Dur epth E. Depth Phase_ (ode Subcode T_ C)I~t _ _ _ ~ 06/20/2006 10:30 11:00 0.50 0 0 PRODS STK OTHR P Clean and clear rig floor. 11:00 12:00 1.00 0 0 PRODS DRILL PULD P PU/MU Rotary steerable toots, collar and LD to ether. Flush stack. 12:00 13:00 1.00 0 0 PRODS DRILL SFTY P PJSM. Continue flushing stack. 13:00 13:45 0.75. 0 0 PRODS DRILL OTHR P Pull WB, flush stack, set WB and LD tools. 13:45 14:15 0.50 0 56 PRODS DRILL TRIP P RIH w/ bit and Rotary steerable tools, flex collar. PU MWD. 14:15 15:15 1.00 56 88 PRODS DRILL OTHR P Upload MWD. Monitor well -static. 15:15 15:45 0.50 88 356 PRODS DRILL TRIP P RIH w/ BHA, break in bearings and shallow ulse test MWD. 15:45 17:30 1.75 356 6,325 PRODS DRILL TRIP P RIH filling DP at 3,159' and 6,325' 17:30 18:15 0.75 6,325 6,325 PRODS DRILL SFTY P PJSM. Cut and Slip 72' of drill line. 18:15 18:45 0.50 6,325 6,452 PRODS DRILL TRIP P RIH, pass thru window smoothly. Break circ at 6,429'. Ream from 6,429' - 6,452' with 90 rpm, 282 GPM, 2,000 si and 1-2,000 ft-Ib of for ue. 18:45 00:00 5.25 6,452 7,003 PRODS DRILL DDRL P Drill ahead from 6,452' 7,003' tmd (3,439' tvd). ADT = 3.75 hr. PU = 120K, S0= 60K ROT= 81 K, TQ on/off = 6K/5-6K. ECDs = 10.2 ppg, Max Gas = 63 units. Concretions @ 6,565-6,572', 6,597 - 6,601', 6,754 - 6,759'. Total = 16'. 06/21/2006 00:00 12:00 12.00 7,003 8,020 PRODS DRILL DDRL P Continue drilling 7,003 - 8,020' and (3,430' tvd). PU=130K, S0= 57K, ROT= 80K, TQ on/off = 6,000!7,000 ft-Ib, Press= 2,500 psi, ECD= 10.43 ppg, Max Gas = 109 units Concretions: 7,019-28', 7,037-39', 7,049-54', 7,130-136', 7,140-145', 7,159-167', 7,182-190', 7,214-216', 7,218-220', 7,242-255', 7,258-271', 7,308-320', 7,323-346', 7,405-410', 7514-51 T, 7,528-534', 7,598-602'. Total= 120'. 12:00 00:00 12.00 7,003 9,227 PRODS DRILL DDRL P Continue drilling 8,020 - 9,227' and (3,432' tvd). PU=145K, SO= 57K, ROT= 85K, TQ on/off = 6,500 ft-Ib, Press= 2,650 psi, ECD= 11.06 ppg, Max Gas = 92 units Concretions: 8,202-205', 8,258-280', 8,297-312', 8,405-420', 9,085-096', 9,122-129', 9,141-145' Total=81' 06/22/2006 00:00 12:00 12.00 9,227 10,427 PRODS DRILL DDRL P Drill 6-3/4" D-lateral from 9,227-10.,427' tmd (3,429' tvd) PU= 145K, S0= OK, ROT= 80K, Torque on/off = 8,000/8,500 ft-Ib, Max Gas= 224 units, ECD= 11.2 ppg Concretions: 9,875-90', 9,943-48', 10,047-54', 10,210-214', 10,220-223'. Total: 34' _ -~-._-__.~ _~ ~~® .~~ - i ___e_ _____~ ~ --- - Time Logs l Date From To Dur S. ve th E Depth Ph~s~_ bode Subcode T_ C;OP~1 - -- -- - - - - - - 06/22/2006 12:00 00:00 12.00 10,427 11,314 PRODS DRILL DDRL P Drill ahead 6-3/4" D-lateral 10,427-11,314' tmd, (3,441' tvd) Concretions: 10,632-637', 10,870-72', 11,135-138', 11,150-163', 11,188-210', 11,218-232', 11,240-252', 11,266-279', 11,284-292', 11,298-314', Total= 108' 06/23/2006 00:00 12:00 12.00 11,314 12,050 PRODS DRILL DDRL P Drill 6-3/4" D-lateral 11,314-12,050' tmd (3,477' tvd). ART= 9.15 hr PU= 155K, S0= OK, ROT= 80K Torque On/Off = 9,000/9,000 ft-Ib Press= 3,050 psi, ECD= 11.45 ppg Max Gas= 132 units Concretions: 11,328-345', 11,348-357', 11,659-666', 11,681-693', 11,705-708', 11,775-778', 11,831-838', 11,847-850', 11,853-867', 11,902-913', 11,926-939' Total= 73' 12:00 18:30 6.50 12,050 12,678 PRODS DRILL DDRL P Drill 6-3/4" D-lateral 12,050-12,678' tmd (3,484' tvd). ART= 5.19 hr PU= 170K, S0= OK, ROT= 85K Torque On/Off = 9,000/10,000 ft-Ib Press= 3,300 psi, ECD= 11.80 ppg Max Gas= 70 units Concretions: Total= 0 18:30 19:15 0.75 12,678 12,678 PRODS DRILL CIRC P Circulate weighted Hi-Vis sweep at 310 GPM, 3,375 psi with a 20% increase in cuttings returns. Survey hole at TD. 19:15 19:30 0.25 12,678 12,647 PRODS DRILL OWFF P LD single joint, monitor well -static. 19:30 00:00 4.50 12,647 10,294 PRODS DRILL REAM P BROOH 12, 647-10,294' at 310 GPM, 3,150--3,000 psi, 100 RPM, and 40-45 ft/min. Average torque= 8,000 ft-Ib, PU=90K. Lost 9.7 bbl while BROOH. 06/24/2006 00:00 04:30 4.50 10,294 6,429 PRODS DRILL REAM P Continue BROOH 10,294 - 6,429' at drilling rate. Pull thru window w/o roblems. PU= 120K, S0= 35K 04:30 06:30 2.00 6,429 6,336 PRODS DRILL CIRC P Pull inside window to 6,336', pump 30 bbl weighted sweep plus 3 btms up at 300 GPM, 100 RPM, torque= 4-5,000 ft-Ib. 06:30 09:30 3.00 6,336 10,197 PRODS DRILL TRIP P RiH. Slide through window without problems. RIH to 8,940 washing thru tight spot to 9,000'. Continue RIH to 10,197' where slackoff wt = 0. 09:30 12:00 2.50 10,197 10,918 PRODS DRILL REAM P Wash and ream 10,197-918' at 305 GPM, 3,000 si and 100 RPM. 12:00 12:45 0.75 10,918 12,678 PRODS DRILL REAM P Continue wash and reaming to TD at 12,678' tmd, at 305 GPM, 3,100 psi, 100 r m amd 4,000 ft-Ib. 12:45 14:15 1.50 12,678 12,678 PRODS DRILL CIRC P Pump 35 bbl weighted Hi-Vis sweep at 275 - 310 GPM, 2,900-3,450 psi, 140 rpm with no increase in cuttings returns. 14:15 15:00 0.75 12,678 12,678 PRODS DRILL CIRC P Displace open hole with 298 bbl of 60/40, 8.7 ppg, SFMOBM. Chase with OBM and d 'ob. _ ~~ mw_~~-~-- -----._..._~~..~__ _~..~ ~ Tirne Logs --- Date From To Dur_ ~. ~~th E. De~th_ f'h~se bode Subco~ie T_ _ COM 06/24/2006 15:00 15:15 0.25 12,678 12,650 PROD3 DRILL PULD P LD single and flow check well -okay. 15:15 20:30 5.25 12,650 359 PROD3 DRILL TRIP P Drop rabbit and POOH on elevators. Inspect Lo-TADs and Super-Sliders. Calculated displacement 73.1. bbl, actual displacement 94.1 bbl. Pulled 30K over throu h ti ht s of at 9,005'. 20:30 21:30 1.00 359 60 PROD3 DRILL PULD P LD HWDP and collars in BHA. 21:30 00:00 2.50 60 60 PROD3 DRILL OTHR P Download MWD and LD same. Function tested Blind Rams. 06/25!2006 00:00 00:30 0.50 60 0 PROD3 DRILL PULD P Continue LD MWD and BHA. 00:30 01:00 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 01:00 01:45 0.75 0 0 COMPZ CASIN< RURD P RU 4-1/2" casing equip., hold PJSM 01:45 05:15 3.50 0 6,329 COMPZ CASIN( RUNL P RIH with 141 Jts of 4-1/2", 11.6 Ib/ft, L-80, BTC-M slotted /blank liner, with 6.125 x 4.5" Hydroform centralizers, free floatin . 05:15 06:00 0.75 6,329 6,359 COMPZ CASIN( -CIRC P PU/MU seal bore receptacle, HR liner runnin tool and XO. 06:00 06:.15 0.25 6,359 6,359 COMPZ CASIN( PUTB P RD casing tools. 06:15 09:45 3.50 6,359 12,489 COMPZ CASINC RUNL P RIH to 6,390'. Rotate liner at 25 RPM with 2,500 ft-Ib and 85K ROT wt. Continue RIH to 12,250' where SO wt went to zero. Floated casing to 12,489'. 09:45 10:15 0.50 12,489 12,685 COMPZ CASIN( RUNL P Rotate liner from 12,489 - 12,623', PU 2 joints from shed, tagging bottom at 12,685', PU 170K, S0= OK, ROT= 95K, TQ = 8-9,000 ft-Ib at 10 RPM. 10:15 11:00 0.75 12,685 12,685 COMPZ CASIN( RUNL P Set liner on depth, drop ball and pump down, seating at 645 strokes, slackoff with 50K, shear ball seat at 4,500 si. 11:00 11.:15 0.25. 12,685 6,371 COMPZ CASIN( OTHR P LD 2 joints of DP. 11:15 12:00 0.75 6,371 6,371 COMPZ CASINC CIRC P CBU at 6,371' with 305 GPM, and 1,950 si. 12:00 12:15 0.25 6,371 6,371 COMPZ CASINC OTHR P Pump dry job, monitor well -.static. 12:15 14:30 2.25 6,371 0 COMPZ CASIN( OTHR P POOH, LD running tool removed one bad Lo-TAD from stand #10. Calc displacement on POOH = 51.2 bbl vs. 52.4 bbl actual. 14:30 15:00 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. 15:00 16:00 1.00 0 0 COMPZ WELCT BOPS P Pull WB, rig up test joint and test equip, MU floor valves. Repair lockdown screw and gland nut in wellhead. e~ ~~ ~ ~ ~~ ~~~~ ~u ~fi ~? F Time Lois Date From To Dur - 5. ~~pth _- - _ E Depth - - Phase Code Sut~code T COM __ 06/25/2006 16:00 _ 19:00 _ 3.00 _ 0 _ 0 _ COMPZ WELCT BOPE P Test all valves in choke manifold, Annular preventer, top pipe rams, upper and lower IBOP valves, manual and HCR choke and kill valves, 4"floor and dart valves to 250 low and 3,000 psi high, holding 5 minutes for low and high each. Perform accumulator function test, before 3,000 psi, after closing 2,000 psi, 200 psi buildup in 44 sec, and full charge in 2 min, 46 sec. Five nitrogen bottles -average of 2,350 psi. Blow down choke manifold and lines line backu for drillin . 19:00 20:00 1.00 0 0 COMPZ WELCT BOPE P RD test equipment, install WB 20:00 20:30 0.50 0 330 COMPZ FISH PULD P PJSM, MU whipstock retrieval BHA. 20:30 00:00 3.50 330 6,414 COMPZ FISH TRIP P RIH to retrieve whipstock. Remove Lo-TAD from stand #10. Fill pipe every 20 stds, calculated fill 46.6 bbl, actual = 39.7 bbl. Circulate and wash over whipstock slot at 250 GPM, 1,240 psi, rotating at 20 RPM, TQ= 3-4,000 ft-Ib, ROT= 97K Note: GBR and Frank's Casing took measurements on the rig for a h draulic casin stabber. 06/26/2006 00:00 04:45 4.75 6,414 6,331 COMPZ FISH FISH P Continue to attempt to hook whipstock washing from 6,409 - 6,425'. Hook whipstock twice, pull to 190K, fired jars and pulled free. POOH to 6,331'. Weight before hooking = 135K, after= 125K. 04:45 05:45 1.00 6,331 6,331 COMPZ FISH CIRC P Circulate at 6,331' with 210 GPM and 1,250 si. Monitor well -static. 05:45 09:15 3.50 6,331 59 COMPZ FISH TRIP P POOH to 59'. 09:15 11:00 1:75 59 0 COMPZ FISH PULD P LD BHA XO, Jar, Bumper Jar, 1 JT 3-1/2" HWDP, hook, whipstock, trip anchor assembly w/ No-Go Seal assembl . 11:00 11:30 0.50 0 0 COMPZ FISH OTHR P Clear and clean rig floor. 11:30 12:00 0.50 0 0 COMPZ CASIN( CIRC P PU casing equipment and slim hole M WD. 12:00 12:30 0.50 0 0 COMPZ CASIN( RURD P RU to run hook hanger. PU / RU, power tongs, crummies and false rota tabe. 12:30 12:45 0.25 0 0 COMPZ CASIN( RURD P PJSM for PU Hook Hanger 12:45 14:45 2.00 0 31 COMPZ CASIN( PUTB P MU hook hanger assembly and MWD. U load MWD. 14:45 18:45 4.00 31 6,407 COMPZ CASIN( RUNL P Run hook hanger and No-Go on XO below seal bore at 6,530' in the B-Lat liner. POOH to above window, PU= 130K, S0= 79K. ~___.___ __ _ ~ e r__:_ ~ ~ 1 Time LocJs - -- __ - , Date From To L1ur S. ~ e th E Depth Phase Code Subcode T OM 06/26/2006 18:45 _ 20:30 _ 1.75 31 6,407 COMPZ CASIN ( RUNL P Orient to 2 deg right, pass thru window on second attempt, RIH and hook 58.75' in on stand with 30K of down weight. Hanger oriented itself to 1 deg left. PU, turn 180 deg, RIH 67' in on stand and tag XO below the 5-1 /2" receptacle joint (1,95' low). PU, turn hanger string, orienting to 19 degrees left. RIH 57.5' in on stand where hanger started taking weight and self oriented to 4 deg left. SO with 35K at 59' in on stand. Hook hanger set at 6407.44' tmd. Circulate and drop ball pumping down to ball seat. Pressure up to 2,800 psi and inflate ECP, continure pressure up to 4,500 psi and release from hanger and ECP. PU wt = 120K after, 130K before. 20:30 20:45 0.25 6,407 6,407 COMPZ CASIN( CIRC P Pump slug. Monitor well -static. 20:45 00:00 3.25 6,407 0 COMPZ CASIN( RUNL P POOH to slimhole MWD, download and LD. Displacement calculated = 52.3 bbl, Actual displacement = 50.8 bbl. 06/27/2006 00:00 00:45 0.75 15 0 COMPZ CASINC RUNL P UD Baker Hook Hanger running tools, UD Slim hole Sperry Sun MWD, UD inner wash strin . 00:45 01:15 0.50 0 0 COMPZ CASIN< RURD P Remove all tools from rig floor, Slim Hole MWD tools to i e shed 01:15 01:30 0.25 0 0 COMPZ CASIN( RURD P Clean and Power wash rig floor and rota area. 01:30 02:30 1.00 0 0 COMPZ RIGMN SVRG P PJSM -Slip and Cut drill line (79' cut) 02:30 03`00 0.50 0 0 COMPZ CASIN( RURD P PJSM - R/U Csg running tools 03:00 04:00 1.00 0 182 COMPZ CASIN< RNCS P M!U LEM assy per detail ,Bent Jt w/ seals, 1 jt 4.5" Tbg, 2 pup jts, LEM, Seal bore, ZXP 04:00 07:15 3.25 182 6,521 COMPZ CASIN( RNCS P TIH w/ LEM assy on DP to 6521' MD, Up wt 127k, Dn wt 77k, TOL @ 6353' MD 07:15 08:00 0.75 6,521 6,521 COMPZ CASIN( CIRC P Drop Ball & Pump down @ 3 BPM, 600 psi, 125 gpm, 36 spm, Ball on seat @ 25 stks, SO to 40k & pressure up to 3000 psi, set liner top packer, continue pressure up to 4000 psi and release from LEM. 08:00 09:00 1.00 6,521 6,420 COMPZ CASIN( RUNL P POOH T/6420' MD, CBU @ 72 spm, 250 gpm, 1550 psi, Up wt = 125k, Dn wt = 75k 09:00 12:00 3.00 6,420 1,145 COMPZ CASIN( RUNL P Monitor well, Pump Dry Job, POOH t/ 1145' cleaning OBM off off Super Sliders and Lo-TADs 12:00 12:15 0.25 1,145 0 COMPZ CASIN( RUNL P Continue POOH f/1145' to Surface 12:15 12:30 0.25 0 0 COMPZ CASIN( RURD P UD Running Tool __._ Time Logs _ _ _ Date From to Dur ti. epth E_ D~Qth_Phase Code Subcode T OfA 06/27/2006 12:30 13:00 0.50 0 0 COMPZ RPCOf~ RURD P Pull wear ring 13:00 14:00 1.00 0 0 COMPZ RPCOti RURD P Clear and Clean Rig Floor & RU to run 4.5" IBT Com letion Strin 14:00 14:15 0.25 0 0 COMPZ RPCOti SFTY P PJSM/ Hazard Assesment meeting w/ Co Rep, Toolpusher, Rig Crew & Casin Hand on runnin tubin 14:15 19:30 5.25 0 6,387 COMPZ RPCOh RCST P Run 204 jts Tubing and Jewlery, PU Wt = 82k, SO Wt = 59k 19:30 20:00 0.50 6,383 6,383 COMPZ RPCOh HOSO P Run In, Tag Up, Space out 4' from being fully inserted, come out, PU Space Out Pups & Landing Jt w/ Hanger. Mule shoe of completion @ 6382.65' -Seals 4' from fully inserted. U wt 82k, SO wt 59k 20:00 20:30 0.50 6,383 6,383 COMPZ RPCOh HOSO P Orient and Land Tubing on Hanger & RI-LDS 20:30 22:30 2.00 6,383 6,383 COMPZ RPCOti SFEQ P Sim-Ops, UD Landing Jt, Test Upper & Lower Hanger Body Seals to 5000 psi for 15 min, UD Casing tools, Clear & Clean Rig Floor, Remove Bell Nipple, Start Flushing Pits, Mud S stem, and Geo-S an w/ H2O 22:30 00:00 1.50 6,383 6,383 COMPZ RPCOh NUND P De-Energize, Drain BOPE stack & start Ni lin Down 06/28/2006 00:00 02:00 2.00 0 0 COMPZ RPCOh NUND P Nipple up tree, Test tubing bonnet and tree to 5000 si for 10 min. 02:00 02:30 0.50 0 0 COMPZ RPCOh NUND P Pull two-way check 02:30 07:00 4.50 0 0 COMPZ RPCOh PULD P PJSM - R/U mouse hole UD 4" DP from derrick 153 'ts 07:00 07:45 0.75 0 0 COMPZ RPCOh RURD P R/U Hot Oil 07:45 08:00 0.25 0 0 COMPZ RPCOh CIRC P PJSM w/ Rig crew and HOt Oil on dis lacin well with diesel. 08:00 10:00 2.00 0 0 COMPZ RPCOh FRZP P Pressure Test lines to 2000 psi, displace well with 310 BBLs diesel @ 4 BPM, 1250 psi, R/D Hot Oil. Freeze protect pumped thru sliding sleeve @ 6309` MD. Diesel in Tbg & Annulus to 6309' MD. 10:00 11:00 1.00 0 0 COMPZ RPCOh RURD P R/U Scaffolding and Lubricator 11:00 12:00 1.00 0 0 COMPZ RPCOti NUND P Set BVP, R/D Lubricator 12:00 12:30 0.50 0 0 COMPZ RPCOI~ NUND P UD Lubricator, install tree cap, PJSM & Hazard assesment on UD drily pipe using mousehole, also UD Lo-TADS, remove scaffoldin . 12:30 21:30 9.00 0 0 COMPZ RPCOti RURD P Some-Ops cleaning pits, R/W, Preparing for Rig Move, off Hi-Line power @ 14:00 hrs, UD 25 stands slick, 15 stands Hybrids, 50 stands DP w/ Lo-TADS €'~~~~ r a ~;3' ~~ a -_~ r ~ ~ _ _ --__ _ I Time Logs_ _ _ _ Date From To Dur e th E_Dee_th Phase Code Subcode T COM 06/28/2006 21:30 00:00 2.50 0 0 CC)MPZ RPC©ti RURD P Blow Down Rig, Break service lines, prepare to jack rig and move off well. ****Note**** Release Rig @ 2400 hrs Midniciht 6/28/2006 -Move to 1J-156 ~'~~~ ~7 r~r ~7 Halliburton Companyi Survey Report ' Company: ConocoPhillipsAlaska Inc. llate: 7/13/2006 Time: 09:54:28 Yage: I ! Field: Kuparuk River Unit C'o -ordinate(NE) Reference: Well: 1J-170, True North ! Site: Kuparuk 1J Pad Ve rtical (TVD) Re ference: 1J-170L2 : 109. 0 Well: 1J-170 Section (VS) Refer ence Well (O.OON,0:O OE,O.OOAzi) Wellpath: 1J-170L2 Su rveyCalculatio n h1ethod: Minimum Curva ture Db: Oracle Field: Kuparuk River Unit North Slope Alaska I United States Map System:US State Plane Coordin ate System 1927 Map Zone: Alaska, Zone 4 ', Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Well: 1J-170 Slot Name: I We11 Position: +N/-S -305.03 ft Northing: 5945614.10 ft Latitude: 70 15 43.258 N !, +E/-W -70.73 ft Easti ng : 558721.61 ft Longitude: 149 31 31.065 W Position Uncertainty: 0.00 ft Wellpath: 1J-170L2 Drilled From: 1J-170PB1 500292331061 Tie-on Depth: 6371.85 ft j Current Datum: 1 J-170L2 : Height 109.00 ft Above System Datum: Mean Sea Level ', Magnetic Data: 5/23/2006 Declination: 24.08 deg !, 'i Field Strength: 57565 nT Mag Dip Angl e: 80.77 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction !i ft ft ft deg 28.00 ! 0.00 0.00 0.00 I Survey Program for DeSnitive Wellpa th ~I '! Date: 7/13/2006 Validated: No V ersion: 1 j Actuat From To Survey Toolcode Tool Name '~ ft ft ! --- - - j 50.00 732.00 1J-170PB1 gyro (50 .00-732.00) C B-GYRO-SS Camera based gyro single shot !, 803.23 6371.85 1 J-170P61 (803.23-9246.96) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C !~ 6409.00 12642.41 1J-170L2 (6409.00-12642.41) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SC C Survey ', MD Incl Azim TVD Sys TVD N/S E/W I<IapN IV1apE Tool ft deg deg ft ft ft ft ft ft ' 28.00 0.00 0.00 28.00 -81.00 0.00 0.00 __ 5945614.10 558721.61 __ TIE LINE ! 50.00 0.25 25.67 50.00 -59.00 0.04 0.02 5945614.14 558721.63 CB-GYRO-SS i 100.00 0.25 22.52 100.00 -9.00 0.24 0.11 5945614.34 558721.72 CB-GYRO-SS !, 172.00 0.58 33.07 172.00 63.00 0.69 0.37 5945614.80 558721.97 CB-GYRO-SS !I 267.00 0.88 313.81 266.99 157.99 1.60 0.10 5945615.70 558721.70 CB-GYRO-SS ! 358.00 3.08 287.40 357.93 248.93 2.82 -2.73 5945616.89 558718.86 CB-GYRO-SS 450.00 5.60 270.56 449.67 340.67 3.60 -9.58 5945617.62 558712.00 CB-GYRO-SS ', 540.00 7.50 260.08 539.08 430.08 2.63 -19.76 5945616.58 558701.83 CB-GYRO-SS ! !I 632.00 9.14 250.71 630.11 521.11 -0.82 -32.57 5945613.03 558689.05 CB-GYRO-SS ~ 732.00 12.79 234.79 728.29 619.29 -9.83 -49.12 5945603.89 558672.57 CB-GYRO-SS ! 'I 803.23 14.79 229.29 797.47 688.47 -20.31 -62.46 5945593.31 558659.32 MWD+IFR-AK-CAZ-SC 857.48 15.67 226.57 849.81 740.81 -29.86 -73.03 5945583.67 558648.83 MWD+IFR-AK-CAZ-SC ! 948.06 20.33 228.41 935.93 826.93 -48.73 -93.69 5945564.65 558628.31 MWD+IFR-AK-CAZ-SC !! 'I 1041.06 24.31 230.15 1021.95 912.95 -71.72 -120.48 5945541.44 558601.70 MWD+IFR-AK-CAZ-SC ! 1134.20 28.34 230.76 1105.41 996.41 -98.00 -152.33 5945514.92 558570.06 MWD+IFR-AK-CAZ-SC !~, 1225.44 33.10 230.11 1183.83 1074.83 -127.70 -188.24 5945484.95 558534.39 MWD+IFR-AK-CAZ-SC I! 1318.35 37.47 231.40 1259.65 1150.65 -161.62 -229.82 5945450.71 558493.08 MWD+IFR-AK-CAZ-SC 1410.82 40.50 233.18 1331.52 1222.52 -197.17 -275.85 5945414.81 558447.34 MWD+IFR-AK-CAZ-SC ~ 1504.40 42.52 233.73 1401.60 1292.60 -234.09 -325.67 5945377.50 558397.80 MWD+IFR-AK-CAZ-SC 1596.02 46.06 233.75 1467.17 1358.17 -271.92 -377.25 5945339.27 558346.53 MWD+IFR-AK-CAZ-SC i i 1689.22 45.31 233.86 1532.28 1423.28 -311.30 -431.07 5945299.47 558293.02 MWD+IFR-AK-CAZ-SC 1782.35 50.09 232.99 1594.94 1485.94 -352.35 -486.36 5945258.00 558238.06 MWD+IFR-AK-CAZ-SC i 1873.86 55.20 232.89 1650.44 1541.44 -396.18 -544.38 5945213.73 558180.38 MWD+IFR-AK-CAZ-SC t 1966.96 58.05 234.02 1701.66 1592.66 -442.46 -606.84 5945166.97 558118.29 MWD+IFR-AK-CAZ-SC '! i i 2061.56 61.81 234.48 1749.05 1640.05 -490.27 -673.28 5945118.64 558052.24 MWD+IFR-AK-CAZ-SC 2153.34 66.94 235.16 1788.73 1679.73 -537.93 -740.90 5945070.46 557985.00 MWD+IFR-AK-CAZ-SC !, 2245.85 68.35 235.35 1823.91 1714.91 -586.69 -811.20 5945021.16 557915.09 MWD+IFR-AK-CAZ-SC 2340.01 66.55 234.38 1860.02 1751.02 -636.73 -882.31 5944970.57 557844.37 MWD+IFR-AK-CAZ-SC Halliburton Company. Survey Report (~ouipan}: ConocoPhillips Alaska Inc. Dafe: 7/13/2006 Time: 09:54:28 Pagc: 2 Iicld: Ku paruk River Uni t Co-ordinate (:VE) Reference: Well: 1J-17 0, T rue North Site: Kuparuk 1J Pad Verti cal (TVD)Referencr. 1J-170L2 : 109 A R'ell: 1J -170 Secti on (~S) Reference: Well (O.OON,O.O OE,O.OOAzi)' ~~'ellpath: 1J -170L2 Surve} Calculation Method: Minimum Curvature D6:, Oracle Sun~e~° 14D Incl Azim TVD Sys TV D N!S E/W DtapN MapE luul ft deg de g ft ft ft ft ft ft 2430.35 66.09 233 .38 1896. 31 1787. 31 -685 .49 -949. 14 5944921 .29 557777 .93 MWD+IFR-AK-CAZ-SC ~ 2524.20 66.73 232 .33 1933. 86 1824. 86 -737 .43 -1017. 70 5944868 .83 557709 .79 MWD+IFR-AK-CAZ-SC i 2617.29 65.63 232 .47 1971. 46 1862. 46 -789 .42 -1085. 15 5944816 .32 557642 .76 MWD+IFR-AK-CAZ-SC ', 2708.83 65.47 232 .71 2009. 35 1900. 35 -840 .07 -1151. 32 5944765 .16 557576 .99 MWD+IFR-AK-CAZ-SC I ' 2801.61 66.32 234 .48 2047. 24 1938. 24 -890 .33 -1219. 48 5944714 .38 557509 .23 MWD+IFR-AK-CAZ-SC I 2893.74 64.53 235 .05 2085. 56 1976. 56 -938 .66 -1287. 90 5944665 .51 557441 .19 MWD+IFR-AK-CAZ-SC 2988.02 66.31 235 .05 2124. 77 2015. 77 -987 .78 -1358. 18 5944615 .86 557371 .31 MWD+IFR-AK-CAZ-SC II 3074.18 65.18 236 .36 2160. 17 2051. 17 -1032 .04 -1423. 07 5944571 .09 557306 .77 MWD+IFR-AK-CAZ-SC 3105.86 63.95 236 .54 2173. 77 2064. 77 -1047 .85 -1446. 91 5944555 .10 557283 .05 MWD+IFR-AK-CAZ-SC 3200.29 64.63 235 .81 2214. 74 2105. 74 -1095 .21 -1517. 59 5944507 .19 557212 .75 MWD+IFR-AK-CAZ-SC t 3291.60 63.12 238 .30 .2254. 95 2145. 95 -1139 .80 -1586. 37 5944462 .07 557144 .33 MWD+IFR-AK-CAZ-SC I i i 3384.37 63.59 241 .70 2296. 56 2187. 56 -1181 .25 -1658. 17 5944420 .07 557072 .86 MWD+IFR-AK-CAZ-SC I 3478.44 63.52 245 .56 2338. 47 2229. 47 -1218 .65 -1733. 61 5944382 .09 556997 .72 I MWD+IFR-AK-CAZ-SC ~I 3572.09 64.29 249 .70 2379. 67 2270. 67 -1250 .64 -1811. 37 5944349 .50 556920 .23 MWD+IFR-AK-CAZ-SC '~ 3666.38 63.60 255 .60 2421. 12 2312. 12 -1275 .90 -1892. 17 5944323 .61 556839 .63 MWD+IFR-AK-CAZ-SC I 3761.00 63.46 260 .73 2463. 32 2354. 32 -1293 .26 -1975. 03 5944305 .60 556756 .92 MWD+IFR-AK-CAZ-SC 3853.11 64.39 266 .07 2503. 83 2394. 83 -1302 .75 -2057. 17 5944295 .47 556674 .86 MWD+IFR-AK-CAZ-SC II 3946.84 67.20 273 .93 2542. 30 2433. 30 -1302 .69 -2142. 56 5944294 .87 556589 .48 MWD+IFR-AK-CAZ-SC ~I 4039.97 65.00 278 .25 2580. 05 2471. 05 -1293 .68 -2227. 20 5944303 .21 556504 .78 MWD+IFR-AK-CAZ-SC i 4133.23 64.70 281 .87 2619. 69 2510. 69 -1278 .94 -2310. 30 5944317 .30 556421 .57 MWD+IFR-AK-CAZ-SC 4224.53 63.44 282 .61 2659. 61 2550. 61 -1261 .54 -2390. 54 5944334 .08 556341 .21 MWD+IFR-AK-CAZ-SC ~I 4319.36 66.10 283 .59 2700. 03 2591. 03 -1242 .09 -2474. 08 5944352 .87 556257 .53 MWD+IFR-AK-CAZ-SC ~ 4412.60 66.79 282 .94 2737. 29 2628. 29 -1222 .48 -2557. 27 5944371 .83 556174 .19 MWD+IFR-AK-CAZ-SC 4505.54 67.18 282 .40 2773. 63 2664. 63 -1203 .72 -2640. 73 5944389 .94 556090 .60 MWD+IFR-AK-CAZ-SC 4601.05 67.18 284 .97 2810. 68 2701. 68 -1182 .89 -2726. 26 5944410 .10 556004 .92 MWD+IFR-AK-CAZ-SC 4690.50 66.73 288 .90 2845. 71 2736. 71 -1158 .93 -2804. 98 5944433 .45 555926 .02 MWD+IFR-AK-CAZ-SC ~~ 4780.83 65.35 293 .36 2882. 40 2773. 40 -1129 .20 -2881. 95 5944462 .57 555848 .83 MWD+IFR-AK-CAZ-SC 4879.54 64.12 298 .89 2924. 56 2815. 56 -1089 .93 -2962. 07 5944501 .21 555768 .42 MWD+IFR-AK-CAZ-SC !I 4972.71 63.90 302 .49 2965. 40 2856. 40 -1047 .20 -3034. 07 5944543 .37 555696 .09 MWD+IFR-AK-CAZ-SC j 5068.22 64.61 306 .75 3006. 90 2897. 90 -998 .33 -3104. 84 5944591 .68 555624 .95 MWD+IFR-AK-CAZ-SC I~ 5160.02 64.66 312 .00 3046. 25 2937. 25 -945 .73 -3168. 93 5944643 .78 555560 .46 MWD+IFR-AK-CAZ-SC 5254.34 I 67.22 318 .22 3084. 73 2975. 73 -884 .73 -3229. 63 5944704 .30 555499 .28 MWD+IFR-AK-CAZ-SC I 5345.64 67.73 323 .79 3119. 73 3010. 73 -819 .21 -3282. 67 5944769 .39 555445 .74 MWD+IFR-AK-CAZ-SC 5438.98 67.21 329 .57 3155. 52 3046. 52 -747 .21 -3330. 01 5944841 .02 555397 .85 MWD+IFR-AK-CAZ-SC ', 5533.31 68.47 335 .37 3191. 13 3082. 13 -669 .78 -3370. 35 5944918 .13 555356 .91 MWD+IFR-AK-CAZ-SC 5625.93 72.12 341 .26 3222. 37 3113. 37 -588 .79 -3402. 50 5944998 .85 555324 .13 MWD+IFR-AK-CAZ-SC ~ 5719.45 I 72.25 346 .61 3251. 01 3142. 01 -503 .27 -3427. 12 5945084 .17 555298 .84 MWD+IFR-AK-CAZ-SC '~, 5814.69 73.89 352 .76 3278. 76 3169. 76 -413 .68 -3443. 41 5945173 .62 555281 .86 MWD+IFR-AK-CAZ-SC 5907.49 75.91 358 .77 3302. 96 3193. 96 -324 .38 -3450. 00 5945262 .86 555274 .58 MWD+IFR-AK-CAZ-SC ', 6000.27 78.27 359 .79 3323. 69 3214. 69 -233 .96 -3451. 13 5945353 .26 555272 .74 MWD+IFR-AK-CAZ-SC ', 6093.70 78.76 359 .45 3342. 29 3233. 29 -142 .40 -3451. 74 5945444 .80 555271 .42 MWD+IFR-AK-CAZ-SC 6186.46 79.63 358 .81 3359. 68 3250. 68 -51 .30 -3453. 12 5945535 .88 555269 .32 MWD+IFR-AK-CAZ-SC I 6280.24 78.96 357 .80 3377. 10 3268. 10 40 .81 -3455. 85 5945627 .96 555265 .88 MWD+IFR-AK-CAZ-SC 6371.85 79.47 357 .84 3394. 24 3285. 24 130 .74 -3459. 27 5945717 .84 555261 .76 MWD+IFR-AK-CAZ-SC • 6409.00 79.24 358 .13 .3401. 10 3292. 10 167 .22 -3460. 55 5945754 .32 555260 .19 MWD+IFR-AK-CAZ-SC 6486.47 82.51 1 .04 3413. 39 3304. 39 243 .69 -3461. 10 5945830 .77 555259 .05 MWD+IFR-AK-CAZ-SC 6582.71 84.65 4 .61 3424. 15 3315. 15 339 .19 -3456. 38 5945926 .30 555263 .02 MWD+IFR-AK-CAZ-SC 6679.35 86.94 8 .16 3431 .24 3322. 24 434 .95 -3445. 66 5946022 .13 555272 .99 MWD+IFR-AK-CAZ-SC i 6775.99 87.18 12 .01 3436. 20 3327. 20 529 .95 -3428. 76 5946117 .25 555289 .15 MWD+IFR-AK-CAZ-SC 6873.09 88.85 14 .31 3439. 56 3330. 56 624 .44 -3406. 67 5946211 .89 555310 .50 MWD+IFR-AK-CAZ-SC ', 6968.26 92.32 15 .69 3438 .59 3329. 59 716 .34 -3382. 05 5946303 .98 555334 .41 MWD+IFR-AK-CAZ-SC i 7063.76 92.98 14 .70 3434 .18 3325. 18 808 .40 -3357. 04 5946396 .22 555358 .69 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Ina Date: 7/13/2006 Time: 09:5428 Page: 3 Field: Kuparuk River Uni f Co-ordiuate (~E) Reference: Well: 1J-17 0, True North Site: Kuparuk 1J Pad Verti cal (TV D) Reference: 1J-170L2 : 109.0 Hell: 1J -170 Secti on (VS) Reference: Well (O.OON;O.OO E,O.OOAzi) ~Vellpath: 1J -170L2 Survey Calc ulatimi Method: Minimum C urvature llb: Oracle Survey __ A9D lnd .~zim TVD Sys TVD N/S E/W Maps' h1apE Tool ft deg deg ft ft ft ft ft ft - 7162.38 90.99 11 .47 3430. 76 3321 .76 904 __ .39 _ -3334. __ 73 _ 5946492 .37 555380 .25 MWD+IFR-AK-CAZ-SC 7259.03 90.94 9 .69 3429. 13 3320 .13 999 .38 -3316. 99 5946587 .49 555397 .25 MWD+IFR-AK-CAZ-SC ! 7354.23 92.06 9 .20 3426. 64 3317 .64 1093 .25 -3301. 37 5946681 .47 555412 .13 MWD+IFR-AK-CAZ-SC 7451.67 89.01 10 .19 3425. 73 3316 .73 1189 .29 -3284. 97 5946777 .62 555427 .78 MWD+IFR-AK-CAZ-SC 7552.67 91.01 17 .46 3425. 71 3316 .71 1287 .29 -3260. 85 5946875 .80 555451 .13 MWD+IFR-AK-CAZ-SC 7646.37 89.26 14 .20 3425. 49 3316 .49 1377 .42 -3235. 30 5946966 .12 555475 .98 MWD+IFR-AK-CAZ-SC 7742.72 88.59 10 .92 3427. 30 3318 .30 1471 .43 -3214. 35 5947060 .28 555496 .19 MWD+IFR-AK-CAZ-SC 7837.66 91.95 11 .76 3426. 85 3317 .85 1564 .51 -3195. 68 5947153 .49 555514 .13 MWD+IFR-AK-CAZ-SC 7934.10 88.64 7 .54 3426. 36 3317 .36 1659 .54 -3179. 52 5947248 .64 555529 .55 MWD+IFR-AK-CAZ-SC 8032.32 88.78 6 .20 3428. 57 3319 .57 1757 .03 -3167. 78 5947346 .21 555540 .53 MWD+IFR-AK-CAZ-SC 8129.38 88.66 2 .77 3430. 74 3321 .74 1853 .76 -3160. 19 5947442 .98 555547 .36 MWD+IFR-AK-CAZ-SC 8224.48 88.53 1 .45 3433. 07 3324 .07 1948 .76 -3156. 69 5947538 .00 555550 .12 MWD+IFR-AK-CAZ-SC 8321.71 91.14 358 .24 3433. 35 3324 .35 2045 .97 -3156. 95 5947635 .19 555549 .10 MWD+IFR-AK-CAZ-SC 8417.71 91.31 355 .27 3431. 30 3322 .30 2141 .78 -3162. 39 5947730 .95 555542 .92 MWD+IFR-AK-CAZ-SC 8514.69 I 90.81 355 .74 3429. 50 3320 .50 2238 .45 -3169. 99 5947827 .55 555534 .57 MWD+IFR-AK-CAZ-SC ' 8611.16 91.44 354 .80 3427. 61 3318 .61 2334 .57 -3177. 94 5947923 .59 555525 .87 MWD+IFR-AK-CAZ-SC 8708.07 90.75 353 .86 3425. 75 3316 .75 2430 .99 -3187. 51 5948019 .92 555515 .54 MWD+IFR-AK-CAZ-SC 8805.09 89.26 353 .30 3425. 75 3316 .75 2527 .39 -3198. 36 5948116 .23 555503 .95 MWD+IFR-AK-CAZ-SC ', 8899.91 87.41 354 .64 3428. 50 3319 .50 2621 .64 -3208. 32 5948210 .39 555493 .26 MWD+IFR-AK-CAZ-SC ', 8998.83 I 89.22 356 .29 3431. 41 3322 .41 2720 .20 -3216. 13 5948308 .88 555484 .67 MWD+IFR-AK-CAZ-SC 9095.31 C 89.40 359 .72 3432 .57 3323 .57 2816 .60 -3219. 49 5948405 .24 555480 .56 MWD+IFR-AK-CAZ-SC a I 9191.88 89.71 1 .45 3433 .32 3324 .32 2913 .16 -3218. 51 5948501 .80 555480 .80 il MWD+IFR-AK-CAZ-SC 9287.19 90.88 1 .49 3432. 83 3323 .83 3008 .44 -3216. 06 5948597 .08 555482 .50 MWD+IFR-AK-CAZ-SC ! 9383.52 90.57 0 .70 3431. 61 3322 .61 3104 .74 -3214. 22 5948693 .39 555483 .59 MWD+IFR-AK-CAZ-SC I 'i 9481.40 91.25 359 .52 3430. 06 3321 .06 3202 .61 -3214. 03 5948791 .24 555483 .01 MWD+IFR-AK-CAZ-SC 'I 9578.46 ~ 91.12 356 .32 3428. 05 3319 .05 3299 .57 -3217. 55 5948888 .16 555478 .73 MWD+IFR-AK-CAZ-SC 9675.04 90.50 353 .95 3426. 69 3317 .69 3395 .78 -3225. 74 5948984 .30 555469 .80 MWD+IFR-AK-CAZ-SC 9770.94 89.27 354 .29 3426. 88 3317 .88 3491 .18 -3235. 57 5949079 .61 555459 .23 MWD+IFR-AK-CAZ-SC 'i ~! 9867.54 88.53 355 .03 3428 .73 3319 .73 3587 .34 -3244. 56 5949175 .69 555449 .49 MWD+IFR-AK-CAZ-SC 9964.60 89.53 355 .76 3430. 38 3321 .38 3684 .07 -3252. 35 5949272 .34 555440 .95 MWD+IFR-AK-CAZ-SC ! ', 10062.48 91.07 359 .10 3429. 86 3320 .86 3781 .83 -3256. 74 5949370 .06 555435 .80 MWD+IFR-AK-CAZ-SC I, ', 10157.82 89.08 358 .48 3429. 74 3320 .74 3877 .15 -3258. 75 5949465 .35 555433 .04 MWD+IFR-AK-CAZ-SC !I 10255.29 90.08 357 .77 3430 .45 3321 .45 3974 .56 -3261. 94 5949562 .72 555429 .09 MWD+IFR-AK-CAZ-SC I i 10352.75 90.45 356 .52 3430. 00 3321 .00 4071 .90 -3266. 79 5949660 .01 555423 .48 MWD+IFR-AK-CAZ-SC j 10450.27 88.95 354 .70 3430. 51 3321 .51 4169 .12 -3274. 26 5949757 .16 555415 .26 MWD+IFR-AK-CAZ-SC ~ 10547.01 89.90 353 .85 3431. 48 3322 .48 4265 .37 -3283. 91 5949853 .33 555404 .86 MWD+IFR-AK-CAZ-SC 10642.82 87.78 354 .21 3433. 42 3324 .42 4360 .64 -3293. 87 5949948 .50 555394 .16 MWD+IFR-AK-CAZ-SC 10739.10 89.22 355 .27 3435. 94 3326 .94 4456 .48 -3302. 69 5950044 .26 555384 .59 MWD+IFR-AK-CAZ-SC 10836.36 89.46 357 .78 3437. 06 3328 .06 4553 .54 -3308. 58 5950141 .27 555377 .94 MWD+IFR-AK-CAZ-SC I 10933.14 88.34 0 .96 3438. 92 3329 .92 4650 .28 -3309. 65 5950237 .99 555376 .12 MWD+IFR-AK-CAZ-SC ~ 11030.09 91.14 0 .73 3439 .36 3330 .36 4747 .21 -3308. 22 5950334 .92 555376 .79 MWD+IFR-AK-CAZ-SC 11126.40 89.32 356 .66 .3438. 97 3329 .97 4843 .47 -3310. 41 5950431 .15 555373 .85 MWD+IFR-AK-CAZ-SC ! 11224.02 89.33 352 .25 3440 .13 3331 .13 4940 .61 -3319. 84 5950528 .19 555363 .66 MWD+IFR-AK-CAZ-SC 11318.65 87.47 353 .24 3442 .77 3333 .77 5034 .44 -3331. 79 5950621 .92 555350 .99 MWD+IFR-AK-CAZ-SC 11413.11 87.05 356 .86 3447 .28 3338 .28 5128 .42 -3339. 93 5950715 .83 555342 .11. MWD+IFR-AK-CAZ-SC ~I 11507.58 88.04 358 .32 3451 .33 3342 .33 5222 .72 -3343. 90 5950810 .08 555337 .41 MWD+IFR-AK-CAZ-SC I !! 11598.15 88.72 358 .75 3453 .89 3344 .89 5313 .22 -3346. 21 5950900 .56 555334 .39 MWD+IFR-AK-CAZ-SC I 11693.06 88.10 358 .29 3456 .53 3347 .53 5408 .06 -3348. 66 5950995 .37 555331 .20 MWD+IFR-AK-CAZ-SC !i 11786.82 89.28 356 .59 3458 .67 3349 .67 5501 .70 -3352. 85 5951088 .96 555326 .29 MWD+IFR-AK-CAZ-SC !~ ~' 11879.37 87.35 354 .49 3461 .39 3352 .39 5593 .92 -3360. 04 5951181 .11 555318 .37 MWD+IFR-AK-CAZ-SC I~ 11974.37 84.31 357 .64 3468 .30 3359 .30 5688 .42 -3366. 55 5951275 .55 555311 .13 i MWD+IFR-AK-CAZ-SC I 12066.50 86.32 0 .79 3475 .83 3366 .83 5780 .22 -3367. 80 5951367 .33 555309 .16 MWD+IFR-AK-CAZ-SC ii 12159.74 87.12 3 .74 3481 .16 3372 .16 5873 .22 -3364. 12 5951460 .35 555312 .12 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 7/13!2006 Time: 09:54:28 Page: d Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 1J-170, True North Site: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-170L2 : 109.0 WeN: 1J-170 Section (VS) Reference: Well (OAON,O.OOE,O.OOAzi) W'ellpath: 1J-170L2 Survey Calculation :Method: Minimum Curvature Db: Oracle Survev - _ __ i~ID Intl Azim Tti'D Sys TVD _ __ N/S E!W ~IapN I<IapE Tool ft deg deg ft ft ft ft ft ft C 12250.58 88.35 5.84 _ 3484.75 3375.75 ____ 5963.67 -3356.54 .5951550.84 _ - 555318.99 MWD+IFR-AK-CAZ-SC 12340.64 89.90 4.63 3486.13 3377.13 6053.34 -3348.33 5951640.56 555326.51 MWD+IFR-AK-CAZ-SC 12432.91 88.28 359.92 3487.59 3378.59 6145.49 -3344.66 5951732.73 555329.45 MWD+IFR-AK-CAZ-SC 12522.84 86.11 357.24 3492.00 3383.00 6235.27 -3346.89 5951822.49 555326.53 MWD+IFR-AK-CAZ-SC 12613.72 87.86 357.62 3496.78 3387.78 6325.93 -3350.96 5951913.10 555321.75 MWD+IFR-AK-CAZ-SC 'I 12642.41 88.04 357.24 3497.80 3388.80 6354.58 -3352.24 5951941.73 555320.24 MWD+IFR-AK-CAZ-SC 12678.00 88.04 357.24 3499.02 3390.02 6390.10 -3353.95 5951977.24 . 555318.25 ~ PROJECTED to TD • - -, ' ~ m -? _.~ ~v ,y , __~ ~ . ALA58iA OIL A11TD ~7 CO1~T5ER~ATI011T COl~'Il~IISSIOI~T Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-170L2 ConocoPhillips Alaska, Inc. Permit No: 206-064 Surface Location: 1802' FSL, 2490' FEL, Sec. 35, T 11 N, R l OE, UM Bottomhole Location: 2913' FSL, 568' FEL, Sec. 27, T11N, RlOE, 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 obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw. the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-170, Permit No 206-062, API 50-029-23310-00. Injections should continue to be reported as a function of the original API number stated above. 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). ConocoPhillips Alaska Inc. I J-170L2 Permit No: 206-064 DATED this~day of May, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~- ALASKA OIL AND GAS CONSERVATION COMMISSION ~^ ~~~" r ~:;,,i PERMIT TO DRILL 20 AAC 25.005 _, ,, 1a. Type of Work: Drill ^/ Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service Q ' Development Gas ^ Multiple Zone^ Single Zone ^ 1c. Specify if well is proposed for: 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: 1 J-170L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12736' - ND: 3470' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1802' FSL, 2490' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25660 West Sak Oil Pool Top of Productive Horizon: 1673' FSL, 674' FEL, Sec, 34, T11 N, R10E, UM ' 8. Land Use Permit: ALK 470 13. Approximate Spud Date: 6/15/2006 Total Depth: 2913' FSL, 568' FEL, Sec. 27, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: <3 miles to KRU ' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558722 y- 5945614 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest well within Pool: 1 J-10 , 200' @ 5250' ' 16. Deviated wells: Kickoff depth: 6138 ft. Maximum Hole Angle: 89.6° deg 17. Maximum Anticipated Pressures in psig (see 20 AnC 25.035) Downhole: 1562 psig Surface: 1180 psig 18. Casing Program S ecif ti Setting Depth Quantity of Cement Size p ica ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 3018' 28' 28' 3018' 2145' 530 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7.625" 29.7# L-80 BTCM 7681' 28' 28' 7681' 3619' 430 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 6594' 6138' 3347' 12736' 3470' 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 ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): ~~~~ r „ Perforation Depth ND (ft): 20. Attachments: Filing Fee ~ BOP Sketch Drilling Program ^ Time v. Depth Plot Shallow Hazard Analysis / Properly Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Nugent @ 265-6862 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ Phone "LbSd'~50 Date h/.S/O~, P h n ll Dr k Commission Use Only Permit to Drill Number: .~~p ~ C..~Ct~~ API Number: 50- ~Z~' Z331~ ~ 6 I Permit Approval Date: See cover letter for other requirements Conditions of approval : If box is checked, well ma~ot be used to explore for, test, or produce Coalbed mQthane, gas hydrates, or gas contained in shales: ~~~~ pS~ ~~~'e~s~ e,-s 4~~nK Samples req'd: Yes ^ No LrrJ~ log req'd: Yes ^ No []/ Other: v ~~1n~ ~p~ \ ~ H2S measures: Yes ^ D' svy req'd: Yes [V]~ No ^ y~ ~ \ -~`~.\G1~~RCJ~CCC~ /~ `~ BY THE COMMISSION i DATE: ,COMMISSIONER Form 10-401 Revised 12!2005 ,~ Su • Du lic e /~``- ~ (~6l ub Ap~tion for Permit to Drill, Well 1J-170 L2 Revision No.0 Saved: 3-May-06 Permit It -West Sak Well #1J-170 L2 ~~°~ r.^ +'t Application for Permit to Drill Document, (~I~~c'V~II M d x i n7 i z E 1Mell Value Table of Contents 1. Well Name ................................................................................................................. 2 Re uirements of 20 AAC 25.005 ...................................................... p ................................................. 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(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 Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ........................................Error! Bookmark not defined. Requirements of 20 AAC 25.005(c)(7) ...............................................•-•-•--••-----.........................-•---........ 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c) (8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 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) ..........................................•-•-•-••--•--............................--•--........ 5 11 . Seabed Condition Analysis ..................................................................................... 5 .Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding ............................................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ..............................................._................................................ 5 not done 1J-170L2 PERMIT IT Page 1 of 6 ¢p. Printed:3-May-06 ~~~~~~i~ Apon for Permit to Drill, Well 1J-170 L2 Revision No.O Saved: 3-May-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) .......................................................................•-•--•---................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan .......................................................................................•--•-•--................. 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Aftachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 2f1 AAC 25.1140(b). For a we!/ with mu/tip/e we// branches, each branch must Simi/ar/y be identified by a unique name andAPl number by adding a suhrx to the name designated for the well by the operator and to the number assigned to the wet! by the commission. The well for which this Application is submitted will be designated as 1J-170 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except far an item already an file with the commission and identified in the application: (2) a plat identifying the property and the property's awners and showing (A)the coordinates of the proposed lacation of the we// at the surface, at the top of each objective formation, and at Iota/depth, referenced to governmental sectian lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the weU at the top of each objective formation and at total depth; Location at Surface 1,802' FSL, 2,489' FEL, Section 35, T11N, R10E ' ASPZone 4NA027Coordinates RKB Elevation 109.0' AMSL Northings.' 5,945,614 Eastings; 558,722 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 1,673' FSL, 674' FEL, Section 34, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB.' 6,138 Northings; 5,945,458 Eastings: 555,259 Total ~ertica/ De th, RKB; 3,347 Total vertical De th, SS.' 3,238 Location at Total De th 2913' FSL, 568' FEL, Section 27, T11N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12, 736 Northfngs: 5,951,978 Eastings; 555,307 Total ~ertica/De th, RKB: 3,470 . Total t/ertica/ De th, SS.' 3,361 and (D) other r"nformation required by 2D AAC 25. t15t1(b); E ~4`~'I~L v ~~ not done 1J-170L2 PERMIT IT Page 2 of 6 Printed: 3-May-O6 Ap~tion for Permit to Drill, Well 1J-170 L2 Revision No.O Saved: 3-May-06 Requirements of 20 AAC 25.050(b) Ifa we// is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (I) include a plat, drawn to a su/tab/e scale, showing the path of the proposed we/tbore, inc/uding a//adjacent we//bores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for a// wel/s witlain Z00 feet of the proposed wel/bore (A) list the names of the operators of those wells, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail; or (8) state that the applicant is the on/y afi`ected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An app/ication for a Permit to Drill must be accompanied by each of the fot/owing r'tems, except for an item a/ready on Ills wr"th the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (Bt?PE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication far a Permit to Drill must be accompan/ed by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (4) information on drilling hazards, inc/uding (A) the maximum downho% pressure that maybe encountered, criter/a used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW ~ (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. 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 "D" sand formation is 1,180 psi, calculated thusly: ' MPSP = (3,470 ft TVD)(0.45 - 0.11 psi/ft) = 1,180 psi (B) data on potentia! gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia/ causes of ho% problems such as abnormally geo pressured strata, lost circulation zones, and zones that have a propensity for differential st/cking; Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except far an item already on file with the commission and identified m the application: (5) a description of the procedure for canducting formation integrity tests, as required under 20 AAC 25.030(1?; The parent wellbore, iJ-170, will be completed with 7-5/8" intermediate casing landed in the West Sak A- 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 ConocoPhillips Alaska placed on file with the Commission. t ` a' $ '~~ .~. ~ [ ` c ~ `W !~ s c..M, not done 1J-170L2 PERMIT /T Page 3 of 6 Printed: 3-May-06 Application for Permit to Drill, Well 1J-170 Revision fJo.O Saved: 4-May-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied try each of the fo/%wing items, except for an item already on fi/e with the commission and identified in the application: (6) a complete proposed casing and cementing program as required try 20 AAC 25.030, and a description of any slotted liner, pre- perforated liner, or screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top etm Csg/Tbg Size Weigh Length MD/7VD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 .Welded 80 28 / 28 108 / 108. Cemented to surface with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 3,018 28 / 28 3,018 /2,145 530 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned 7-5/8 9-7/8 29.7 L-$0 BTCM 7,681 28 / 28 7,681 / 3,619 4,zoo' MD / 2,637' ND. Cemented w/ 430 sx Dee CRETE 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 5,824 6,684 / 3,447 12,508 / 3,643 Slotted- no cement Slotted Lateral (1J-170) 4-.1/2 6-3/4" B Sand 11.6 L-80 BTC 6,057. 6,584 / 3,434 12;649 / 3,525 Slotted- no cement ::S Lateral(i]-170 L1) ._.. 4-1/2 6-3/4" D Sand 11_.6 L-80 BTC 6,594 6,138 / 3,347 12,736 / 3 470 Slotted- no cement Slotted Lateral(i]-170 L2) , ~~ 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applicatian for a Permit to Dri/! must be accompanied by each of the fol/awing items, except for an item a/ream on fi/e with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by tite commission under 20 AAC 25.035(h)(2); IVo diverter system will be utilized during operations on 1J-170 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/ication for a Permit to Dri//must be accompanied by each of the fo/%wing items, except for an item alreao~ on file with the commission and identified in the application: (8) a drilling t7uid program, including a diagrarri and description of the drilling fluid system, as required 6y 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit 8.8 Plastic Viscostiy 15 - 25 Ib/100 s Yield Point 18 - 28 cP HTHP Fluid loss <4 0 ml/30 min 200 si . ORIGINAL ~-. not done 1J-170fAPERMlT IT Page 4 of 6 Printed: 4-May-06 App11L~Sfion for Permit to Drill, Well 1J-170 L2 Revision No.0 Saved: 3-May-06 200psi & 150° Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 Drilling fluid practices will 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 141. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Dri!! must be accompanied 6y each of the fo/lowing items, except for an r`tem already on file with the commission and identified in the application: (9) far an exp/oratory or stratigraphic test well, a tabulation setting out the depths of predicted abnorma/!y geo pressured strata as required by 20 AAC 25. (I33(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Dri// must be accompanied by each of the following items, except for an item already on fi/e with the commission and identi/ed in the app//catian; (70J for an exploratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 20 AAG 25, ©61(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drr`ll must be accompanied by each of the fol%wing items, except for an item already on file with the commission and identified in the application: (11) for a well dri/led from an affshore platform, mobi/e bottom-founded structure, jack-up rig, ar floating drilling vess% an analysis ofseabed conditions as required by 2Q AAC25. ®61(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding. Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to tlril/ must be accompanied by each of the fo/%wing items, except far an item already on ale with the commission and identified in the application: (12) evidence showing that the requirements of2Q AAC 25. f12s (Bonding}have been met; 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 application for a Permit to Drill must be accompanied by each of the fo/lowmg items, except for an item a/ready on frle wr"th the commission and identified in the application: The proposed drilling program is listed below. Please. refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-170 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 6,138' MD / 3,347' T~/D, the top of the top of the D sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 12,736' MD / 3,470' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. not done 1J-170L2 PERMIT IT Page 5 of 6 Printed: 3-May-O6 r`?~~~j Appll~tion for Permit to Drill, Well 1J-170 L2 Revision No.O Saved: 3-May-06 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2"slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running .tool. POOH. 10. 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. 11. POOH, laying down drill pipe as required. 12. PU injection completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel. 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/icat/on far a Permit to /?ri// music be accompanied by each of the fo!/owing items, except for an item already on ~/e with the commission and identified in the application,• (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 2l1 AAC ~5.0$D for an annular disposal operation in the wel/.; 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 will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (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 authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic not done 1J-170L2 PERMIT IT Page 6 of 6 ~~ ~ t ~ Printed: 3-May-O6 ~~. ~ w~ . ~ +[F . • ,, ConocoPhillips Alaska ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 -Slot 1J-170 1 J-170 L2 Proposal Report 10 April, 2006 ~perir~ Ctrl[ing eirvices ~~~ c 3 g ~' ~ MON J 0 _ _ __ _ _ _ _ _.___ _ _ __ _ ____ _ ~ ___ ~ ~ fiV r o cr (O MN~f~a ~' 0 Q ,~~ a J ~ d a' N E. M0\N 0 c ~ On O O F 2 N ~ r a o ~ ~ O O M N 3~ O gam" O C7 ~eDM~ p ~ O Z O r f~ .~- eT ~ N M1O~ ~ -j a ~~ ~ ~ Ooooo 0000 ~O vv° - ,`~.f ~ m o o m NM~ ~\ ~~ ~ r r ~y J N Ln p Z r N M ~ ~ ~ \ O \ ~ ~ rn F J W V ~ !a ~ ~ 4 ohs \ F N cam- O O J o 7 ~ ~ -y M M G O O 7 ~ ~ q LJ O ~ C ~ M }~ G C y ~ O m ~ d ~ M o ~ \ oM) C ~ ohs C ~ N O rL C ~ V ~ 00 c N C9 ~~ N Q ~ C N o .. ~ J \ ~. a O J G ~ m o 3 ~~~~ 0 ~ `~ \ ~ o _ ~ ° ~ \ N ~J 7 3 ' O ~ ~ ~ ' ~ ~ C r G n ~ ~ ~? ~ ~ ~ , y:. ~ ~ ° YY •• O~ ~ ~ o o :. .. d'C~ .~. ~ ~ - 3 Nr d N ~ R C \ \ _ }... a ~ a .~ ~ ~ ` ~\ ~ m d ~ ~ ~ ~ ~ ~ ~ o ~ K ~ ~ N M \\ e68 \ M f w ~ \ \ ~ [ ~ ~ ~ ~ °o ~ € I M ~ ~p ~\ ~ ~ \ ~ ~ L1 ~ \ \ .,A® ~ ~ O J Ty~ Jq '. ~i ~ ~ G o N `a~ O ~ b h~ O 60O °~< 66 ~ 90~ o0 N O O aD O O O O O d' V O O O O W N P'1 O O (D r-et~g11 41d O O O O O ~ ~J W~~B-a/~~~1 O O O O W N N M O O O O. CO O M 7 O' O ~ 'S O O QO 7 Project: Kuparuk River l Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: 1J-170 L2 Plan: 1J-170 L2 (wp05) L2 : BHL @ 12736ft MD, 3470ft TVD - 41/2 i i i i i 1J-170 L1 (wp05 i #J-170 L2 T5 Tae (wp05 ~i - 1J-170 (wp05 '-- ~ 41/2" -' #J-170 L2 T4{wp05 _______-- '''/ 1J-170 L2 T3 (wp05 - _ _ _ _ _ _ _ _ L S V O #J-170 L2 T2(wp05--------- r N j( ~ CASING DETAILS No TVD MD Name Size 1 80.00 80.00 20" 20 2 2145.00 3018.00 10 3/4" 10-3/4 3 3347.00 6138.33 7 5/8" 7-5/8 4 3470.00 12736.27 4 1 /2" 4-1 /2 T ~zm~.~t~s tt; ~~~n;~ Paer:l, Magnetic North: 24.04° Magnetic Field Strength: 57565.On Dip Angle: 80.77° Date: 7/1/2006 Model: BGGM200 t11" Sperry Oriliin~ garvtcas Conan Phillips I Aiaska J-170 L oy DD Polygon Describes a corridor 104' wide With a 50'+(-allowance from the proposed Wellbare. 31 1 1 I -1 I -1 c If t` J ~ L2 . End Rathole Build @ 5°/100ft to 89° Inc - 6180ft MD, 3355ft TVp i f i~ f / ' L2 : BOW @ 6150ft MD, 3350ft TV ~/ ,, ?f ,"'~ f , - L2 : TOW @ 6138ft MD, 3347ft TV ====-- II' f~~i p0 350° ,51,9 ~~~oo° ~a ~roo N ~S OD N N 1J-170 L2 T# {wp05 _ _ _ - - _ - ~ ~ ° _ L2 : Continue Geosteer in D-Sand : 6543ft MD, 3388ft 0 N t t O O -6250 -5625 -5000 -4375 -3750 -3125 -2500 -1875 -1250 -625 ,ra, r~ w)6dest(~E~st~+)(1250ft/in' 0 625 1250 1875 2500 ConaCC~Ph~~~ips A13ska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: iJ-170 L2 Design: 1J-170 L2 (wp05) • Halliburton Energy Services. Kati I ~ ~°~~ Planning Report -Geographic Sperry l7rrll~ng gerviices Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 TVD Reference: Planned RK8 @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-170 -Slot 1J-170 Well Position +N/-S 0.00 ft Northing: 5,945,614.10 ft Latitude: 70° 15' 43.258" N +E/-W 0.00 ft Easting: 558,721.61 ft Longitude: 149° 31' 31.065" W Position Uncertainty 0.00 ft Wellhead E levation: ft Ground Level: 81.OOft Wellbore 1J-170 L2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2005 7/1/2006 24.0413 80.7740 57,565 Design 1J-170 L2 (wp05) --- Audit Notes: Version: Phase: PLAN Tie On Depth: 6,138.32 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 O.UO 0.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/_g +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 6,138.32 77.00 359.79 3,347.00 -129.11 -3,464.05 0.00 0.00 0.00. 0.0000 6,150.32 78.91 359.79 3,349.50 -117.37 -3,464.10 15.90 15.90 0.00 0.0000 6,180.32 78.91 359.79 3,355.28 -87.93 -3,464.21 0.00 0.00 0.00 0.0000 6,460.53 88.58 10.00 3,385.85 188.87 -3,440.27 5.00 3.45 3.64 47.0487 6,543.31 89.11 14.11 3,387.53 269.80 -3,422.99 5.00 0.64 4.96 82.7155 7,998.87 89.11 14.11 3,410.18 1,681.29 -3,068.29 0.00 0.00 0.00 0.0000 8,281.01 89.35 0.00 3,414.00 1,960.56 -3,033.73 5.00 0.09 -5.00 -89.1175 8,631.17 .89.54 349.50 3,417.40 2,308.75 -3,065.74 3.00 0.05 -3.00 -89.0063 9,807.39 89.54 349.50 3,426.80 3,465.22 -3,280.16 0.00 0.00 0.00 0.0000 10,115.18 89.62 358.73 3,429.05 3,771.05 -3,311.69 3.00 0.03 3.00 89.5512 11,615.18 89.62 358.73 3,439.00 5,270.65 -3,344.93 0.00 0.00 0.00 0.0000 12,015.43 88.95 358.73 3,444.00 5,670.77 -3,353.82 0.17 -0.17 0.00 -179.7381 12,415.78 88.19 358.73 3,454.00 6,070.89 -3,362.70 0.19 -0.19 0.00 179.7685 12,736.28 86.09 0.37 3,470.00 6,390.95 -3,365.20 0.83 -0.66 0.51 142.0133 4/10/2006 12:30:OOPM Page 2 of 6 COMPASS 2003.11 Build 50 ^~ t {Sk i *~r ~ ~ ~ k Halliburton Energy Services , ~, ~, Planning Report -Geographic Al~sh~ Sperry i~riilling Serrriic~es Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 L2 Design: 1J-170 L2 (wp05) Planned Survey 1J-170 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section lft) (°) (°) (ft) (ft) (ft) (ft) (ft) lft) (°/100ft) (ft) 6,138.32 77.00 359.79 3,347.00 3,238.00 -129.11 -3,464.05 5,945,458.00 555,259.00 0.00 -129,11 L2 : TOW @ 6138ft M D, 3347ft TVD -1673ft FS L & 674ft FEL -Sec 34 - T11 N - R10E - 7 5/8" , 6,150.32 78.91 359.79 3,349.50 3,240.50 -117.37 -3,464.10 5,945,469.73 .555,258.87. 15.90 -117.37 L2 : BOW @ 6150ft MD, 3350ft TVD 6,180.32 78.91 359.79 3,355.28 3,246.28 -87.93 -3,464.21 5,945,499.17 555,258.53 0.00 -87.93 L2 : End Rathole Build @ 5°/100ft to 89° Inc - 6180ft MD, 33 55ft TVD 6,200.00 79.58 0.52 3,358.95 3,249.95 -68.60 -3,464.15 5,945,518.50 555,258.43 4.99 -68.60 6,300.00 83.01 4.20 3,374.08 3,265.08 30.13 -3,460.07 5,945,617.25 555,261.74 5.00 30.13 6,400.00 86.48 7.82 3,383.24 3,274.24 129.13 -3,449.64 5,945,716.32 555,271.40 5.00 129.13 6,460.53 88.58 10.00 3,385.85 3,276.85 188.87 -3,440.27 5,945,776.12 555,280.30 5.00 188.87 6,500.00 88.83 11.96 3,386.75 3,277.75 227.61 -3,432.75 5,945,814.91 555,287.52 5.00 227.61 6,543.31 89.11 14.11 3,387.53 3,278.53 269.80 -3,422.99 5,945,857.17 555,296.95 5.00 269.80 L2 : Continue Geosteer in D-Sand : 6543ft MD, 3388ft TVD 6,600.00 89.11 14.11 3,388.41 3,279.41 324.77 -3,409.18 5,945,912.24 555,310.33 0.00 324.77 6,700.00 .89.11 14.11 3,389.96 3,280.96 421.74 -3,384.81 5,946,009.39 555,333.94 0.00 421.74 6,800.00 89.11 14.11 3,391.52 3,282.52 518.71 -3,360.44 5,946,106.54 555,357.55 0.00 518.71 6,900.00 89.11 14.11 3,393.08 3,284.08 615.68 -3,336.07 5,946,203.69 555,381.16 0.00 615.68 7,000.00 89.11 14.11 3,394.63 3,285.63 712.66 -3,311.70 5,946,300.84 555,404.77 0.00 712.66 7,100.00 89.11 14.11 3,396.19 3,287.19 809.63 -3,287.33 5,946,397.99 555,428.38 0.00 809.63 7,200.00 89.11 14.11 3,397.75 3,288.75 906.60 -3,262.96 5,946,495.14 555,451.99 0.00 906.60 7,300.00 89.11 14.11 3,399.30 3,290.30 1,003.58 -3,238.59 .5,946,592.29 555,475.60 0.00 1,003.58 7,400.00 89.11 14.11 3,400.86 3,291.86 1,100.55 -3,214.22 5,946,689.45 555,499.21 0.00 1,100.55 7,500.00 89.11 14.11 3,402.42 3,293.42 1,197.52 -3,189.86 5,946,786.60 555,522.82. 0.00 1,197.52 7,600.00 89.11 14.11 3,403.97 3,294.97 1,294.49 -3,165.49 5,946,883.75 555,546.43 0.00 1,294.49 7,700.00 89.11 14.11 3,405.53 3,296.53 1,391.47 -3,141.12 5,946,980.90 555,570.04 0.00 1,391.47 7,800.00 89.11 14.11 3,407.09 3,298.09 1,488.44 -3,116.75 5,947,078.05 555,593.65 0.00 1,488.44 7,900.00 89.11 14.11 3,408.65 3,299.65 1,585.41 -3,092.38 5,947,175.20 555,617.26 0.00 1,585.41 7,998.87 89.11 14.11 3,410.18 3,301.18 1,681.29 -3,068.29 5,947,271.25 555,640.60 0.00 1,681.29 8,000.00 89.11 14.05 3,410.20 3,301.20 1,682.39 -3,068.01 5,947,272.35 555,640.87 4.86 1,682.39 8,100.00 89.19 9.05 3,411.69 3,302.69 1,780.32 -3,048.00 5,947,370.43 555,660.12. 5.00 1,780.32 8,200.00 89.28 4.05 3,413.03 3,304.03 1,879.63 -3,036.60 5,947,469.81 555,670.74 5.00 1,879.63 8,281.01 89.35 0.00 3,414.00 3,305.00 1,960.56 -3,033.73 5,947,550.75 555,672.97 5.00 1,960.56 1J-170 L2 T1 (wp05) 8,300.00 89.36 359.43 3,414.21 3,305.21 1,979.55 -3,033.83 5,947,569.74 555,672.73 2.99 1,979.55 8,400.00 89.41 356.43 3,415.28 3,306.28 2,079.47 -3,037.44 .5,947,669.62 555,668.34 3.00 2,079.47 8,500.00 89.47 353.43 3,416.26 3,307.26 2,179.06 -3,046.27 5,947,769.13 555,658.73 3.00 2,179.06 8,600.00 89.52 350.43 3,417.14 3,308.14 2,278.06 -3,060.31 5,947,868.00 555,643.93 3.00 2,278.06 8,631.17 89.54 349.50 3,417.40 3,308.40 2,308.75 -3,065.74 5,947,898.65 555,638.25 3.00 2,308.75 8,700.00 89.54 349.50 3,417.95 3,308.95 2,376.42 -3,078.29 5,947,966.22 555,625.18 0.00 2,376.42 8,800.00 89.54 349.50 3,418.74 3,309.74 2,474.74 -3,096.52 5,948,064.38 555,606.19 0.00 2,474.74 8,900.00 89.54 349.50 3,419.54 3,310.54 2,573.06 -3,114.75 5,948,162.55 555,587.19 0.00 2,573.06 9,000.00 89.54 349.50 3,420.34 3,311.34 2,671.39 -3,132.97 5,948,260.72 555,568.20 0.00 2,671.39 9,100.00 89.54 349.50 3,421.14 3,312.14 2,769.71 -3,151.20 5,948,358.88 555,549.21 0.00 2,769.71 9,200.00 89.54 349.50 3,421.94 3,312.94 2,868.03 -3,169.43 5,948,457:05 555,530.21 0.00 2,868.03 9,300.00 89.54 349.50 3,422.74 3,313.74 2,966.35. -3,187.66 5,948,555.22 555,511.22 0.00 2,966.35 9,400.00 89.54 349.50 3,423.54 3,314.54 3,064.67 -3,205.89 5,948,653.38 555,492.23 0.00. 3,064.67 9,500.00 89.54 349.50 3,424.34 3,315.34 3,162.99 -3,224.12 5,948,751.55 555,473.23 0.00 3,162.99 9,600.00 89.54 349.50 3,425.14 3,316.14 3,261.31 -3,242.35 5,948,849.72 555,454.24 0.00 3,261.31 4/10/2006 12:30:OOPM Page 3 of 6 COMPASS 2003.11 Build 50 ~~ ~ ~~~ ~~ Halliburton Energy Services t ~`~1~ . u ~ ~ ~C~110CG1 1 S Planning Report -Geographic - Alaska Sperry Drflling Servtce~ Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Company: ConocoPhillips Alaska (Kuparuk) TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Wellbore: 1J-170 L2 Design: 1J-170 L2 (wp05) Planned Survey 1J-170 L2 (wp05) Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E/_yl/ Northing Easting DLSEV Vert Section lft) (°) (°) (ft) lft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 9,700.00 89.54 349.50 3,425.94 3,316.94 3,359.63 -3,260.58 5,948,947.88 555,435.25 0.00 3,359.63 9,800.00 89.54 349.50 3,426.74 3,317.74 3,457.96 -3,278.81 5,949,046.05 555,416.25 0.00 3,457.96 9,807.39 89.54 349.50 3,426.80 3,317.80 3,465.22 -3,280.16 5,949,053.31 555,414.85 0.00 3,465.22 9,900.00 89.56 352.27 3,427.52 3,318.52 3,556.65 -3,294.82 5,949,144.61 555,399.47 3.00 3,556.65 10,000.00 89.59 355.27 3,428.26 3,319.26 3,656.05 -3,305.67 5,949,243.91 555,387.85 3.00 3,656.05 10,100.00 89.62 358.27 3,428.95 3,319.95 3,755.87 -3,311.29 5,949,343.68 555,381.45 3.00 3,755.87 10,115.18 .89.62 358.73 3,429.05 3,320.05 3,771.05 -3,311.69 5,949,358.85 555,380.93 3.01 3,771.05 10,200.00 89.62 358.73 3,429.61 3,320.61 3,855.85 -3,313.57 5,949,443.62 555,378.39 0.00 3,855.85 10,300.00 89.62 358.73 3,430.28 3,321.28 3,955.82 -3,315.79 5,949,543.56 555,375.40 0.00 3,955.82 10,400.00 89.62 358.73 3,430.94 3,321.94 4,055.79 -3,318.00 5,949,643.51 555,372.40 0.00 4,055.79 10,500.00 89.62 358.73 3,431.60 3,322.60 4,155.77 -3,320.22 5,949,743.45 555,369.41 0.00 4,155.77 10,600.00 89.62 358.73 3,432.27 3,323.27 4,255.74 -3,322.43 5,949,843.39 555,366.41 0.00 4,255.74 10,700.00 89.62 358.73 3,432.93 3,323.93 4,355.71 -3,324.65 5,949,943.34 555,363.42 0.00 4,355.71 10,800.00 89.62 358.73 3,433.59 3,324.59 4,455.69 -3,326.87 5,950,043.28 555,360.42 0.00 4,455.69. 10,900.00 89.62 358.73 3,434.26 3,325.26 4,555.66 -3,329.08 5,950,143.22 555,357.42 0.00 4,555.66 11,000.00 89.62 358.73 3,434.92 3,325.92 4,655.63 -3,331.30 5,950,243.17 555,354.43 0.00 4,655.63 11,100.00 89.62 358.73 3,435.58 3,326.58 4,755.60 -3,333.52 5,950,343.11 555,351.43 0.00 4,755.60 11,200.00 89.62 358.73 3,436.25 3,327.25 4,855.58 -3,335.73 5,950,443.05 555,348.44 0.00 4,855.58 11,300.00 89.62 358.73 3,436.91 3,327.91 4,955.55 -3,337.95 5,950,543.00 555,345.44 0.00 4,955.55 11,400.00 89.62 358.73. 3,437.57 3,328.57 5,055.52 -3,340.16 5,950,642.94 555,342.45 0.00 5,055.52 11,500.00 89.62 358.73 3,438.24 3,329.24 5,155.50 -3,342.38 5,950,742.88 555,339.45 0.00 5,155.50 11,600.00 89.62 358.73 3,438.90 3,329.90 5,255.47 -3,344.60 5,950,842.83 555,336.45 0.00 5,255.47 11,615.18 89.62 358.73 3,439.00 3,330.00 5,270.65 -3,344.93 5,950,858.00 555,336.00 0.00 5,270.65 1J-170 L2 T2 (wp05) 11,700.00 89.48 358.73 3,439.67 3,330.67 5,355.44 -3,346.81 5,950,942.77 555,333.46 0.17 5,355.44 11,800.00 89.31 358.73 3,440.73 3,331.73 5,455.41 -3,349.03 5,951,042.71 555,330.46 0.17 5,455.41 11,900.00 89.14 358.73 3,442.08 3,333.08 5,555.38 -3,351.25 5,951,142.64 555,327.46 0.17 5,555.38 12,000.00 88.97 358.73 3,443.72 3,334.72 5,655.34. -3,353.47 5,951,242.58 555,324.46 0.17 5,655.34 12,015.43 88.95 358.73 3,444.00 3,335.00 5,670.77 -3,353.82 5,951,258.00 555,324.00 0.17 5,670.77 1J-170 L2 T3 (wp05) 12,100.00 88.79 358.73 3,445.67 3,336.67 5,755.30 -3,355.69 5,951,342.50 555,321.46 0.19 5,755.30 I 12,200.00 88.60 358.73 3,447.95 3,338.95 5,855.25 -3,357.91 5,951,442.42 555,318.46 0.19 5,855.25 12,300.00 88.41 358.73 3,450.56 3,341.56 5,955.19 -3,360.13 5,951,542.33 555,315.47 0.19 5,955.19 12,400.00 88.22 358.73 3,453.51 3,344.51 6,055.12 -3,362.35 5,951,642.24 555,312.47 0.19 6,055.12 12,415.78 88.19 358.73 3,454.00 3,345.00 6,070.89 -3,362.70 5,951,658.00 555,312.00 0.19 6,070.89 1J-170 L2 T4 (wp05) 12,500.00 87.64 359.16 3,457.07 3,348.07 6,155.04 -3,364.24 5,951,742.13 555,309.80 0.83 6,155.04 12,600.00 86.98 359.67 3,461.76 3,352.76 6,254.92 -3,365.26 5,951,841.99 555,308.00 0.83 6,254.92 12,700.00 86.33 0.19 3,467.60 3,358.60 6,354.75 -3,365.38 5,951,941.80 555,307.10 0.83 6,354.75 12,736.28 .86.09 0.37 3,470.00 3,361.00 6,390.95 -3,365.20 5,951,978.00 555,307.00 0.83 6,390.95 L2 : BHL @ 12736ft MD, 3470ft TV D : 2913ft FSL & 568ft FE L -Sec 27 - T11 N - R10E - 41/2" -1J-170 L2 T5 Toe (wp05) 4/10/2006 12:30:OOPM Page 4 of 6 COMPASS 2003.11 Build 50 • s ~.41"14CU~''~f~l~S Alaska Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-170 Wellbore: 1J-170 L2 Design: 1J-170 L2 (wp05) Halliburton Energy Services ~ E ~ ,_~ Planning Report -Geographic ~ -- ----~- Sperry ©rifling Serwiaes Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minirnum Curvature Geologic Targets 1J-170 L2 TVD ~~r~f ~dar~r= +NI-S +E/-W Northing Easting 3,414.00 1J-170 L2 T1 {vrp05} 1,960.56 -3,033.73 5,947,550.75 555,672.97 - Point 3,470.00 1J-176 L2 T5 Toe (wp45} 6,390.95 -3,365.20 5,951,978.00 555,307.00 - Point 3,444.00 1J-170 L2 T3 {wp05} 5,670.77 -3,353.82 5,951,258.00 555,324.00 - Point 3,454.00 1J-970 L2 T4 {wp05} 6,070.89 -3,362.70 5,951,658.00 555,312.00 - Point 3,347.00 1J-170 L2 DD Poly -129.10 -3,464.05 5,945,458.00 555,259.00 - Polygon Point 1 -50.00 0.39 5,945,458.00 555,209.00 Point 2 -50.04 12.12 5,945,469.73 555,208.87 Point 3 -50.15 41.57 5,945,499.17 555,208.53 Point 4 -26.22 318.36 5,945,776.12 555,230.30 Point 5 -8.94 399.29 5,945,857.17 555,246.95 Point 6 345.76 1,810.78 5,947,271.25 555,590.60 Point 7 380.32 2,090.05 5,947,550.75 555,622.97 Point 8 348.32 2,438.24 5,947,898.65 555,588.26 Point 9 133.90 3,594.72 5,949,053.31 555,364.85 Point 10 102.36 3,900.55 5,949,358.85 555,330.93 Point 11 69.12 5,400.14 5,950,858.00 555,286.00 Point 12 60.24 5,800.26 5,951,258.00 555,274.00 Point 13 51.36 6,200.38 5,951,658.00 555,262.00 Point 14 48.85 6,520.44 5,951,978.00 555,257.00 Point 15 148.86 6,519.66 5,951,978.00 555,357.00 Point 16 151.36 6,199.60 5,951,658.00 555,362.00 Point 17 160.24 5,799.48 5,951,258.00 555,374.00 Point 18 169.12 5,399.36 5,950,858.00 555,386.00 Point 19 202.36 3,899.77 5,949,358.85 555,430.93 Point 20 233.90 3,593.94 5,949,053.31 555,464.85 Point 21 448.32 2,437.46 5,947,898.65 555,688.26 Point 22 480.32 2,089.27 5,947,550.75 555,722.97 Point 23 445.77 1,810.00 5,947,271.25 555,690.60 Point 24 91.07 398.51 5,945,857.17 555,346.95 Point 25 73.79 317.58 5,945,776.12 555,330.30 Point 26 49.85 40.79 5,945,499.17 555,308.53 Point 27 49.96 11.34 5,945,469.73 555,308.87 Point 28 50.00 -0.39 5,945,458.00 555,309.00 3,439.00 1J-170 L2 T2 {wp05} 5,270.65 -3,344.93 .5,950,858.00 555,336.00 - Point 4/10/2006 12:30:OOPM Page 5 of 6 COMPASS 2003.11 Build 50 ~~~`~~t . ~ , CC)1"tClCQ~I"ti~~f pS Air:>~ Database: EDM 2003.11 Single User Db Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Site: Kuparuk iJ Pad Well: Plan 1J-170 Wellbore: 1J-170 L2 Design: 1J-170 L2 (wp05) Prognosed Casing Points • Halliburton Energy Services Planning Report -Geographic - Sperry Or311ing services Local Co-ordinate Reference: Well Plan 1J-.170 -Slot 1J-170 TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) North Reference: True Survey Calculation Method: Minimum Curvature Measured Vertical Casing Hole Depth Depth Diameter Diameter lft) (ft) (") C') so.oo 80.00 Zo zo 3,018.00 2,145.00 10-314 13-1/2 6,138.33 3,347.00 7-5/8 9-7/8 12,736.27 3,470.00 4-1/2 6-3/4 4/10/2006 12:30:OOPM Page 6 of 6 ~~~~~ 4 COMPASS 2003.11 Build 50 • Conoc~Phillips Alaska • ConocoPhillips Alaska (Kuparuk) Kuparuk River Unit Kuparuk 1J Pad Plan 1J-170 1J-170 L2 1J-170 L2 (wp05) Anticollision Report 10 April, 2006 j s~e~ ~ril~n~ secs SURVEY PRl)GRAM Date: 20060408700:00:00 Validated: Yes Version: Dep[h From Depth To Survey/Plan Tool 28.00 800.00 CB-GYR0.SS 800.00 6138.32 MWD+IFR-AK-CAZSC 613832 12736.28 1J-170 L2 (wp05) N1WD*IFR-AK-CAZHC 0 Scan Method: Trev. Cylinder North Error Surface: Elliptical Conic Warning Method: Rules Based 30- 330 30 25 2 300 60 1 1 90 5 1 15 240 120 "~~, 20 25 From Colour To MD 210 - 150 12 30 240 120 0 6000 180 - 6000 6250 Travelling Cylinder Azimuth (TFO+AZ[) ~°] vs Centre to Centre Separafion [15 fUin] 16 6250 6500 6500 6750 6750 7000 20 7000 °°°° 7250 SECTION DETAILS --- 7250 7500 210 - 150 7500 7750 Sec MD Inc Azi ND +NIS +EI-W DLeg TFace VSec Target - 1 6138.32 77.00 359.79 3347.00 -029.11 3464.05 0.00 0.0000 -129.11 - 240 7750 8000 2 6150.32 78.91 359.79 3349.50 -117.37 -3464.10 15.90 0.0000 -117.37 -- - 8000 8250 3 6180.32 78.91 359.79 3355.28 -87.93 -3464.21 0.00 0.0000 57.93 4 6460.53 88.58 10.00 3385.85 188.87 .9440.27 5.00 47.0487 188.87 8250 8500 5 6543.31 89.11 14.11 3387.53 269.80 -3422.99 5.00 82.7155 269.80 180 8500 8750 6 7998.87 89.11 14.11 3410.18 1681.29 3068.29 0.00 0.0000 1681.29 7 8281.01 89.35 0.00 3414.00 1960.56 -3033.73 5.00 59.1175 1960.56 1Jd70 L2 T1 (wp04) 8750 9000 8 8631.17 89.54 349.50 3417.40 2308.75 .9065.74 3.00 59.0063 2308.75 9000 9250 9 9807.39 89.54 349.50 3426.80 346522 3280.16 0.00 0.0000 3465.22 10 10115.18 89.62 358.73 3429.05 3771.05 3311.69 3.00 89.5512 3771.05 Travelling Cylinder Azimuth (TFO+AZn [°] vs Centre to Centre Separation [100 ft/in] 9250 9500 ~ 12 72 1 9500 9750 015.43 88.95 358.73 3444.00 5670.77 J3 82 13 12415.78 88.19 358.73 3454.00 6070.89 -3362.70 0.1 F779.738 5670.77 1J-170 L2 T3 (wp04) 0.19179.7685 6070.89 1J-170 L2 T4 (wp04) 9750 1000 14 1273628 86.09 0.37 3470.00 6390.95 -3365.20 0.83142.0133 6390.95 1J-170 L2 T5 Toe (wp04) 10000 1025 10250 1050 10500 1075 10750 1100 REFERENCE INFORMATION 11000 1125 Co-ordinate (WE) Reference: V Well Plan 1J-170-Slot 1J-170, True North 11250 1150 ertical (ND) Reference: Section (VS) Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Slot -1J-170(O.OON, O.OOE) 11500 11750 Measured Depth Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) 11750 13000 Calculation Method: Minimum Curvature NAD 27 ASP Zone 4: WELL DETAILS: Plan 1J-170 ConocoPhillips Alaska (Kuparuk) ANTI~COLLISION SETTINGS Ground Level: 81.00 Drilling 8 Wells Interpolation Method: MD Interval: SOStations +NIS +EI-W Northing Easting Latittude Longitude Slot West Sak Depth Range From: 6138.32 To 12736.2791620847 0.00 0.00 5945614.10 558721.61 70°75'43.258N 149°31'31.065W 1J-170 Maximum Range:1470.82791620847 Calculation Method: Minimum Curvature Reference: Plan: 1J-170 L2 (wp05) Enor System: ISCWSA r1 LJ .~ Cc~r~c~cc~~~Iw~ Al~sk~ Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error. O.OOft Reference Well: Plan 1J-170 Well Error. O.OOft Reference Wellbure 1J-170 L2 Reference Design: 1J-170 L2 (wp05) r~ ~~ Halliburton Energy Services ~~~~ Anticollision Report --~ ~~s~ t~ritl[n~ Serwic~s Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 1J-170 -Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81)) Planned RKB @ 109.OOft (Doyon 141 (28+g1)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Reference 1J-170 L2 (wp05) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of referen Interpolation Method: MD Interval 50.OOft Error Model: ISCWSA Depth Range: 6,138.32 to 12,736.28ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,470.83ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program Date 1,102006 From To (ft) (ft) Survey (Wellbore) 28.00 800.00 1J-170 (wp05) (1J-170) 800.00 6,138.32 1J-170 (wp05) (1J-170) 6,138.32 12,736.28 1J-170 L2 (wp05) (1J-170 L2) Tool Name Description CB-GYRO-SS camera based gyro single shot MWD+IFR-AK-CAZ-SC MWD+IFR AKCAZSCC MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 12:27:39PM Page 2 of 6 COMPASS 2003.11 Build 50 ORIGINAL C] • -' ~ ~ ~~ Halliburton Energy Services .._ ~e. ~~ ~~~ ~~ ~~~ Alaska Anticollision Report .......... Spumy Drilling Services Company: ConocoPhillips Alaska (Kuparuk) Local Co-ordinate Reference: Well Plan 1J-170 -Slot 1J-170 Project: Kuparuk River Unit TVD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Reference Site: Kuparuk 1J Pad MD Reference: Planned RKB @ 109.OOft (Doyon 141 (28+81)) Site Error: O.OOft North Reference: True Reference Well: Plan 1J-170 Survey Calculation Method: Minimum Curvature Well Error: O.OOft Output errors are at 2.00 sigma Reference Wellbore 1J-170 L2 Database: ' EDM 2003.11 Single User Db Reference Design: 1J-170 L2 (wp05) Offset TVD Reference: Reference Datum Summary Site Name Offset Well -Wellbore -Design Kuparuk 1 J Pad 1J-10 - 1J-10 - 1J-10 1J-159 - 1J-159 - 1J-159 iJ-159 - 1J-159 L1 - 1J-159 L1 1J-159 - 1J-159 L1 P61 - 1J-159 L1 PB1 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 P62 1J-159 - 1J-159 L2 - 1J-159 L2 1J-159 - 1J-159 PB1 - 1J-159 P61 1J-164 - iJ-164 - 1J-164 1J-164 - 1J-164 L1 - 1J-164 L1 1J-164 - 1J-164 L2 - 1J-164 L2 1J-164 - 1J-164 L2 PB1 - 1J-164 L2 PB1 iJ-166 - 1J-166 - 1J-166 1J-166 - 1J-166 L1 - 1J-166 L1 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 PB1 1J-166 - 1J-166 L2 - 1J-166 L2 1J-166 - 1J-166 L2 PB1 - 1J-166 L2 PB1 1J-168 - 1J-168 - 1J-168 1J-168 - 1J-168 L1 - 1J-168 L1 1J-168 - 1J-168 L2 - 1J-168 L2 1J-168 - 1J-168 L2 P61 - 1J-168 L2 PB1 Plan 1J-115 -Plan 1J-115 - 1J-115 (wp02) Plan 1J-118 -Plan 1J-118 -Plan 1J-118 (wp01} Plan iJ-120 -Plan 1J-120 - 1J-120 (wp01) Plan 1J-122 -Plan 1J-122 - 1J-122 (wp02) Plan iJ-123 Kuparuk Prelim - 1J-23 E Lat - 1J-23 E Plan 1J-123 Kuparuk Prelim - iJ-23 Pilot - 1J-23 Pil Plan 1J-123 Kuparuk Prelim - 1J-23 W Lat - 1J-23 Plan iJ-124 -Plan 1J-124 - iJ-124 (wp01) BHI Plan 1J-127 -Plan 1J-127 - 1J-127 (wp03) Plan 1J-127 -Plan 1J-127 L1 - 1J-127 L1 (wp03) Plan 1J-127 -Plan 1J-127 L2 - 1J-127 L2 (wp03) Plan 1J-129 (013 Phase 2) -Plan 1J-129 - 1J-129 I Plan 1J-130 -Plan 1J-130 - 1J-130 (wp02) Plan 1J-132 (012 Phase 2) -Plan 1J-132 - 1J-132 I Plan 1J-150 (Ugnu Disposal) -Plan 1J-UgnuDispos Plan 1J-156 - 1J-156 - 1J-156 (wp04) Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp04) Plan 1J-156 - 1J-156 L2 - 1J-156 L2 (wp04) Plan 1J-158 - 1J-158 - 1J-158 (wp03) Plan 1J-160 -Plan 1J-160 - 1J-160 (wp01) BHI Plan 1J-162 - 1J-162 - 1J-162 (wp03.1-North Heel) Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp3.1) Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp3.1) Plan 1J-170 - 1J-170 - 1J-170 (wp05) Plan 1J-170 - 1J-170 L1 - 1J-170 L1 (wp05) Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E Lal Plan 1J-173 Kuparuk- 1J-73 Kuparuk- 1J-73 W La Plan 1J-173 Kuparuk- 1J-73 Pilot- 1J-173 Pilot (wF Plan 1J-174 (01 Phase 2) -Plan 1J-174 - 1J-174(w Plan iJ-176 (02 Phase 2) -Plan 1J-176 - 1J-176 (v Plan 1J-178 (03 Phase 2) -Plan iJ-178 - 1J-178 (v WSP-04 -WSP-04 -WSP-04 Reference Offset Centre to Measured Measured Centre Depth Depth Distance (ft) (ft) (ft) 8,115.48 5,250.00 200.32 8,253.46 5,400.00 1,031.24 .131..94.. . .900.59 8,253.48 5,400.00 1,031.26 131.80 900.74 8,253.48 5,400.00 1,031.26 132.51 900.03 8,199.97 5,250.00 1,042.30 131.18 912.91 8,199.97 5,250.00 1,042.30 130.47 913.62 12,736.28 12,995.00 1,296.59 223.55 1,075.40 6,153.10 6,450.00 1,183.93 119.03 1,084.03 6,153.10 6,450.00 1,183.93 119.63 1,083.44 6,153.10 6,450.00 1,183.93 119.61 1,083.45 9,873.52 5,721.67 459.92 183.15 281.24 6,160.42 4,150.00 1,073.23 105.91 995.10 6,160.42 4,150.00 1,073.23 105.90 995.10 6,160.42 4,150.00 1,073.23 105.90 995.10 6,751.37 4,950.00 853.90 113.93 743.79 6,319.86 4,800.00 1,259.30 112.76 1,148.53 6,199.93 6,199.98 1.71 4.25 -2.09 6,199.93 6,199.98 1.71 4.25 -2.09 No-Go Allowable Distance Deviation (ft) from Plan (ft) 122.99 86.32 Warning Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range .Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Out of range Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Pass -Major Risk Out of range Out of range Out of range FAIL -Major Risk FAIL -Major Risk Out of range Out of range Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 12:27:39PM Page 4 of 6 COMPASS 2003.11 Build 50 eR!~iNp.~ • ~c~ne~C ~lili~s tll ~ska Company: ConocoPhillips Alaska (Kuparuk) Project: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Site Error. O.OOft Reference Well: Plan 1J-170 Well Error: O.OOft Reference Wellbare 1J-170 L2 Reference Design: 1J-170 L2 (wp05) • Halliburton Energy Services . ~~ Anticollision Report - ---~------- - -- Sperry Drrlimg Servrce~ Local Co-ordinate Refere~7ce TVD Reference: MD Reference: North Reference: Survey Calculation Method: Output errors are at Database: Offset TVD Reference: Well Plan 1J-170- Slot 1J-170 Planned RKB @ 109.OOft (Doyon 141 (28+81 )) Planned RKB @ 109.OOft (Doyon 141 (28+81)) True Minimum Curvature 2.00 sigma EDM 2003.11 Single User Db Reference Datum Summary Site Name Offset Well - Wellbore -Design Kuparuk 1J Pad WSP-05 -WSP-05 -WSP-05 WSP-06 -WSP-06 -WSP-06 WSP-07 -WSP-07 -WSP-07 WSP-08 -WSP-08 -WSP-08 WSP-20 -WSP-20 -WSP-20 Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Depth Depth Distance (ft) from Plan (ft) (ft) (ft) (ft) Out of range Out of range Out of range Out of range Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 4/10/2006 12:27:39PM Page 5 of 6 COMPASS 2003.11 Build 50 ~ ~ t ~~ ~~~b_ 1J-17OI~Drilling Hazards~ummarv (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Ouen Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheolo y, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets), umpin out, backreamin 1J-170L2 Drilling Hazards Summary prepared by Shane Cloninger ~ 3/20/2006 1:33 PM ~-~~ 5 s"e":~" ' _ '~. 20" 91.5# x 34" Insulated Conductor, K-55, set at +/. 80' 11" x 5" Vetco Gray MB 228 Wellhead 10-3/4", 45.5#, BTC ~ ~ ~~ S ' hoe set @ 3018 MD, ' o, 2145 TVD, 66 deg \` .• Tubing String , ~l} ;+` 4-1 /2" 12.6#, L-80, IBTM Y \ .~ 3.958" ID, 3.833" Drift \~ \ 5-1/2" X 7-518" ZXP Liner / Top Packer w/ Hoid Seal Assembly Downs 4.75" Seal OD , Tubing, Special Drift to +/- 500' MD 3.875" DB Nipple, for Possible SSSV GLM, Camco KBG-2, 4.1/2" X 1" GLM, Camco KBG-2, 4.1/2" X 1" ~c~nt~CO~~ips West Sak 7-5/8"Injector 1 J -170 Tri-Lateral Completion CMU Sliding Sleeve, w/ 3.81" DB Nipple ~ Casing Sealbq£e.Rec~ptacle, 20' Length Lateral Entry Module(LEM) D-sand Window 'D' Sand Lateral /at 6138' MD, 3347 TVD ` 4.112" 11.6# L-80 Slotted Liner Swivel 3-1/2" Bent Joint Liner Every Other Joint - ~T~;-. __ { , 3-112" Guide Shoe ~r""'~ -"-~ + 4.112" Liner Shoe, 11.6#, L Set @ 12736' MD, 3470' Seal Assembly / 4.75" Seal OD ~ \ ,~ ~11 r, ~ "'7 BAKER NY6XES Baker Oil Tools Lateral Entry Module (LEM With Diverters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool String Installed Installed (3.00" Latera l Drill) (2.50" ID Mainbore Drift) ~ { 'GS' Profile for ¢ '-- Coil Connector 4`-'v (1.00' Length) I RunninglRetrieving ti I;. ~/ {\] 4 1 1 - S Snap InlSnap Out I '. ~ reack Pressure.Valve dPOSitive Lowtingti ll '. (1.60' Length) I i Collet I i N ~ ~ ~ I r Flow-Thru Swivel jj Latemllsolation ~~ ~ ~ (1.25' Length) 1 ~ Seals ~ - ( Lateral Diverter ~` / _ :I . ~/ Hydraulic ' ~ Ramp ~ Diswnnect (1.60' Length) \' ~ `~. IsolatioN Mainbore I fl ~ - r~ GS Spear ~ (1 50'L th Diverter Sleeve ~ i~~ L t ~~ . eng ) ~ a eral lsola0on Seals 6.85 ft Approx OAL` ~ `Jars may be required in highly deviated ~ ~ 18.5' ' Diverter Length 18.5' Sleeve Len th 0 L ' or deep applications (fi approx length). r 4-1/2" X 7518" Sal Bores Model'B' H_ OOK Hanorr 8" ID 5-1/2" X 7-518" ZXP L e t Packer w/Hold Downs Lateral Entrv Module (LEM Assam .--- 5.1/2" X 7-5/8" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile 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 4.75" Seal OD 3.875" Seal ID • ~ Liner Every Other Joint 3-1/2" Bent Joint I. 4.1/2" X 7-518" - ~~ ~ - _~r-„ y, , ~,-, r ~fi_,» _~ 3.1/2" Guide Shoe Model 'B' HOOK Hanger ~ '" ~~ ~" - ~ . , . ~~ i-} ~ Lateral Entry Module(LEM) t B-sand Window Casing Sealbore -~4 i r Receptacle ` at 6584' MD, 3434'TND 'B Sand Lateral 20' Length ~ 4-1/2" 11.6# L-80 Slotted Liner Swivel -~)~-•-~• -~ - °~ -~ 4.1/2" Liner Shoe, 11.6#, L-80 BTC Seal Bores ~ ~ ~ Set @ 12649' MD, 3525' TVD 3.68" ID 3.582" DB Nipple 4112" 12.6# Tubin ~ 3.833" Ddit ~~~ 3.956"ID y '~ 5-112" X 7-518" ZX~ ~'? ~~ ,',, Liner Top Packer..`\~ with Hold Downs / ~ 3.1/2" X 7-5/6" ~ \ Liner Hanger /Packer Assembly at Flex Lock +/.6684' MD Liner Hanger /~~ Casing Sealbore Receptacle, 20'Length Eauipment Saecifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5,32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/ diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 8.75" 4-1/2" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drift, w/ coil diverter: 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +1.18.5' "'" ~ 4-1 /2" Casing Shoe, 11.6#, L-80 BTC ~""`~"'"~'~.-_..,,_%~4 .~ Set @ 12508' MD, 3643' TVD 7-5/8" Casing, L-80, BTCM, Set at b Baker Hughes 2006. This document may not be reproduced or tlieMbuted, In whole or In part, In any roan or @ 7681' MD, 3619' TVD (85 deg) y anymeana electronic or meehanleai, Including photocopying, recording, or by any informatton storage and retrieval system now known or hemaTter Invented, wiNout written permiss(on from Baker Hughes Inc. Seal Assembly 4.75" Seal OD `A' Sand Undulating Lateral 4112" 11.6# L-80 Slotted `,. Liner Every Other Joint 41/2"Eccentric '~ ,A1 / ~GuideShoe ~~°~~ •<i. 1 ...Jd .. ..... .. C] • • TRANSMITTAL LETTER CHECKLIST WELL NAME /~/21.~ ~•7- ~ 7d L 2- PTD# Za~-o~ ~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well l~~ ~.- / ~ " ~ ~ y ' . / V (If last two digits in API b PerrPit Np,~~oZD, API No. 50-~ ~3 /h - Da, num er are ~~R between 60-69) should continue to be reported as a function of the or'ginal API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well] until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCompany NameZmust contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1 /25/06 C:\j ody\transmittal_checkl ist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAKOlL-490150 Well Name: KUPARUK RIV U WSAK 1J-170L2 Program SER Well bore seg^ PTD#:2060640 Company CONOCOPHILLIPS ALASKA INC Initial Class/Type SER / PEND GeoArea 890 Unit 11160 OnlOff Share On Annular Disposal ^ Administration 1 Permitfee attached- NA_ _ - _ West Sak D Sand multilateral well branch; fee waived per 20 AAC 25.005(e). 2 Lease number appropriate_ _ - - Yes - - - - Top_productive interval and TD_in ADL 025$60. - - - _ - . - - 3 Unique well-name andnumher----------------------------- ---------yeS- ------ -------------------------------------------------------------------- 4 Well located in a_defined_pool _ _ - ---------------- Yes _ ------ - _ - Kupa[uk River, West-Sak Oil Pool - 490150, _ goyemed-by_CO 4066_ - - _ - . - _ . - ---------------- 5 Well located proper distance from drilling unit-boundary- - - - _ - - - _ _ - - - - . - Yes - - - - - Well is more_ than-500 feet from an external proper~r line- - - - - - - - - - - - - - - - - - - 6 Well located proper distance f[om other wells- _ - _ _ - - - _ - Yes - - _ - . CO 4066, Rule 3; no restrictions as_to well spacing exce i that no_ a shall be o _ened (n a well closer p pY P 7 Sufficient acreage ayail_able in drilling un~- . - - _ - . Yes - _ than 500 feet to-an external_prope[ty line where ownership or landowne[ship changes, 8 Ifdeviated,is-wellboreplat_included________________ Yes- _______-----______-----______------- - 9 Operator only affected party - - - - - Yes - ----------------------------------------- 10 Operator has.appropriate_bond(nforce------------------------ ---------Yes- --------------------------------------------____-- 11 Permitcan be issued without conservation order- _ - - - _ . - - Yes - - - - - Appr Date 12 Pe[mit_canbeissuedwithoutadministrative-approval______--___-___ __--.---Yes- -------------------------------------- SFD 5!1212006 13 Can permit be approved before 15-day wait Yes 14 Well located w(th-in area and_strata authorized by-Injection Order # (put Ip# in_comments)-(FOr_ Yes - - _ _ _ _ _ Area Injection Order No, 2B - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 All wells-within 114_mile area_of review jdent(fied (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - _ - - - _KRU 1J-10,1J-168L2,_1 E-10512_(toe). See diagrams and calculations in-PTD 2060620._ - _ _ _ _ _ _ ----- -- 16 Pre-produced injector; duration of pre production Less than_ 3 months_(For_seruice well only) Yes _ - _ David_Nugent, CPAI,-5/16106; This well will-be flowed_ back for 30 days for clean-up, . ACMP_Finding of Consistency.has been issued for_thisproject- _ _ - NA_ ACMP determin_ation_n_o longer-affects AOGCC apRroval-of perms to drill-- - - - - - - - - - - - - - Engineering 18 _C_ondu_ct_orstring_provided _ - . _ _ - - - - NA_ Conductor set-in motherbore,-1J-170 (206.062).- - - _ - - . _ - - 19 Surface casing_proteotsallknown_USDWs______________________ _________ NA__- --_ _Allaquifersexempted,40CFR_147.102_(b)(3).__--____________--_--__________.-_- _ 20 CMT vol adeguale_to circul_ate_on conductor-& su_rf_csg - - - - - - - NA- _ _ Surface casing set in 1_J-170._ _ - _ _ - - -- 21 CMT_v_ol_adequate-totie-(nlong string to surf csg- - _ . _ _ - - NA_ _ _ - _ . Production-eosin set in-1J-170. _ _ - _ _ - - 9- - - 22 CMT.will coverall know_n_productiye horizons_ _ - - - - - - - - - - - - - No- Slotted liner completion planned, _ - - - - _ _ - - 23 Casing designs adequate to[ C, T, B &_permafrost- - - _ - _ Yes - _ _ _ - Motherbore meets design requirements. NA-for_slotted liner. _ . - - 24 Adequate tan_kage_or reserve pit - - - - - - _ ------------ Yes --- Rig is_equipped with steelpits. No resen!e_p_itplanned, All waste to approved annulus.ordisposal wel_IS. - . - - - - 25 Ifa-re-drill,has_a_10-403 for abandonment been approved------------- - NA--_ -- ___-_________---__------.- - - - 26 Adequate wellbore separationproposed _ - _ _ _ - _ _ - - - - - - - - - - - - - - - - - - -Yes _ _ _ _ _ - _ Proximity analysis performed, Ne rest well segment is 1J-170L1-~ 100' tyd below. _ _ - _ - - - - _ 27 If dwerter required, does d meet regulations- _ . _ - - _ ~~ _ _ _ _ ~R 12A? s~~~~i1~g\~~~~ ~ ~~~~ ~?*~~ ' Appr Date 28 Dnlhn fluid- ro ram schematic & eqm list adequate_ 9 P q _ _ p _ _ Yes - _ r - ~ ~^ ~~~ _ _ - .Maximum expected f_o[mation pressure 8.7-EMW._ Planned MW $:8-ppg. _ _ _ _ - - - _ _ _ - - _ _ _ _ _ _ . TEM 5/2512006 29 B_OPEs,dotheymeetregulation_______________-_-----_-_- -__--- .-Yes >~ 30 BOPE_press rating appropnate; test to (put prig mcomments)- __ Yes ____----_____ MASP calculated at 1180psi. 3K stack arrangement and BOP test planned. _ - - _ - - 31 Choke_manifoldcomplieswlAPLRP-53 (May 84) -_-___------_ ___---.--Yes__ _______________ - - - 32 Work willoccurwithoutoperationshutdown---------------------- ---------Yes__ --_____-----__--__-______--__-__--_- 1 33 Is presence-of H2Sgos-probable _ - - - - - - _ - - - No- - _ - - H2S has not_been reported on 1J pad, Riq is equipped with sensors and alarms. _ - - _ - 34 Mechanical condition of wells within AOR verified (Fors_enrice wel_I onlya _ _ _ _ - - -Yes 1 J-10-and 1J-168_satisfacto_rily cemented. Other aRRroa_ches within zone, _ - . - _ . - Geology 35 Permitc_an be issued wlo hydrogen_sulfide measures - - . - _ - _ _ - - - Yes None expected._ Rig has sensors and_afarms. _ - _ - - - _ _ 36 Data-presented on_ potential overpressure zones _ - _ - - - Yes Expected res._pressure is ~8Jppg EMW; will be drilled with 8.8 ppgoil-based mud, - - - - _ Appr Date 37 Seismic analysis-of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ - NA - SFD 5!1212006 38 Seabed condition survey-(if off-shore) _ - NA - - - ----------------------------- - 39 Contact namelphone for weekly_progress reports [exploratory only] _ - _ _ - - NA- - - Geologic Commissioner: Engineering tic Date: D ate Co mmission r : e i i Date West Sak D sand in ector. This is one of the well branches from tri-lateral induction well KRU 1J-170. SFD 1 P nner s % m ~ j , ~ ~ ~ ~ ( r ~~ • • • Well History File APPENDIX Information of detailed nature that is not particularly germane io the WeN Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of tl~e file under APPENDIX. No special effort has been made io chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Jul 18 14:37:42 2006 Reel Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF • Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1J-170 L2 API NUMBER: 500292331061 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 18-JUL-06 JOB DATA MWD RUN 3 MWD RUN 13 MWD RUN 14 JOB NUMBER: W-0004406587 W-0004406587 W-0004406587 LOGGING ENGINEER: P. ORTH T. GALVIN P. ORTH OPERATOR WITNESS: M. THORNTON M. THORNTON M. THORNTON SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1802 FEL: 2490 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 109.00 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3041.0 2ND STRING 6.750 7.625 6409.0 3RD STRING PRODUCTION STRING REMARKS: 1. 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 WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 6409' MD/3401'TVD, WITHIN THE RUN 3 INTERVAL OF THE 1J-170 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW MILLED, AND 30' OF RAT HOLE WERE DRILLED DURING MWD RUN 13. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUNS 1,2 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 3,14 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 14 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. 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. 7. MWD RUNS 1-3,13,14 REPRESENT WELL 1J-170 L2 WITH API#: 50-029-23310-61. THI WELL REACHED A TOTAL DEPTH (TD) OF 12678'MD/3499'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY ~ PBU TOOL CODE START H STOP DEPTH GR 3004.0 12620.5 FET 3020.0 12627.5 RPD 3020.0 12627.5 RPS 3020.0 12627.5 RPM 3020.0 12627.5 RPX 3020.0 12627.5 ROP 3050.5 12678.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 3 3004.0 6409.0 MWD 13 6409.5 6452.0 MWD 14 6452.0 12678.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth 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 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 3004 12678 7841 19349 3004 12678 RPD MWD OHMM 0.63 2000 58.6703 19216 3020 12627.5 RPM MWD OHMM 1.33 1392.15 46.6436 19216 3020 12627.5 RPS MWD OHMM 1.43 246.54 46.7435 19216 3020 12627.5 RPX MWD OHMM 4.84 2000 44.0636 19216 3020 12627.5 FET MWD HOUR 0.17 468.41 1.52141 19216 3020 12627.5 GR MWD API 20.08 124.01 66.3281 19234 3004 12620.5 ROP MWD FT/H 0.14 547.4 9 183.853 19256 3050.5 12678 First Reading For Entire File..........3004 Last Reading For Entire File...........12678 File Trailer Service name .............STSLIB.001 Service Sub Level Name.. Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3004.0 6409.0 FET 3020.0 6409.0 RPX 3020.0 6409.0 RPS 3020.0 6409.0 RPM 3020.0 6409.0 RPD 3020.0 6409.0 ROP 3050.5 6409.0 LOG HEADER DATA DATE LOGGED: 02-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6409.0 TOP LOG INTERVAL (FT) 3050.0 BOTTOM LOG INTERVAL (FT) 6409.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 63.1 MAXIMUM ANGLE: 86.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 9.875 DRILLER'S CASING DEPTH (FT) 3041.0 BOREHOLE CONDITIONS MUD TYPE: Lignosulfonate MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S) 63.0 MUD PH: 9.3 ~ MUD CHLORIDES (PPM): 150 FLUID LOSS (C3) 5.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT) 3.650 70.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.910 89.6 MUD FILTRATE AT MT: 3.600 70.0 MUD CAKE AT MT: 3.900 70.0 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 Logging Direction ............ .....Down Optical log depth units...... .....Feet Data Reference Point ......... .....Undefined Frame Spacing ................ .....60 .12N Max frames per record ........ .....Undefined Absent value ................. .....-999 Depth Units..... ........... ..... Datum Specification Block sub -type...0 Name Service Order Units Size N sam 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 MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3004 6409 4706.5 6811 3004 6409 RPD MWD030 OHMM 0.63 2000 19.6826 6779 3020 6409 RPM MWD030 OHMM 1.33 1392.15 13.1028 6779 3020 6409 RPS MWD030 OHMM 1.43 59.97 12.4889 6779 3020 6409 RPX MWD030 OHMM 4.84 56.39 11.801 6779 3020 6409 FET MWD030 HOUR 0.17 52.29 1.06288 6779 3020 6409 GR MWD030 API 20.08 124.01 68.0886 6811 3004 6409 ROP MWD030 FT/H 2.9 547.49 199.244 6718 3050.5 6409 First Reading For Entire File..........3004 Last Reading For Entire File...........6409 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 ~ • Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 6409.5 6452.0 LOG HEADER DATA DATE LOGGED: 20-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 6452.0 TOP LOG INTERVAL (FT) 6409.0 BOTTOM LOG INTERVAL (FT) 6452.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6409.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.80 MUD VISCOSITY (S) 69.0 MUD PH: .0 MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3) 3.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 72.6 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value........ ............-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD130 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6409.5 6452 6430.75 86 6409.5 6452 ROP MWD130 FT/H 0.14 23.97 8.87477 86 6409.5 6452 First Reading For Entire File..........6409.5 Last Reading For Entire File...........6452 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 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.......06/07/18 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: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6409.5 12627.5 RPD 6409.5 12627.5 RPM 6409.5 12627.5 GR 6409.5 12620.5 . • RPS 6409 12627.5 FET 6409.5 12627.5 ROP 6452.5 12678.0 LO G HEADER DATA DATE LOGGED: 23-JUN-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12678.0 TOP LOG INTERVAL (FT) 6452.0 BOTTOM LOG INTERVAL (FT) 12678.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.5 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 160788 EWR4 Electromag Resis. 4 156401 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 6409.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S): 76.0 MUD PH: .0 MUD CHLORIDES (PPM): 24000 FLUID LOSS (C3) 3.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 118.4 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 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 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth 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 MWD140 OHMM 4 1 68 4 2 ~ RPM MWD140 OHMM 1 68 8 3 RPS MWD140 OHMM 4 1 68 12 4 RPX MWD140 OHMM 4 1 68 16 5 FET MWD140 HOUR 4 1 68 20 6 GR MWD140 API 4 1 68 24 7 ROP MWD140 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6409.5 12678. 9543.75 12538 6409.5 12678 RPD MWD140 OHMM 11.11 296.23 79.9212 12437 6409.5 12627.5 RPM MWD140 OHMM 12.66 155.11 64.9256 12437 6409.5 12627.5 RPS MWD140 OHMM 13.55 246.54 65.4146 12437 6409.5- 12627.5 RPX MWD140 OHMM 10.67 2000 61.6489 12437 6409.5. 12627.5 FET MWD140 HOUR 0.2 468.41 1.77135 12437 6409.5 12627.5 GR MWD140 API 41.85 89.5 65.3629 12423 6409.5 12620.5 ROP MWD140 FT/H 0.4 336.1 176.758 12452 6452.5 12678 First Reading For Entire File..........6409.5 Last Reading For Entire File...........12678 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/07/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Service name .............LISTPE Date .....................06/07/18 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
