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Home My WebLink About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y Meredith Guhl at 12:01 pm, Aug 20, 2021 321-411 Ron Phillips Digitally signed by Ron Phillips Date: 2021.08.20 11:54:27 -08'00' Victoria Loepp 8/13/21 & 8/19/21 BOP test pressure to 3100 psi Annular preventer to 2500 psi X X 10-404 DSR_8/20/21DLB 08/30/2021 VTL 8/31/21 X -00 DLB dts 8/31/2021 JLC 8/31/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.09.02 10:05:15 -08'00' RBDMS HEW 9/2/2021 Ron L Phillips Senior Wells Engineer CPAI Drilling and Wells If you have any questions or require any further information, please contact me at 265-6312. P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2021 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3H-26 (PTD# 194-029). Well 3H-26 was drilled in 1994 by Parker 245 and completed by Nordic 1 as an injector into the A-sands. The C-sands were perforated in 1997. The well was worked over in 2005 by Nordic 2 as a producer. Nabors CDR3 drilled 3 more laterals for this well in 2017. Well 3H-26 was SI on 11/19/2019 for a RWO. Production casing leaks found at 5,145' from 4995 to 5310' on 2/25/2020 8/18/2021. The proposed workover scope for 3H-26 will include pulling the 3-1/2" completion, installing a metal skin patch across the production casing leak at 5,145' MD packer above the leaks and straddling the leaks with 3-1/2" tubing and then installing a new 3-1/2" completion. Ron Phillips Digitally signed by Ron Phillips Date: 2021.08.20 11:55:06 -08'00' Production casing leaks found at 5,145' from 4995 to 5310' on 2/25/2020 8/18/2021. installing a metal skin patch across the production casing leak at 5,145' MD packer above the leaks and straddling the leaks with 3-1/2" tubing an 3H-26 RWO Procedure Kuparuk Producer PTD #194-029 1 Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 3-1/2” completion, patch production casing and install a new 3-1/2” completion. General Well info: Well Type: Producer MPSP: 2,082 psi using 0.1 psi/ft gradient Static BHP: 2,671 psi / 5,915’ TVD (8.7 ppg EMW) measured on 06/10/20 Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed (Tubing and Production casing leaks) MIT-OA PASSED – 06/21/2017 IC POT &PPPOT PASSED – 11/05/2005 TBG POT &PPPOT PASSED – 06/21/2017 Production Engineer: Lynn Aleshire Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. Dummy all GLMs leaving the deepest GLM open as a circulation point. 3. String shot and chem cut tubing at ~6084’MD in the middle of the first joint above the 2-3/8”CTD liner. 4. FT LDS, grease tree valves and set BPV. Workover Procedure 1. MIRU Nabors 7ES on 3H-26. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig tubing cut 6084’MD. 6. Perform a Cleanout run down to 6084’MD. 7. Run test packer /bridge plug combo to verify production casing leak location. 8. Run lower completion and set packer/PBR below casing leak. 9.Run and set casing patch across leak at 5145’ MD. 10.Run and set a packer at 4980', to straddle the casing leaks from 4995' to 5310'. 11. MU 3 ½” completion with GLMs and sting seals into PBR. 12. Once on depth, space out ~3’as needed. 13. Pressure test tubing to 3000 psi for 5 minutes. 14. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 15. Confirm pressure tests, then shear out SOV with pressure differential. 16. Install BPV. 17. ND BOPE. NU tree. 18. Pull BPV, freeze protect well, and set BPV if necessary. 19. RDMO. Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV, ball & rod and run GLD. 4. Handoff to operations to put back on production. VTL 8/31/21 30 min 3H-26 Proposed Schematic w/staddle packerNew 3-1/2" Completion:3-1/2" 9.3# L-80 HYD-563 tubing to surface3-1/2" Camco KBG-2-9 GLM @ 2502', 3408', 4295', 4900'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer @ 4980' (with tubing to straddle casing leaks from 4995'-5310')Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 5,999'Camco D nipple w/plug @ 6,050' MD Baker 3-1/2" GBH-22 seal assembly @ 6113' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified byRLP8/19/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD5-1/2" casing leaks from 4995'-5310' 3H-26 Proposed SchematicNew 3-1/2" Completion:3-1/2" 9.3# L-80 HYD-563 tubing to surface3-1/2" Camco KBG-2-9 GLM @ 2502', 3408', 4295', 5099'Weatherford expandable metal skin patch across 5,145'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 6,053'D-nipple @ 6069' MD (2.75" min ID)Baker overshot bottom @ 6,088'Camco DS nipple w/reducer @ 6,106' MD (1.81" min ID)Baker 3-1/2" GBH-22 seal assembly @ 6114' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified byRLP7/7/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD 3H-26 Proposed SchematicNew 3-1/2" Completion:3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ ~2766', ~4124', ~4988', ~5631', ~6055'Weatherford expandable metal skin patch across 5,145'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 6,053'X-nipple @ 6069'Baker overshot bottom @ 6,088'Camco DS nipple @ 6,106' MD (2.812" min ID)Baker 3-1/2" GBH-22 seal assembly @ 6114' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified by RLP 6/10/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,335.0 11/19/2019 3H-26 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DMY's 9/11/2020 3H-26 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.9 Set Depth (ftKB) 121.0 Set Depth (TVD) … Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.9 Set Depth (ftKB) 3,142.8 Set Depth (TVD) … 3,140.3 Wt/Len (l… 29.70 Grade L-80 Top Thread LTC Casing Description PRODUCTION 5.5x5"@6552' OD (in) 5 1/2 ID (in) 4.28 Top (ftKB) 38.7 Set Depth (ftKB) 6,643.1 Set Depth (TVD) … 6,290.9 Wt/Len (l… 17.00 Grade L-80 Top Thread LTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.8 Set Depth (ft… 6,126.0 Set Depth (TVD) (… 5,793.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.8 HANGER FMC TUBING HANGER 3.500 504.2 NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6 21.13 NIPPLE CAMCO 'DS' NIPPLE 2.812 6,113.2 5,781.1 20.99 LOCATOR BAKER GBH-22 LOCATOR 2.850 6,113.5 5,781.4 20.98 SEAL ASSY BAKER BOT GBH-22 SEAL ASSY 2.85" DRIFT 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,060.0 4,894.9 37.32 LEAK - Production CSG Production casing leak between 5060-5065 4/24/2020 2.992 5,134.5 4,953.5 38.88 PATCH PERM Set Owens X Span permanent patch ( OAL 17.4') 11/23/2020 2.250 5,141.0 4,958.5 39.01 LEAK - TUBING Tubing Leak 7/7/2018 2.992 6,106.0 5,774.4 21.13 NIPPLE REDUCER Set 2.81"D X 1.81"D Nipple reducer 11/22/2020 1.810 6,106.0 5,774.4 21.13 Tubing Plug Set 1.81" CA2 plug in nipple recucer. (24" OAL) 11/23/2020 0.000 6,113.0 5,780.9 20.99 LINER TOP TOP OF L1-02 CTD LINER 8/5/2017 1.920 6,229.0 5,890.1 18.64 WHIPSTOCK BAKER WHIPSTOCK. OAL = 47', OAW 330 LBS, MAX TOOL OD = 2.70, SET WHIPSTOCK 29.4° LEFT OF HIGH-SIDE, TOP OF WHIPSTOCK SET @ 6229' (2 RA TAGS) 7/12/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 4/9/1997 4.0 IPERF 1 11/16" PIVOTS, 180° ph 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 6/15/1998 4.0 RPERF 2 1/8" EnerJet, 0° ph 6,306.0 6,336.0 5,963.4 5,992.2 A-3, A-2, 3H-26 6/24/1994 4.0 IPERF 2 1/8" EnerJet, 90° ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,765.7 2,763.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 2 4,124.4 4,096.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 5/26/2019 3 4,987.6 4,836.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 1/3/2016 4 5,630.9 5,351.9 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 6/30/2005 5 6,055.1 5,727.0 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 Notes: General & Safety End Date Annotation 4/29/2005 NOTE: TREE: FMC 3-1/8"" / GEN IV / 5000 psi rated 3H-26, 11/26/2020 9:17:04 AM Vertical schematic (actual) PRODUCTION 5.5x5"@6552'; 38.7-6,643.1 IPERF; 6,306.0-6,336.0 IPERF; 6,250.0-6,280.0 RPERF; 6,250.0-6,280.0 WHIPSTOCK; 6,229.0 LINER TOP; 6,113.0 SEAL ASSY; 6,113.5 NIPPLE REDUCER; 6,106.0 Tubing Plug; 6,106.0 NIPPLE; 6,106.2 GAS LIFT; 6,055.1 GAS LIFT; 5,630.8 PATCH PERM ; 5,134.5 LEAK - TUBING; 5,141.0 LEAK - Production CSG; 5,060.0 GAS LIFT; 4,987.6 GAS LIFT; 4,124.4 SURFACE; 40.9-3,142.8 GAS LIFT; 2,765.7 NIPPLE; 504.2 CONDUCTOR; 40.9-121.0 HANGER; 37.8 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 3/6/1994 3H-26 ... TD Act Btm (ftKB) 6,660.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020800 Wellbore Status PROD Max Angle & MD Incl (°) 39.20 MD (ftKB) 5,149.90 WELLNAME WELLBORE3H-26 Annotation Last WO: End Date 4/29/2005 H2S (ppm) 200 Date 8/31/2018 Comment SSSV: NIPPLE ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE From:Phillips, Ron L To:Loepp, Victoria T (OGC); AOGCC Permitting (CED sponsored) Cc:Conklin, Amy A; Senden, R. Tyler Subject:RE: [EXTERNAL]Re: KRU 3H-26 (PTD 194-029, Sundry 321-300) Date:Friday, August 27, 2021 12:47:04 PM Attachments:20210827050410.pdf Victoria, Here is the passing 30 minute charted MIT-T 3000 psi pressure test for KRU 3H-26. I am not sure how to properly submit this in Form Tracker and the contractor that submits our paperwork is on vacation. When she gets back in the office I will ask her to properly submit it. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, August 23, 2021 2:54 PM To: Phillips, Ron L <Ron.L.Phillips@conocophillips.com>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: [EXTERNAL]Re: KRU 3H-26 (PTD 194-029, Sundry 321-300) CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Ron, This proposed 30 minute MIT-T will work. However, it does bring up a point. The actual approved sundry with any notes made by the AOGCC does not go to the slope job site? The approved copy is the copy that should be at the jobsite. Victoria Sent from my iPhone On Aug 23, 2021, at 2:25 PM, Phillips, Ron L <Ron.L.Phillips@conocophillips.com> wrote: Victoria, On page 3 of the KRU 3H-26 10-403 Sundry (attached) you crossed out the 5 min tubing pressure test (step 12) and wrote in ‘30 minutes on chart’. I discussed this with the company man two weeks ago, but never sent him an email of the change. He changed out, and the oncoming company man was not informed of the change. I did not talk to the on coming company man about the change and he followed the original procedure. I woke up at 5 am on Sunday and called the rig but they had already sheared the shear out valve in the deepest GLM and they were rigging down off 3H-26. I am sorry, I did not intentionally skip this step. Slickline is going out to KRU 3H-26 this week to pull the SOV, install a dummy valve and pressure test the tubing to 3000 psi for 30 charted minutes with the help of Little Red pump services. I will send in the chart as soon as we get it. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 <3H-26 10-403 RWO Apprvd.pdf> From:Phillips, Ron L To:Loepp, Victoria T (OGC) Cc:Senden, R. Tyler Subject:KRU 3H-26 (PTD 194-029, Sundry 321-300) Date:Monday, August 23, 2021 2:25:06 PM Attachments:3H-26 10-403 RWO Apprvd.pdf Victoria, On page 3 of the KRU 3H-26 10-403 Sundry (attached) you crossed out the 5 min tubing pressure test (step 12) and wrote in ‘30 minutes on chart’. I discussed this with the company man two weeks ago, but never sent him an email of the change. He changed out, and the oncoming company man was not informed of the change. I did not talk to the on coming company man about the change and he followed the original procedure. I woke up at 5 am on Sunday and called the rig but they had already sheared the shear out valve in the deepest GLM and they were rigging down off 3H-26. I am sorry, I did not intentionally skip this step. Slickline is going out to KRU 3H-26 this week to pull the SOV, install a dummy valve and pressure test the tubing to 3000 psi for 30 charted minutes with the help of Little Red pump services. I will send in the chart as soon as we get it. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska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y Samantha Carlisle at 9:42 am, Jun 17, 2021 321-300 Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:34:32 -08'00' X VTL 7/22/21 DSR-6/17/21 10-404 -00 DLB X X BOP test to 2500 psig Annular preventer test to 2500 psig DLB 06/17/2021 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 12:22:33 -08'00' P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2021 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3H-26 (PTD# 194-029). Well 3H-26 was drilled in 1994 by Parker 245 and completed by Nordic 1 as an injector into the A-sands. The C-sands were perforated in 1997. The well was worked over in 2005 by Nordic 2 as a producer. Nabors CDR3 drilled 3 more laterals for this well in 2017. Well 3H-26 was SI on 11/19/2019 for a RWO. Production casing leak found at 5,145' on 2/25/2020. The proposed workover scope for 3H-26 will include pulling the 3-1/2" completion, installing a metal skin patch across the production casing leak at 5,145' MD and then installing a new 3-1/2" completion. If you have any questions or require any further information, please contact me at 265-6312. RRoonn LL PPhhiilllliippss SSeenniioorr WWeellllss EEnnggiinneeeerr CCPPAAII DDrriilllliinngg aanndd WWeellllss Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:33:58 -08'00' The proposed workover scope for 3H-26 will include pulling the 3-1/2" completion, installing a metal skin patch across the production casing leak at 5,145' MD and then installing a new 3-1/2" completion. 3H-26 RWO Procedure Kuparuk Producer PTD #194-029 1 Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 3-1/2” completion, patch production casing and install a new 3-1/2” completion. General Well info: Well Type: Producer MPSP: 2,082 psi using 0.1 psi/ft gradient Static BHP: 2,671 psi / 5,915’ TVD (8.7 ppg EMW) measured on 06/10/20 Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed (Tubing and Production casing leaks) MIT-OA PASSED – 06/21/2017 IC POT &PPPOT PASSED – 11/05/2005 TBG POT &PPPOT PASSED – 06/21/2017 Production Engineer: Lynn Aleshire Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. Dummy all GLMs leaving the deepest GLM open as a circulation point. 3. String shot and chem cut tubing at ~6084’ MD in the middle of the first joint above the 2-3/8” CTD liner. 4. FT LDS, grease tree valves and set BPV. Workover Procedure 1. MIRU Nabors 7ES on 3H-26. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig tubing cut 6084’ MD. 6. Perform a Cleanout run down to 6084’MD. 7. Run test packer /bridge plug combo to verify production casing leak location. 8. Run lower completion and set packer/PBR below casing leak. 9. Run and set casing patch across leak at 5145’ MD. 10. MU 3 ½” completion with GLMs and sting seals into PBR. 11. Once on depth, space out ~3’ as needed. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well, and set BPV if necessary. 18. RDMO. Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV, ball & rod and run GLD. 4. Handoff to operations to put back on production. 30 minutes on chart 3H-26 Proposed SchematicNew 3-1/2" Completion:3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ ~2766', ~4124', ~4988', ~5631', ~6055'Weatherford expandable metal skin patch across 5,145'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 6,053'X-nipple @ 6069'Baker overshot bottom @ 6,088'Camco DS nipple @ 6,106' MD (2.812" min ID)Baker 3-1/2" GBH-22 seal assembly @ 6114' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified by RLP 6/10/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,335.0 11/19/2019 3H-26 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DMY's 9/11/2020 3H-26 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.9 Set Depth (ftKB) 121.0 Set Depth (TVD) … Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.9 Set Depth (ftKB) 3,142.8 Set Depth (TVD) … 3,140.3 Wt/Len (l… 29.70 Grade L-80 Top Thread LTC Casing Description PRODUCTION 5.5x5"@6552' OD (in) 5 1/2 ID (in) 4.28 Top (ftKB) 38.7 Set Depth (ftKB) 6,643.1 Set Depth (TVD) … 6,290.9 Wt/Len (l… 17.00 Grade L-80 Top Thread LTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.8 Set Depth (ft… 6,126.0 Set Depth (TVD) (… 5,793.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.8 HANGER FMC TUBING HANGER 3.500 504.2 NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6 21.13 NIPPLE CAMCO 'DS' NIPPLE 2.812 6,113.2 5,781.1 20.99 LOCATOR BAKER GBH-22 LOCATOR 2.850 6,113.5 5,781.4 20.98 SEAL ASSY BAKER BOT GBH-22 SEAL ASSY 2.85" DRIFT 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,060.0 4,894.9 37.32 LEAK - Production CSG Production casing leak between 5060-5065 4/24/2020 2.992 5,134.5 4,953.5 38.88 PATCH PERM Set Owens X Span permanent patch ( OAL 17.4') 11/23/2020 2.250 5,141.0 4,958.5 39.01 LEAK - TUBING Tubing Leak 7/7/2018 2.992 6,106.0 5,774.4 21.13 NIPPLE REDUCER Set 2.81"D X 1.81"D Nipple reducer 11/22/2020 1.810 6,106.0 5,774.4 21.13 Tubing Plug Set 1.81" CA2 plug in nipple recucer. (24" OAL) 11/23/2020 0.000 6,113.0 5,780.9 20.99 LINER TOP TOP OF L1-02 CTD LINER 8/5/2017 1.920 6,229.0 5,890.1 18.64 WHIPSTOCK BAKER WHIPSTOCK. OAL = 47', OAW 330 LBS, MAX TOOL OD = 2.70, SET WHIPSTOCK 29.4° LEFT OF HIGH-SIDE, TOP OF WHIPSTOCK SET @ 6229' (2 RA TAGS) 7/12/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 4/9/1997 4.0 IPERF 1 11/16" PIVOTS, 180° ph 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 6/15/1998 4.0 RPERF 2 1/8" EnerJet, 0° ph 6,306.0 6,336.0 5,963.4 5,992.2 A-3, A-2, 3H-26 6/24/1994 4.0 IPERF 2 1/8" EnerJet, 90° ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,765.7 2,763.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 2 4,124.4 4,096.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 5/26/2019 3 4,987.6 4,836.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 1/3/2016 4 5,630.9 5,351.9 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 6/30/2005 5 6,055.1 5,727.0 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 Notes: General & Safety End Date Annotation 4/29/2005 NOTE: TREE: FMC 3-1/8"" / GEN IV / 5000 psi rated 3H-26, 11/26/2020 9:17:04 AM Vertical schematic (actual) PRODUCTION 5.5x5"@6552'; 38.7-6,643.1 IPERF; 6,306.0-6,336.0 IPERF; 6,250.0-6,280.0 RPERF; 6,250.0-6,280.0 WHIPSTOCK; 6,229.0 LINER TOP; 6,113.0 SEAL ASSY; 6,113.5 NIPPLE REDUCER; 6,106.0 Tubing Plug; 6,106.0 NIPPLE; 6,106.2 GAS LIFT; 6,055.1 GAS LIFT; 5,630.8 PATCH PERM ; 5,134.5 LEAK - TUBING; 5,141.0 LEAK - Production CSG; 5,060.0 GAS LIFT; 4,987.6 GAS LIFT; 4,124.4 SURFACE; 40.9-3,142.8 GAS LIFT; 2,765.7 NIPPLE; 504.2 CONDUCTOR; 40.9-121.0 HANGER; 37.8 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 3/6/1994 3H-26 ... TD Act Btm (ftKB) 6,660.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020800 Wellbore Status PROD Max Angle & MD Incl (°) 39.20 MD (ftKB) 5,149.90 WELLNAME WELLBORE3H-26 Annotation Last WO: End Date 4/29/2005 H2S (ppm) 200 Date 8/31/2018 Comment SSSV: NIPPLE ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE From:Loepp, Victoria T (CED) To:Phillips, Ron L Subject:Re: KRU 3H-26 (PTD 194-029, Sundry 321-300) Date:Thursday, August 19, 2021 6:27:16 PM Approval is granted for changes outlined below. Please follow up with a 10-403, Change of Approved program tomorrow. Victoria Sent from my iPhone On Aug 19, 2021, at 2:21 PM, Phillips, Ron L <Ron.L.Phillips@conocophillips.com> wrote: Good afternoon Victoria, Yesterday we found several production casing leaks from 4995’ MD to 5310’ MD with a caliper log and a test packer. Our proposed change to the completion is to set a packer at 4980’ and straddle the leaks with 3-1/2” tubing down to the lower packer at 6015’. This well is a producer and our gas lift mandrels will all be above the packer at 4980’. The original plan was to set an 80’ patch across the only know leak at 5145’. I have attached the proposed schematic with the metal skin patch and the revised proposed schematic with the straddle packer. I put a red box around the straddle packer and tubing on the new schematic. We will follow up with a 10-403. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 <3H-26 Proposed Schematic.xlsm> <3H-26 Proposed Schematic with staddle packer.xlsm> 3H-26 Proposed SchematicNew 3-1/2" Completion:3-1/2" 9.3# L-80 HYD-563 tubing to surface3-1/2" Camco KBG-2-9 GLM @ 2502', 3408', 4295', 5099'Weatherford expandable metal skin patch across 5,145'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 6,053'D-nipple @ 6069' MD (2.75" min ID)Baker overshot bottom @ 6,088'Camco DS nipple w/reducer @ 6,106' MD (1.81" min ID)Baker 3-1/2" GBH-22 seal assembly @ 6114' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified by RLP 7/7/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD 3H-26 Proposed Schematic w/staddle packerNew 3-1/2" Completion:3-1/2" 9.3# L-80 HYD-563 tubing to surface3-1/2" Camco KBG-2-9 GLM @ 2502', 3408', 4295', 4900'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer @ 4980' (with tubing to straddle casing leaks from 4995'-5310')Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 5,999'Camco D nipple w/plug @ 6,050' MD Baker 3-1/2" GBH-22 seal assembly @ 6113' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified by RLP 8/19/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD5-1/2" casing leaks from 4995'-5310' C:\Users\aebell\Desktop\August 2021 Data Drop\CPA Data Drop 08182021\2021-08-18_15800_3H-26_CaliperSurvey_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 15800 KRU 3H-26 50-103-02208-00 Caliper Survey 18-Aug-21 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile FTP ______________________________ ______________________________________ Print Name Signature PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL :READ-Anchorage@readcasedhole.com WEBSITE :WWW.READCASEDHOLE.COM _____________________________________ Signaturururururururuurrurururururururuururrururruurrurrrurureeeeee Abby Bell 37' (6HW By Abby Bell at 1:34 pm, Aug 18, 2021 From:Loepp, Victoria T (CED) To:Phillips, Ron L Cc:DOA AOGCC Prudhoe Bay Subject:KRU 3H-26 (PTD#194-029) BOP test pressure Date:Friday, August 13, 2021 8:57:19 PM Approval is granted for BOP test pressure of 3100 psi, 2943 MPSP and 2 ram BOP stack. Victoria Sent from my iPhone On Aug 13, 2021, at 4:31 PM, Phillips, Ron L <Ron.L.Phillips@conocophillips.com> wrote: Victoria, Based on the current well conditions for 3H-26, we are confident the MPSP is below 3000 psi. Current Status 3-1/2” tubing has been removed from the well. Current mud weight = 11.5 ppg. Experiencing steady losses of 10-14 bbls/hr indicating we are overbalanced. Using the current mud weight, top perf depth of 6250’ MD (5910’ TVD), and a 0.1 psi/ft gas gradient: Max SBHP = 5910 ft x 11.5 ppg x 0.052 = 3534 psi. Max MPSP = 3534 psi – (0.1 psi/ft x 5910 ft) = 2943 psi Based upon the above MPSP calculation which is the maximum we could expect given the current status, it appears that we are in compliance with 20 AAC 25.285 with an MPSP < 3000 psi requiring only an annular preventer, one set of blind rams, and one set of pipe rams to fit the size of pipe being used. We believe the reservoir pressure was higher than planned last week because an injector 3H-09 on the other side of what we believed to be a sealing fault was injecting until we shut it in on 8/4, when we discovered the higher pressure. We sincerely ask that you reconsider your decision regarding the 2 sets of rams sized for the pipe being used. Thank you, From:Phillips, Ron L To:Loepp, Victoria T (OGC) Cc:Senden, R. Tyler Subject:RE: [EXTERNAL]KRU 3H-26 (PTD 194-029, Sundry 321-300) APPROVAL BOP test pressure change Date:Thursday, August 12, 2021 1:33:08 PM Good afternoon Victoria, After circulating 11.7ppg brine down the tubing and up the IA we had 32 bph loses. We reduced the fluid weight to 11.6 ppg and still had 20 BPH. We reduced fluid weight to 11.5 ppg and monitored 14 BPH loses. Then we diluted the brine weight down to 11.4 ppg and saw slight returns so we weighted back up to 11.5 ppg and will live with a loss rate of 14 BPH. With 11.5 ppg * 5910’ TVD * .052 = 3534 psi . With a full column of gas that puts our MPSP at 2943 psi and our BOPE test at 3100 psi. We currently have 11.5 ppg KWF in the hole and we are performing the state witnessed BOPE test. Our next weekly BOPE test will be to 250 psi low/ 3100 psi high. Annular preventer 250 psi low/ 3100 psi high. With our MPSP coming in under 3000 psi, this well now only requires a class 2 BOP, therefore we do not plan to swap our bottom pipe rams from 3-1/2” to 2-7/8” while running the 2-7/8” work string. Last week when the MPSP came in over 3000 psi but under 5000 psi we planned to swap the lower pipe rams and pressure test them to match the work string or the tubing we were running or pulling. Current BOPE: 13-5/8” Annular, 2-7/8” x 5” VBR, blind ram, mud cross and 3-1/2” pipe rams Please do not hesitate to call or email me with any questions or clarification. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Phillips, Ron L Sent: Tuesday, August 10, 2021 9:48 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3H-26 (PTD 194-029, Sundry 321-300) APPROVAL BOP test pressure change Good morning Victoria, Yesterday we finished up our BOPE test to 5000 psi. Then when we pulled the tubing hanger and laid down one joint of tubing, the well went on extreme losses. To prevent losing all fluids we shut the well in until we could get more kill weight fluid to the rig. The current brine weight in the well is 12.7 ppg. We are currently filling the pits with 11.6 ppg (the original planned weight for this well based on the shut in bottom hole pressure test from last month). We will open the pipe rams and circulate 11.6 ppg all the way around, shut the well in and get a tubing and casing pressure. We will use the pressure on the gauges to calculate the reservoir pressure then add 0.3 ppg (92 psi) above the reservoir pressure to get the KWF weight. We will weight up, circulate the KWF all the way around and monitor for 30 minutes before continuing to pull tubing. We did not shut in the pipe rams to prevent the reservoir from flowing to surface. We shut the well in to stop the losses until we could get more fluid on location. Do we need to report shutting the well in for this? Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Monday, August 09, 2021 11:03 AM To: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]KRU 3H-26 (PTD 194-029, Sundry 321-300) APPROVAL BOP test pressure change Ron, Approval is granted to modify the BOPE test pressure to 3400 psi. Please include this approval with your approved copy of the sundry including the copy on site for the AOGCC inspector to review. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Monday, August 9, 2021 10:21 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: FW: [EXTERNAL]KRU 3H-26 (PTD 194-029, Sundry 321-300) APPROVAL BOP test pressure change Victoria, This email is to inform you that the MPSP on KRU 3H-26 is even higher that your last approval. Last week the reservoir pressure on 3H-26 crept up even higher than the shut in bottom hole pressure test from last month indicated. We finally got the well to balance out at 12.4 ppg, which is 12.4 ppg * 5910’ TVD * .052 = 3811 psi . With a full column of gas that puts our MPSP at 3220 psi and our BOPE test at 3400 psi. We currently have 12.7 ppg KWF in the hole and we are performing the state witnessed BOPE test. Since this is the first BOPE test with Nabors 7ES, at your request we are testing our BOPE to 5000 psi. Our next weekly BOPE test will be to 250 psi low/ 3400 psi high. Annular preventer 250 psi low/ 3400 psi high. Thank you for the text message over the weekend concerning Nabors 7ES pulling the BPV and installing a Tree test plug without AOGCC witnessed BOP test. If we would have had to close the rams to control flow we would report it, but then it looks like we were trying to perform work with untested BOPE. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, July 30, 2021 9:58 AM To: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 3H-26 (PTD 194-029, Sundry 321-300) APPROVAL BOP test pressure change CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Ron, Approval is granted for the modifications of the BOP test pressure to 3000 psig and the MPSP to 2861 psig. Please include this approval with your approved copy of the sundry and include with the approved sundry on the job site so the AOGCC inspector can review. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Tuesday, July 13, 2021 8:39 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Conklin, Amy A (Swift Technical Services LLC) <Amy.A.Conklin@contractor.conocophillips.com> Subject: KRU 3H-26 (PTD 194-029) increased SBHP Victoria, After we submitted the KRU 3H-26 sundry application to the AOGCC, ConocoPhillips obtained a new SBHP (shut in bottom hole pressure) earlier this month. The SBHP test at 5,781’ TVD was 3,396 psi. Since the top perforation is 129’ TVD below the test depth I added 56.3 psi to the 3,396 psi to get a 3,452 psi at the top perforation (5,910’ TVD). This gives us an MPSP of 2,861 psi. Therefore we plan to test our BOPE to 250/3,000 psi and the annular to 250/2,500 psi. We still plan to start this RWO with Nabors 7ES on 8/1/2021. Please call or email if you have any questions or need more information. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 STATE OF ALASKA Reviewed By: J OIL AND GAS CONSERVATION COMMISSION P.I. Supry it b ?ZrC BOPE Test Report for: KUPARUK RIV UNIT 31-1-26 - Comm Contractor/Rig No.: Nabors 7ES Operator: ConocoPhillips Alaska, Inc. Type Operation: WRKOV Sundry No: Type Test: INIT 321-300 PTD#: 1940290 ' DATE: 8/9/2021 ' Operator Rep: K. Barr / D. Rowell Test Pressures: Rams: Annular: Valves: MASP: 250/5000 250/3500 " 250/5000 ' 2082 ' TEST DATA Inspector JeffJones ' Rig Rep: Insp Source Inspector Inspection No: bopJJ211013085138 Related Insp No: MISC. INSPECTIONS: MUD SYSTEM: ACCUMULATOR SYSTEM: Upper Kelly 1 P/F Lower Kelly Visual Alarm Time/Pressure 1 P/F Location Gen.: -_P- Trip Tank P_-- -P _ System Pressure 3000 P Housekeeping: P Pit Level Indicators P " P Pressure After Closure 1650 P PTD On Location P Flow Indicator P P 200 PSI Attained 17 P Standing Order Posted P Meth Gas Detector P P Full Pressure Attained 102 P Well Sign -P H2S Gas Detector P P Blind Switch Covers: All P Drl. Rig _ P . MS Misc NA_ NA_ Nitgn. Bottles (avg): 5 (d_)2045 P - Hazard Sec. P _- Check Valve 0 NA ACC Misc 0 __NA Misc NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Upper Kelly 1 P' Lower Kelly - 1 P Ball Type 1 P Inside BOP 1 P FSV Misc 0 NA BOP STACK: CHOKE MANIFOLD: Quantity Size P/F Quantity P/F Stripper 0 NA No. Valves 16 P Annular Preventer 1 13 5/8" P Manual Chokes 1 P #1 Rams _ 1 2-7/8 x 5'_'_ P Hydraulic Chokes 1 P" #2 Rams 1 Blind P - CH Mise 0 NA #3 Rams 1 3 1/2" P__1 #4 Rams 0 NA. #5 Rams 0 NA INSIDE REEL VALVES: #6 Rams 0 NA (Valid for Coil Rigs Only) Choke Ln. Valves 1 3 1/8" P - Quantity P/F HCR Valves _1 3 1/8" " P _ Inside Reel Valves -_ 0 NA Kill Line Valves 1 ` 3 1/8" - P Check Valve 0 NA BOP Misc 0 NA Number of Failures: 0 Test Results Test Time 7' Remarks: Nabors 7ES personnel performed the tests today in a safe and proficient manner with no failures witnessed. The gas detection and pit volume totalizer alarm systems were tested and operated properly. BOPE equipment was tested to recommended ✓ working pressure (5K psi) except the annular ( 3.5K). The rig and surrounding location appeared to be clean, orderly and in good condition. From:Ward, Dusty K To:Loepp, Victoria T (OGC) Cc:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Senden, R. Tyler; Phillips, Ron L Subject:RE: [EXTERNAL]KRU 3H-01A (PTD 219-158, Sundry 321-302) KRU 3H-26(PTD 194-029, Sundry 321-300) BOPE Test Requirements Date:Wednesday, August 4, 2021 9:01:46 AM Thank you Victoria. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 4, 2021 8:15 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]KRU 3H-01A (PTD 219-158, Sundry 321-302) KRU 3H-26(PTD 194-029, Sundry 321-300) BOPE Test Requirements All, KRU 3H-26(PTD 194-029, Sundry 321-300) BOPE Test Requirement is 5000 psi for the initial test. This is the first well workover for Nabors 7ES after being stacked for a period of time. Subsequent BOPE test requirement is 2500 psi as approved in the sundry. KRU 3H-01A (PTD 219-158, Sundry 321-302) BOPE Test Requirement remains at 3000 psi as approved in the Sundry. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Wednesday, August 4, 2021 8:02 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: RE: [EXTERNAL]KRU 3H-01 (PTD 219-158, Sundry 321-302) BOPE Test to 5000 psi Required Victoria, 3H-26 will actually be the first well we’re performing. Apologies for any confusion on schedule. I forwarded this information on to our operations and my supervisor and they plan to execute this 5000 psig test on the 3H-26 BOPE test. If we do the 5000 psig test on 3H-26, then may I test to the previously discussed/sundried test for 3H-01? Ron (cc’d) can verify he’s communicated with operations to do this test. Thank you! Have a great day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, August 4, 2021 6:19 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Cc: Regg, James B (CED) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov> Subject: [EXTERNAL]KRU 3H-01 (PTD 219-158, Sundry 321-302) BOPE Test to 5000 psi Required Dusty, When a rig is returning to service after being stacked out for a period of time, the initial BOPE test is to 5000 psi. Since this is the first well work over for Rig Nabors 7ES after being out of service, the BOPE will be required to test to 5000 psi. Please include this change with your approved copy of the sundry and with the job site copy for the inspector to review. Thanx, Victoria Sent from my iPhone On Aug 3, 2021, at 7:30 AM, Ward, Dusty K <Dusty.Ward@conocophillips.com> wrote: Victoria, Thank you. Will do. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, July 30, 2021 9:30 AM To: Ward, Dusty K <Dusty.Ward@conocophillips.com> Cc: DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Regg, James B (CED) <jim.regg@alaska.gov> Subject: [EXTERNAL]KRU 3H-01 (PTD 219-158, Sundry 321-302) Change APPROVAL CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. Dusty, Approval is granted for the changes as outlined below. Please attach this approval and the updated schematic to your approved copy of the sundry including the copy of the approved sundry that is on the job site for the AOGCC inspector to review. 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@alaska.gov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov From: Ward, Dusty K <Dusty.Ward@conocophillips.com> Sent: Thursday, July 29, 2021 1:57 PM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: 3H-01 Sundry Question and Update Victoria, Hope this finds you well. I had 1 question and 1 update for the 3H-01 RWO Sundry (attached). Question 1: At step 11 of the procedure summary on page 3, you added a line to “ PT 7” casing to 3000 psi for 30 min and chart. ”. The 5.5” x 7” annulus will be the new OA effectively from my understanding, and historically the 7” has been the IA, which we would test to 2500 psig. Can I pressure test the 5.5” x 7.0” annulus to 2500 psig instead of 3000psig ? I’d prefer not to test it beyond what we’ve historically tested it. The only reason I had 3000 psig for inside the 3.5” x 5.5” tie-back is that there’s that small 3.5” tubing section that is part of the tubing envelope. Update 1: I noticed I did not have a GLM and nipple between the packer and the 3.5” x 5.5” crossover in the schematic (page 4 of the sundry). We would actually want a GLM and a nipple between those in case we ever wanted to circ in CI or Freeze protect to that 5.5” x 7” annulus. I attached an updated schematic to this e-mail. Please confirm you’ve received this and let me know if you have any questions. (I’ll be OOTO tomorrow and Monday, but please call my cell below if you have questions.) Please confirm it’s ok to test that new 5.5” x 7.0” OA to 2500 psig instead of 3000 psig. Thanks for your time. Appreciate it. Good day. Dusty Ward Senior Wells Engineer Office: 907-265-6531 Cell: 503-476-2519 From:Phillips, Ron L To:Loepp, Victoria T (OGC) Cc:Senden, R. Tyler; Conklin, Amy A (Swift Technical Services LLC) Subject:RE: [EXTERNAL]Re: KRU 3H-26 (PTD 194-029) increased SBHP Date:Wednesday, July 28, 2021 1:37:43 PM Attachments:3H-26 10-403 RWO Apprvd.pdf Victoria, On page 3 of the KRU 3H-26 10-403 Sundry (attached) you crossed out the 5 min tubing pressure test (pg. 3 step 12) and wrote in ‘30 minutes on chart’. We have not been required to do this in the past and I am not sure what has changed. We test the tubing for 5 minutes to prove a barrier for rigging down the BOPE and rigging up the tree. The MIT-IA test (pg. 3 step 13) is for 30 minutes and charted, this proves the tubing and production casing integrity down to the packer. Can you point me to where in the regs it says to perform a 30 minute charted test on the tubing. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Phillips, Ron L Sent: Wednesday, July 28, 2021 10:51 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]Re: KRU 3H-26 (PTD 194-029) increased SBHP Thank you. Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Wednesday, July 28, 2021 10:50 AM To: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Subject: [EXTERNAL]Re: KRU 3H-26 (PTD 194-029) increased SBHP CAUTION:This email originated from outside of the organization. Do not click links or open attachments unless you recognize the sender and know the content is safe. I will send an email to attach Sent from my iPhone On Jul 28, 2021, at 10:45 AM, Phillips, Ron L <Ron.L.Phillips@conocophillips.com> wrote: Victoria, I received the approved sundry for 3H-26 listed below yesterday. I was expecting hand written corrections to the MPSP and BOPE test pressures on the 10-403 or an email response. We plan to move to the KRU 3H-26 next week. Can you please let me know if I need to resubmit the paper work or just attach an emailed from you, to the 10-403 we display in the dog house? Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska 907-317-5092 ATO-06-656 From: Phillips, Ron L Sent: Tuesday, July 13, 2021 8:39 AM To: Victoria T Loepp <victoria.loepp@alaska.gov> Cc: Senden, R. Tyler <R.Tyler.Senden@conocophillips.com>; Conklin, Amy A (Swift Technical Services LLC) <Amy.A.Conklin@contractor.conocophillips.com> Subject: KRU 3H-26 (PTD 194-029) increased SBHP Victoria, After we submitted the KRU 3H-26 sundry application to the AOGCC, ConocoPhillips obtained a new SBHP (shut in bottom hole pressure) earlier this month. The SBHP test at 5,781’ TVD was 3,396 psi. Since the top perforation is 129’ TVD below the test depth I added 56.3 psi to the 3,396 psi to get a 3,452 psi at the top perforation (5,910’ TVD). This gives us an MPSP of 2,861 psi. Therefore we plan to test our BOPE to 250/3,000 psi and the annular to 250/2,500 psi. We still plan to start this RWO with Nabors 7ES on 8/1/2021. Please call or email if you have any questions or need more information. Thanks, Ron Phillips Senior RWO Engineer ConocoPhillips Alaska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y Samantha Carlisle at 9:42 am, Jun 17, 2021 321-300 Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:34:32 -08'00' X VTL 7/22/21 DSR-6/17/21 10-404 -00 DLB X X BOP test to 2500 psig Annular preventer test to 2500 psig DLB 06/17/2021 dts 7/22/2021 JLC 7/22/2021 Jeremy Price Digitally signed by Jeremy Price Date: 2021.07.22 12:22:33 -08'00' RBDMS HEW 7/22/2021 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 14, 2021 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KUP Producer 3H-26 (PTD# 194-029). Well 3H-26 was drilled in 1994 by Parker 245 and completed by Nordic 1 as an injector into the A-sands. The C-sands were perforated in 1997. The well was worked over in 2005 by Nordic 2 as a producer. Nabors CDR3 drilled 3 more laterals for this well in 2017. Well 3H-26 was SI on 11/19/2019 for a RWO. Production casing leak found at 5,145' on 2/25/2020. The proposed workover scope for 3H-26 will include pulling the 3-1/2" completion, installing a metal skin patch across the production casing leak at 5,145' MD and then installing a new 3-1/2" completion. If you have any questions or require any further information, please contact me at 265-6312. RRoonn LL PPhhiilllliippss SSeenniioorr WWeellllss EEnnggiinneeeerr CCPPAAII DDrriilllliinngg aanndd WWeellllss Ron Phillips Digitally signed by Ron Phillips Date: 2021.06.17 08:33:58 -08'00' The proposed workover scope for 3H-26 will include pulling the 3-1/2" completion, installing a metal skin patch across the production casing leak at 5,145' MD and then installing a new 3-1/2" completion. 3H-26 RWO Procedure Kuparuk Producer PTD #194-029 1 Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 3-1/2” completion, patch production casing and install a new 3-1/2” completion. General Well info: Well Type: Producer MPSP: 2,082 psi using 0.1 psi/ft gradient Static BHP: 2,671 psi / 5,915’ TVD (8.7 ppg EMW) measured on 06/10/20 Wellhead type/pressure rating: FMC Gen IV, 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Rams MIT results: CMIT-TxIA Failed (Tubing and Production casing leaks) MIT-OA PASSED – 06/21/2017 IC POT &PPPOT PASSED – 11/05/2005 TBG POT &PPPOT PASSED – 06/21/2017 Production Engineer: Lynn Aleshire Workover Engineer: Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre-Rig Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. Dummy all GLMs leaving the deepest GLM open as a circulation point. 3. String shot and chem cut tubing at ~6084’ MD in the middle of the first joint above the 2-3/8” CTD liner. 4. FT LDS, grease tree valves and set BPV. Workover Procedure 1. MIRU Nabors 7ES on 3H-26. Pull BPV if need to circulate. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure and complete 30-minute NFT. Verify well is dead. Circulate KWF as needed. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/2,500 psi. Test annular 250/2,500 psi. 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing from pre-rig tubing cut 6084’ MD. 6. Perform a Cleanout run down to 6084’MD. 7. Run test packer /bridge plug combo to verify production casing leak location. 8. Run lower completion and set packer/PBR below casing leak. 9. Run and set casing patch across leak at 5145’ MD. 10. MU 3 ½” completion with GLMs and sting seals into PBR. 11. Once on depth, space out ~3’ as needed. 12. Pressure test tubing to 3000 psi for 5 minutes. 13. Pressure test inner annulus to 2500 psi for 30 minutes on chart. 14. Confirm pressure tests, then shear out SOV with pressure differential. 15. Install BPV. 16. ND BOPE. NU tree. 17. Pull BPV, freeze protect well, and set BPV if necessary. 18. RDMO. Post-Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV, ball & rod and run GLD. 4. Handoff to operations to put back on production. 30 minutes on chart 3H-26 Proposed SchematicNew 3-1/2" Completion:3-1/2" 9.3# L-80 EUE 8rd Tubing to surface3-1/2" Camco gas lift mandrels @ ~2766', ~4124', ~4988', ~5631', ~6055'Weatherford expandable metal skin patch across 5,145'Baker 3-1/2" x 5-1/2" 40FA36x30 Packer/PBR @ 6,053'X-nipple @ 6069'Baker overshot bottom @ 6,088'Camco DS nipple @ 6,106' MD (2.812" min ID)Baker 3-1/2" GBH-22 seal assembly @ 6114' MD (2.98" ID)7-5/8" 29.7# L-80 shoe @ 3143' MD5.5" 17# L-80 shoe @ 6643' MD3-1/2" 9.3# L-80 overshot @ 6088' MDKOP @ 6230' MD16" 62.5# H-40 shoe @ 121' MDModified by RLP 6/10/21C-sand perfs 6250' - 6280' MDA-sand perfs 6306' - 6336' MD3H-26L1 TD @ 8773' MD3H-26L1-01 TD @ 8890' MD3H-26L1-02 TD @ 10168' MDBillets @ 6772' MD @ 7408' MD Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 6,335.0 11/19/2019 3H-26 zembaej Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set DMY's 9/11/2020 3H-26 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 40.9 Set Depth (ftKB) 121.0 Set Depth (TVD) … Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 7 5/8 ID (in) 6.87 Top (ftKB) 40.9 Set Depth (ftKB) 3,142.8 Set Depth (TVD) … 3,140.3 Wt/Len (l… 29.70 Grade L-80 Top Thread LTC Casing Description PRODUCTION 5.5x5"@6552' OD (in) 5 1/2 ID (in) 4.28 Top (ftKB) 38.7 Set Depth (ftKB) 6,643.1 Set Depth (TVD) … 6,290.9 Wt/Len (l… 17.00 Grade L-80 Top Thread LTC Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 37.8 Set Depth (ft… 6,126.0 Set Depth (TVD) (… 5,793.1 Wt (lb/ft) 9.30 Grade L-80 Top Connection IBT Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.8 HANGER FMC TUBING HANGER 3.500 504.2 NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6 21.13 NIPPLE CAMCO 'DS' NIPPLE 2.812 6,113.2 5,781.1 20.99 LOCATOR BAKER GBH-22 LOCATOR 2.850 6,113.5 5,781.4 20.98 SEAL ASSY BAKER BOT GBH-22 SEAL ASSY 2.85" DRIFT 2.980 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 5,060.0 4,894.9 37.32 LEAK - Production CSG Production casing leak between 5060-5065 4/24/2020 2.992 5,134.5 4,953.5 38.88 PATCH PERM Set Owens X Span permanent patch ( OAL 17.4') 11/23/2020 2.250 5,141.0 4,958.5 39.01 LEAK - TUBING Tubing Leak 7/7/2018 2.992 6,106.0 5,774.4 21.13 NIPPLE REDUCER Set 2.81"D X 1.81"D Nipple reducer 11/22/2020 1.810 6,106.0 5,774.4 21.13 Tubing Plug Set 1.81" CA2 plug in nipple recucer. (24" OAL) 11/23/2020 0.000 6,113.0 5,780.9 20.99 LINER TOP TOP OF L1-02 CTD LINER 8/5/2017 1.920 6,229.0 5,890.1 18.64 WHIPSTOCK BAKER WHIPSTOCK. OAL = 47', OAW 330 LBS, MAX TOOL OD = 2.70, SET WHIPSTOCK 29.4° LEFT OF HIGH-SIDE, TOP OF WHIPSTOCK SET @ 6229' (2 RA TAGS) 7/12/2017 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 4/9/1997 4.0 IPERF 1 11/16" PIVOTS, 180° ph 6,250.0 6,280.0 5,910.0 5,938.6 C-4, C-3, 3H-26 6/15/1998 4.0 RPERF 2 1/8" EnerJet, 0° ph 6,306.0 6,336.0 5,963.4 5,992.2 A-3, A-2, 3H-26 6/24/1994 4.0 IPERF 2 1/8" EnerJet, 90° ph Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,765.7 2,763.5 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 2 4,124.4 4,096.2 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 5/26/2019 3 4,987.6 4,836.7 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 1/3/2016 4 5,630.9 5,351.9 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 6/30/2005 5 6,055.1 5,727.0 CAMCO KBG-2- 9 1 GAS LIFT DMY BTM 0.000 0.0 9/11/2020 Notes: General & Safety End Date Annotation 4/29/2005 NOTE: TREE: FMC 3-1/8"" / GEN IV / 5000 psi rated 3H-26, 11/26/2020 9:17:04 AM Vertical schematic (actual) PRODUCTION 5.5x5"@6552'; 38.7-6,643.1 IPERF; 6,306.0-6,336.0 IPERF; 6,250.0-6,280.0 RPERF; 6,250.0-6,280.0 WHIPSTOCK; 6,229.0 LINER TOP; 6,113.0 SEAL ASSY; 6,113.5 NIPPLE REDUCER; 6,106.0 Tubing Plug; 6,106.0 NIPPLE; 6,106.2 GAS LIFT; 6,055.1 GAS LIFT; 5,630.8 PATCH PERM ; 5,134.5 LEAK - TUBING; 5,141.0 LEAK - Production CSG; 5,060.0 GAS LIFT; 4,987.6 GAS LIFT; 4,124.4 SURFACE; 40.9-3,142.8 GAS LIFT; 2,765.7 NIPPLE; 504.2 CONDUCTOR; 40.9-121.0 HANGER; 37.8 KUP PROD KB-Grd (ft) 40.99 Rig Release Date 3/6/1994 3H-26 ... TD Act Btm (ftKB) 6,660.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032020800 Wellbore Status PROD Max Angle & MD Incl (°) 39.20 MD (ftKB) 5,149.90 WELLNAME WELLBORE3H-26 Annotation Last WO: End Date 4/29/2005 H2S (ppm) 200 Date 8/31/2018 Comment SSSV: NIPPLE ISSUED AS:PRELIMINARYDATE:ISSUED BY:AS BUILTFOR:APPROVALMARK-UPQUOTEREVIEW07-JUN-21PKMXX17'-314"[5261]3'-912"[1156]4'-734"[1418]2'-0"[610]2'-934"[859]2'-0"[610]2'-0"[610]BY NABORSBY OPERATORPIPE RAMCL WELLCHOKE LINE7BILL OF MATERIALS413121NOQTY DESCRIPTIONBOP, RAM 1358" 5M CAMERON "U" (DOUBLE)1DRILL SPOOL 1358" 5M w/ (2) 318" 5M OUTLETS.BOP, RAM 1358" 5M CAMERON "U" (SINGLE)36GATE VALVE, MANUAL 318" 5MGATE VALVE, HYDRAULIC 318" 5M22BOP, ANNULAR 1358" 5M CAMERON T-9012434455556724" HEIGHT.678KILL LINE5API TARGET BLIND FLANGE 318" 5M48DSA 318"5M x 2116" 5M1FF-TICKET #:THIS DRAWING IS SHOWN TRUE SCALE ONLY WHEN PRINTED ON THIS SIZE PAPERTHIS DOCUMENT AND THE INFORMATION CONTAINED HEREIN IS A CONFIDENTIAL DISCLOSURE. IT IS SHOWN TO YOUR COMPANY WITH THE UNDERSTANDING IT IS NOT TO BEREVEALED TO OTHERS OR USED FOR ANY PURPOSE WITHOUT THE WRITTEN CONSENT OF NABORS INDUSTRIES.REV.XREFDESCRIPTION APP.DATEBYTITLE COPYRIGHTED©DATE:DRN BY:ER:BDWG:APP:RIG:SCALE:NABORSSHT NO. OFNABORS RIG 7ES13 5/8" 5M BOP STACK LAYOUT14002 7ESPKM NTS27-MAY-21 SMB7ES-0008-01B REVISED AND ISSUED FOR INFORMATION 07-JUN-21 PKM3470945 01 01DRILLER SIDEOFF DRILLER SIDE Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3H-26 50-103-20208-00 906832308 Kuparuk River Patch Setting Record Field- Final 23-Nov-20 0 1 2 3K-27 50-029-22751-00 906831229 Kuparuk River Multi Finger Caliper Field & Processed 20-Nov-20 0 1 3 3K-27 50-029-22751-00 906831376 Kuparuk River Leak Detect Log Field- Final 21-Nov-20 0 1 4 3M-17 50-029-21729-00 906811709 Kuparuk River Leak Detect Log Field- Final 28-Nov-20 0 1 5 3N-02A 50-029-21527-01 906813982 Kuparuk River Leak Detect Log Field- Final 30-Nov-20 0 1 6 3N-02A 50-029-21527-01 906804224 Kuparuk River Packer Setting Record Field- Final 5-Nov-20 0 1 7 3S-07 50-103-20430-00 906801235 Kuparuk River Leak Detect Log Field- Final 4-Nov-20 0 1 8 3S-07 50-103-20430-00 906806709 Kuparuk River Packer Setting Record Field- Final 7-Nov-20 0 1 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1940290 E-Set: 34557 Originated:Delivered to:8-Jan-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 2H-11 50-029-20052-00 906834022 Kuparuk River Leak Detect Log with ACX Processed 2-Dec-20 0 1 2 2H-11 50-029-20052-00 906834022 Kuparuk River Multi Finger Caliper Field & Processed 6-Dec-20 0 1 3 2N-333 50-103-20525-00 906859420 Tarn Participating Area Plug Setting Record Field- Final 11-Dec-20 0 1 4 2N-333 50-103-20525-00 906869831 Tarn Participating Area Leak Detect Log Field- Final 17-Dec-20 0 1 5 2W-13 50-029-21252-00 906808475 Kuparuk River Leak Detect Log Field- Final 13-Nov-20 0 1 6 2W-13 50-029-21252-00 906808475 Kuparuk River Packer Setting Record Field- Final 14-Nov-20 0 1 7 2W-13 50-029-21252-00 906813971 Kuparuk River Multi Finger Caliper Field & Processed 11-Nov-20 0 1 8 2Z-08 50-029-20924-00 906803595 Kuparuk River Plug Setting Record Field- Final 8-Nov-20 0 1 9 3H-01 50-103-20084-00 906826894 Kuparuk River String Shot Record Field- Final 19-Nov-20 0 1 10 3H-26 50-103-20208-00 906832308 Kuparuk River Leak Detect Log Field- Final 24-Nov-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 01/08/2021 01/11/2021 Abby Bell PTD: 1940290 E-Set: 34556 Originated:Delivered to:3-Dec-20 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #Digital # 1 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 17-Sep-20 0 1 2 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 18-Sep-20 0 1 3 3B-14 50-029-21287-00 906717380 Kuparuk River Leak Detect Log Field- Final 19-Sep-20 0 1 4 3B-14 50-029-21287-00 906717380 Kuparuk River Packer Setting Record Field- Final 18-Sep-20 0 1 5 3H-26 50-103-20208-00 906703718 Kuparuk River Multi Finger Caliper Field & Processed 11-Sep-20 0 1 6 3K-23 50-029-22771-00 n/a Kuparuk River Radial Bond Log Field- Final 7-Sep-20 0 1 7 3K-23 50-029-22771-00 n/a Kuparuk River Tubing Punch Record Field- Final 7-Sep-20 0 1 8 3N-15 50-029-21592-00 n/a Kuparuk River Leak Detect Log Field- Final 30-Aug-20 0 1 9 3N-15 50-029-21592-00 906726591 Kuparuk River Packer Setting Record Field- Final 24-Sep-20 0 1 10 3O-15 50-029-21797-00 906722930 Kuparuk River Leak Detect Log Field- Final 24-Sep-20 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 12/04/2020 PTD: 1940290 E-Set: 34345 12/08/2020 Abby Bell Originated: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Delivered to: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above Transmittal Date: RECEIVED APR 2 3 2020 AOGCC 1 9 0 2 9 32800 23 -Apr -20 WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # CD # 1 2N-309 50-103-20293-00 906207893 Tarn Packer Setting Record Final -Field 28 -Dec -19 0 1 2 2W-12 50-029-21240-00 906212841 Kuparuk Packer Setting Record Final -Field 2 -Jan -20 0 1 3 3H -14B 50-103-20092-02 906340305 Kuparuk Packer Setting Record Final -Field 1 -Mar -20 0 1 4 3H-26 50-103-20208-00 906340306 Kuparuk Leak Detect Log Final -Field 28 -Feb -20 0 1 5 3H-35 50-103-20805-00 906363845 Kuparuk Radial Cement Bond Log Final -Field 4 -Mar -20 0 1 6 3H -14B 50-103-20092-02 906349140 Kuparuk Multi Finger Caliper Final -Field 29 -Feb -20 0 1 7 8 9 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com Date: l L �. �'� j Signed: v (,! • • C. O N › p n ¢ °L., x° > E Eurw � a, 0 3 oz Q-w • YO 3 `° 'b 6 � m 6 4' . O -O0v E r) Q� teY 7) •C .- ro a, O N L Pill f� zl.) a a c C . C > ca O Y 21t p u Lit a p w w )- n r r n r� N- r_ r r r r f` r" N v E 0 CO fd.. 0 7 7 7 3 7 7 S. 7 7 7 7 7 7 7 E 9 O Vl tA, r CO h Co O) O .- U) Co O O N •,:r IA • f0 4-, 4J NZ, Q N N N N M u0 CO p Q o '(7.) O C i -, u 000000 0 0 0 0 0 0 0 0 C - 0 '- U.' J J J J J J J J J J J J J J OD C 4- 0 } W W W W W W W W W W W W W W v, G.) C U "" H LL LL LL LI. LL LL LL LL LL LL LL LL LI. LL +' (1) N N 0 < J J J J J J J J J J J J J Ja _0 > C 4J II" �' Q Q Q Q Q Q Q Q Q Q Q Q Q Q 'N 0 C ,�._ w C a Z Z Z Z Z Z Z Z Z Z Z Z Z Z a CO N 0 cu aJ Qy OLL LL LL LL LL LL LL LL LL LL LL LL LL LL cr L -0 C > (O Y j) Y N .''' v 0 .0 E qj u O a' z a u > r. V re 0 C _O 03 w M p P 2 U1 Y u s G a o d d ~ c no a o 0 G O • _ V z Q v a 0 C a U wU E E LL LL LL LL o LL LL in G O a 't 't R m O 't O O O O •y O O \ d mO tea ° > -a -0j aaaaaraa 1 .0 O y ma � .� .� v a a3 d• ca > LL CI 03 LSC., ; 0 Cl ote1 an *tS d " a O Q N. z tP d . ro ro ya w O I 2 tv 0 q v d J J J J J J J J J J J J J J 4 I roro Fa 3 3 3 3 3 3 3 3 3 3 3 3 3 3 41)11/09,-.911 • ° Z cccecectecccctccceccxxxce W www W W W W W w w W w W Q W > > > > > > > > > > > > > > V 2xcerecerzce xcezrexxxx c✓1 zYYYY Y Y Y Y Y Y Y Y Y Y > > > > > > > > > > >_, IXCLCCMCLCLCCCCMCGCCCLCCC4 A v iviQ w Q Q Q Q Q Q Q Q Q Q Q Q Q Q 1 a a a a a a a a a a a a a a Y O > > > > > > > > > > > aWU Y Y Y Y Y Y Y Y Y Y Y Y Y Y CC ta o N cc n N NNNNNN to CO r co O N ro O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 W N 0 °` 000000 00000000 O a0000000000000 @ ti r r r r r n v co co co co co co co o 0 0 0 0 0 0 O W E E E E E 2 2 to N to cnto to cn v �'f 000000 00000000 a C UJ X `A v @ CC ro w o o 0 0 0 0 0 0 0 0 E Io 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N Q v r r r f` r r co CO t) Co 0) r .., NN N N N N N ,- If) 7 O) 0 CD In ., O- n!) f)') F- )- n r Is- n rCO O M N N O) 'C - h. 0 O 0 0 0 0 0 N O 0 N O 0 C '- - N N N N N N N N N N N N N N N y) S _C R o) o) O) o) O) O) O) o) e) O) O) r) o) O) .o•O a. R NNNNNNNNNNNONNCO Q1 00000000000 ,- 00 i u 0 u — O O O O O O O O O O O O O O .+ M C 0 co 00 C _... .,,. N in to N N N u7 to i() to N N 1n N d O U • ~ Q w ca N E CC u, d Q '•• c In In In in IA N in 41 5 Y Y .47 E z 15 co co v N ''•, •ttz O O O O O O O N O O I- N 0 to in 0 !, E d N N «� 00 Ii't Z C = a Q O N 2 2 2 2 2 2 2 a a ,. M N N E z N p O 0 V5 a 3 4 ` it a` a H 1- • -029 Zg 3�q WELL LOG ,,. TRANSMITTAL- PROACTIVE DIAGNOSTIC SERVICES, INC. RECEIVED DA AIL/GOGED M.K. BENDER JUL 13 2017 To: AOGCC 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: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED AUG 0 37_01( 1( 1) Caliper Report 07-Jul-17 3H-26 1 Report /CD 50-103-20208-00 2) Caliper Report 06-Jul-17 1E-11 1 Report /CD 50-029-20787-00 Signed : /'22ALe41 _ 6eAteetDate : 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: PDSANCHORAGEE MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:Wchives\MasterTemplateFiles\Templates\Distribution\TransmittalSheets\ConocoPhillips_Transmit.docx •ECEIVED ‘,(),4-02.5) 2$ 3-11 JUL 13 2017 1111 , Memory Multi-Finger Caliper AOGCC a Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 3H-26 Log Date: July 7, 2017 Field: Kuparuk Log No.: 14262 State: Alaska Run No.: 1 API No. 50-103-20208-00 Pipe Description: 3.5 inch 9.2 lb. L-80 EUE IBT Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 6,126 Ft. (MD) Pipe Description: 5.5 inch 17 lb. L-80 LTC Top Log Interval: 6,126 Ft. (MD) Pipe Use: Tubing Bottom Log Interval: 6,309 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS : This caliper data is tied into the Schlumberger Jewelry Log at the WLEG at 6,126 feet(Driller's Depth). This log was run to assess the condition of the tubing and casing with respect to I.D. restrictions prior to setting a whipstock. The setting range for the BOT thru-tubing whipstock is 4 inches to 4.75 inches. The caliper recordings indicate a clear minimum internal diameter of at least 4 inches throughout the 5.5 inch casing logged until —6,252 feet where heavier scale build-up restricts the I.D. to less than the minimum 4 inch I.D. The planned top of whipstock is—6,232 feet so setting operations should not be hindered by restrictions less than 4 inches until—6,252 feet. A 3-D log plot of the caliper recordings across the scale build-up in the 5.5 inch casing logged and a graph illustrating minimum recorded diameters on a joint-by-joint basis are included in this report. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition with respect to internal corrosive and mechanical damage, with no significant wall penetrations or areas of cross-sectional wall loss recorded. Light to moderate scale build-up is present throughout the 3.5 inch tubing, increasing in severity with depth from surface to 6,126 feet(end of tubing), restricting the I.D. to 2.63 inches in joint 183 (5,848 ft). The presence of scale may mask additional damage to the inside of the 3.5 inch tubing A 3-D log plot of the caliper recordings across the 3.5 inch tubing and a graph illustrating minimum recorded diameters on a joint- by-joint basis are included in this report. The caliper recordings indicate the 5.5 inch casing logged appears to be in good condition with respect to internal corrosive and mechanical damage,with no significant wall penetrations or areas of cross-sectional wall loss recorded outside of the perforation intervals. The caliper recordings indicate heavy scale throughout the casing logged, restricting the I.D. to 2.96 inches in joint 4(6,263 ft). The presence of heavy scale throughout the 5.5 inch casing may mask additional damage to the inside of the casing. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations(> 10%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS : No significant areas of cross-sectional wall loss (> 1%)are recorded. ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • S 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS : Desolit tion Minlmuni Recorded Diameter:, 1r ;1t Scale 2.63 inches 183 5,848 Ft. (MD) Scale 2.67 inches 151 4,801 Ft. (MD) Scale 2.71 inches 190 6,092 Ft. (MD) Scale 2.71 inches 188 5,994 Ft. (MD) Scale 2.71 inches 189.3 6,065 Ft. (MD) 5.5 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (>0%)are recorded throughout the casing logged outside of the perforation intervals. 5.5 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 0%)are recorded throughout the casing logged outside of the perforation intervals. 5.5 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS : D sctiptiort Minimum kecOrded i_)iaa _;t . : JOSS Heavy Scale 2.96 inches 4 6,263 Ft. (MD) Heavy Scale 3.34 inches 3 6,255 Ft. (MD) Heavy Scale 3.76 inches 0.1 6,127 Ft. (MD) Heavy Scale 4.20 inches 1 6,148 Ft. (MD) Heavy Scale 4.22 inches 2 6,174 Ft. (MD) C. Goerdt C. Waldrop T. Wiese Held 1-_ilglr'eer(S1 n lyut(s) VOlne6skds, ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysis@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips alaska, Inc. Field : Kuparuk Well : 3H-26 Date : July 7, 2017 Description : Detail of Caliper Recordings Across 3.5 Inch Tubing. Comments Depth Nominal I.D. 3-D Log Image Map i1ft:600ft 2 5 inches 3.5 0° 0° 90° 180° 270° 0° Maximum I.D. F--- I 2.5 inches 3.5 Minimum I.D. I I 2.5 inches 3.5 2.625"Dummy Whipstock Diameter 2.5 inches 3.5 Pup Joints • Joint 1 50 Pup Joints Joint 2 100 ; Joint 3 Joint 4 150 Joint 5 1 200 ; Joint 6 Joint 7 250 Joint 8 300 Joint 9 Joint 10 350 Joint 11 0 • 4 450 00 1 I Joint 12 I I/1111 Joint 13 i 1 Joint 14 .. Pup Joint Nipple 13111 Pup Joint 500 111 1 111 ..._ Joint 15 4 Joint 16 , / 550 i i Joint 17 I I IIIIIIII Joint 18 600 101 1 I 11111 Joint 19 650111111111 . ..i Joint 20 1111111riammum ... ... 1111M1111•11111111111111 . Joint 21 700 MEM MENEM ,.!.- IMINIFIK211•11011 . INIMEIENIMENI , . Joint 22 IIMMIIIII IMEIMI .._ Joint 23 750 1111111 UM .. :. Joint 24 800 IIIMIIIM . IMININUMIMINIME Joint 25 MIIIIIREIMINIMI ,. - . IMINEME Joint 26 850 IMINIEW1111111111 1111111MBWINIMMIN iiiiiiiiii. S • Joint 27 900 Joint 28 li 950 Efflinitimmoms Joint 29 1111111 111111 Joint 30 11111111111111ENNENNI /ill 1000 - Joint 31 Joint 32 1050 III 11 Joint 33 1 1100 I I Joint 34 Joint 35 IEEE.. 1150 1111 111111 Joint 36 111111111i IMEMME --,- 1/21111111 - Joint 37 1200 16111111111111 Err IMRE= _111.11.111111.1111 Joint 38 1111111111111•1111 = _ IriliMENNNI 1250 LElliE111111111111N ,.. Joint 39 i 11E11111 immosimmino Joint 40 1300 IIIIININENNIINIII _ IIIIINNIIININIEN _ 1111111111EINIEMEN :, Joint 41 IIIIIE INN , 1350 IMINIErgiiIIIIIINN Joint 42 INIIIIIHMEINIMIE INUINIMANNIIIIIII ...- 111114111111 Joint 43 1400 Joint 44 Joint 45 1450 Joint 46 1500 Joint 47 Joint 48 1550 Joint 49 1600 Joint 50 Joint 51 1650 Joint 52 1700 Joint 53 Joint 54 ii 1750 8 Joint 55 1 - I - Joint 56 1800 -0 Joint 57 1850 -i Joint 58 Joint 59 1900 • • i.. Joint 60 Ii 1950 . II Joint 61 ; 1114.11rIPMEMEMO 3C, EINES/IMIE111111 - Joint 62 11111111.11 MEM= ',.- v-, IIIIIIIMINIIIIIIIIIIIM .,., 2000 .....r.. ... , Joint 63 IERE mill .fflEitunm... ..„ Joint 64 2050 IMIIIIIIIIIIIIIIIIIII 7, Numme4NENNE --. ..:, 11111111111i1M11111111111 ...,- Joint 65 1111111111111111111 Joint 66 2100 MUNINEFIIIIIME _, ..,..-. EMEIRMINIEMINI Si ,..: Joint 67 10 2150 IMINIMMEMENIM - 11111111111105 MIME 1111111IIIIHMEMEM ,- Joint 68 EINIMEll MEM= -..-. .... lig....E. -4 .11 2200 EIMER IMEINI . -- Joint 69 111 111 Joint 70 it 2250 11111.1111111.1111111111 =. Joint 71 Emmonimmo EMENDINENEE lil 111111011EHIEEMIIM Joint 72 2300 IIIIIIIIIIIIIIIIIIIMMI ,..„, 1111011111511111E111111 ..s. IMEMIR MEIN .,... _ Joint 73 111111111111111111111111111111E imigium .. 2350 -.1- Joint 74 1111111111111 „. 11111111Mall MIMI= e -7- Joint 75 111.1.1.1/11111111111111 2400 ill _ . ; • • Joint 761 -- Joint 77 2450 I 1.11111.11111 -- ,44 Joint 78 IMIllill 2500 1111111111.11 Joint 791 "' Joint 80 2550 I .:.,- Joint Joint 81 III 2600 Joint 82 1111 •111111111 Joint 83 111 2650 ii 1 Joint 84 Joint 85 2700 lai Joint 86 Pup Joint 2750 IIM. GLM 1 — : .9 _ _ . IIIIIIIIIIIINF1 o Pup Joint : =; ,._ Joint 87 2800 Joint 88 ' I I Joint 89 2850 Joint 90 , 111 2900 Joint 91 • 0 Joint 92 11 .. 2950 li 4 ,.... - Joint 93 1111 Joint 94 3000 11 Joint 95 3050 Joint 96 1 _ Joint 97 31 1 00 24 Joint 98 fil _ ... 111 ". II ; 3150 Joint 99 II ir. Joint 100 3200 lira Joint 101 Joint 102 3250 ill • Joint 103 la ,.... 3300 it - Joint 104 11 — Ii Joint 105 3350 11 -72. •-.. Joint 106 3400 ! ti Joint 107 I • Joint 108 3450 • Joint 109 Joint 110 3500 Joint 111 3550 Joint 112 Joint 113 3600 Joint 114 g 3650 Joint 115 Joint 116 3700 Joint 117 Joint 118 3750 Joint 119 3800 Joint 120 -g; Joint 121 3850 Joint 122 3900 Joint 123 Joint 124 • • 3950 ' .. Joint 125 Joint 126 4000 Joint 127 4050 • Joint 128 Joint 129 4100 ; Pup Joint GLM 2 Allr Pup Joint Joint 130 4150 Joint 131 4200 Joint 13211 t Joint 133 4250 Joint 134 Joint 135 4300 : L Joint 136 4350 1 V Joint 137 Joint 138 4400 Joint 139 1 , 4450 • m. • • Normal Joint 141 4500 Joint 142 I o i i 4550 iII.Joint 143 , Joint 144 4600 Joint 145 ta: Joint 146 4650 Joint 147 — 4700 Joint 148 normal ' 4750 normal t . 4800 lu."--- Joint 151 Joint 152 4850 , Joint 153r=::....... Joint 154 4900 = 1 Joint 155 ‘liw: 4950 , Joint 156 • • all Pup Joint ArA .. GLM 3 mg_______ Pup Joint 5000 , Joint 157 II MI Joint 158 5050 AI , .:, Joint 159 Pal 5100 Joint 160 1 Joint 161 5150 I Joint 162 Joint 163 5200 -• Joint 164 1 . _ 5250 i . Joint 165 Joint 166 5300 Joint 167 . .._ 5350 Joint 168 II Joint 169 - 5400 Joint 170 Joint 171 5450 111 ,--....... . • Joint 172 5500 • Joint 173 Joint 174 • • 5550 Joint 175 5600 Joint 176 Pup Joint GLM 4 Pup Joint 5650 Joint 177 Joint 178 5700 Joint 179 Joint 180 5750 Joint 181 5800 Joint 182 Joint 183 5850 Joint 184 5900 Joint 185 Joint 186 5950 Joint 187 • • ___ , Joint 188 6000 Joint 189 t . Pup Joint 6050 GLM 5 -T-e \ _ IF i Pup Joint Joint 190 6100 Pup Joint , 1 Nipple Pup Joints WLEG ainn I 2.625"Dummy Whipstock Diameter I- 2.5 inches 3.5 Minimum I.D. I 2.5 inches 3.5 Maximum I.D. 2.5 inches 3.5 Comments Depth Nominal I.D. 3-D Log Image Map I • + 1ft:600ft 2.5 inches 3.50° 0° 90° 180° 270° 0° • • 1 Ca PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3H-26 Date : Junly 7, 2017 Description : Detail of Caliper Recordings Across 5.5 Inch Casing Logged. Comments Depth Nominal I.D. 3-D Log Image Map I1ft:150ft 3.5 inches 5.5 0° 0° 90° 180° 270° 0° Maximum I.D. I I 3.5 inches 5.5 Minimum I.D. I 3.5 inches 5.5 4"Minimum Setting Diameter h. I 3.5 inches 5.5 v I1.V 3.5"Tubing • Pup Joint 6130 IL . 3 • II __ 6140 __ S I _ _ Joint 1 6150 4 • • • : , Heavy Scale , _. Min.I.D.=4.20" : I 7, 6160 ` _ 6170 Ii __ i ,,,..__ 6180 _~ 41 6190 ; Joint 2 . Heavy Scale Min.I.D.=4.22" 6200 6210 I( • t 6220 - 6230 --_ Joint 3 P Perforations i Heavy Scale 6240 -_ Min.I.D.=3.34' 6250 111.111 . 6260 _. 6270 - -__ -41111111t- IOW Joint 4 _ Perforations lrit— _ 6280 Heavy Scale Min.I.D.=2.96" 6290 6300 Joint 5 Scale Min.I.D.=4.41" 4"Minimum Setting Diameter I- i 3.5 inches 5.5 Minimum I.D. I I 3.5 inches 5.5 Maximum I.D. 3.5 inches 5.5 Comments Depth Nominal I.D. 3-D Log Image Map 17- --ice 1ft:150ft 3.5 inches 5.5: 0° 0° 90° 180° 270° 0° • • Correlation of Recorded Damage to Borehole Profile IPipe 1 3.5 in (19.7'-6,126.1') Well: 3H-26 Pipe 2 5.5 in (6,126.1'- 6,309.2') Field: Kuparuk Company: ConocoPhillips Alaska,Inc. Country: USA Survey Date: July 7,2017 . Approx.Tool Deviation ■ Approx. Borehole Profile 1 - 25 25 r 808 50 1,593 75 2,374 GLM1 - 100 3,174 Z - s ° 125 — 3,954 GLM2- 150 4,757 GLM 3 GLM 4 175 5,560 GLM5 1 6,131 5 6,301 0 50 100 Damage Profile(%wall)/Tool Deviation (degrees) Bottom of Survey=5 • Perforations • . Ca Minimum Diameter Profile Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 2.5 2.75 0.1- Fr20 L. 61 201 Ihi 14.2- 487 23 r 746 I I. 33- 1,060 ! 43- F 1,375 53- i 1,688 63- 1,999 73- 2,311 83 I L 2,623 L C. cu .Q 90 2,861 ._ E 3 Z 100 3,174 C o 110 3,487 0 120 - _- 3,799 129.1 ` 4,110 137- ` 4,350 147 4,663 156.1 ----: 4,977 164- - 5,218 174- 5,529 imp- 181 181 5,769 189.2 6,055 1 • PDS Report Overview �► Body Region Analysis Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE IBT Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT 2.992 in. 20 ft. 6,126 ft. Penetration (%wall) Damage Profile(%wall) 250 mil Penetration body 41.1 Metal loss body 0 50 100 0.1 7-- 200 150 100 50 43 0 = 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analyzed(total=210) 210 0 0 0 GLM 1 (3:30) 90 Damage Configuration(body) 10 8 — GLM 2 (12:00) 6 137 4 GLM 3 (3:00) 2 0 GLM 4(7:00) Isolated General Line Other Hole/ 181 Pitting Corrosion Corrosion Damage Pos.Hole GLM 5 (9:00) Number of joints damaged(total=0) —, 0 0 0 0 0 Bottom of Survey= 190.5 • • CVO PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT Tubing 2.992 in. 0.254 in. 20 ft 6,126 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 20 0 0.00 2 0 2.89 Pup Lt. Scale. 0.2 23 0 0.01 3 0 2.93 Pup 1 25 0 0.02 . 9 1 2.92 Lt. Scale. • 1.1 55 0 0.00 2 0 2.89 Pup Lt. Scale. 1.2 65 0 0.01 4 0 2.90 Pup Lt. Scale. 1.3 73 0 0.02 7 2 2.92 Pup Lt. Scale. -• 2 76 0 0.01 5 0 2.89 Lt. Scale. 3 108 0 0.02 7 0 2.90 Lt. Scale. 4 138 0 0.02 9 0 2.88 Lt. Scale. • 5 169 0 0.01 3 0 2.88 Lt. Scale. i 6 201 0 0.02 7 0 2.89 Lt. Scale. 0 7 232 0 0.01 5 0 2.88 Lt. Scale. 8 263 0 0.01 5 0 2.85 Lt. Scale. II 9 294 0 0.02 7 0 2.87 Lt. Scale. 10 10 324 0 0.01 5 0 2.88 Lt. Scale. II 11 356 0 0.01 5 0 2.89 Lt. Scale. i 12 386 0 0.02 9 0 2.90 Lt. Scale. • 13 418 0 0.02 7 0 2.87 Lt. Scale. • 14 449 0 0.02 7 0 2.87 Lt. Scale. 0 14.1 481 0 0.01 5 0 2.84 Pup Lt. Scale. 0 14.2 487 0 0 0 0 2.87 CAMCO BP-61 LANDING NIPPLE 14.3 488 0 0 0 0 2.85 Pup Lt. Scale. 15 495 0 0.01 3 0 2.90 Lt. Scale. i 16 526 0 0.01 5 0 2.88 Lt. Scale. 0 17 558 0 0.01 3 0 2.88 Lt. Scale. 18 589 0 0.02 7 0 2.85 Lt. Scale. 0 19 620 0 0.02 7 0 2.87 Lt. Scale. 0 20 652 0 0.03 10 0 2.87 Lt. Scale. • 21 683 0 0.03 10 0 2.87 Lt. Scale. • 22 715 0 0.02 7 0 2.87 Lt. Scale. II 23 746 0 0.01 3 0 2.86 Lt. Scale. 1 24 776 0 0.01 3 0 2.86 Lt. Scale. i 25 808 0 , 0.01 5 0 2.84 Lt. Scale. 26 840 0 0.02 9 0 2.85 Lt. Scale. • 27 871 0 0.01 3 0 2.87 Lt. Scale. 28 903 0 0.00 2 0 2.85 Lt. Scale. 29 934 0 0.00 2 0 2.86 Lt. Scale. 30 965 0 0.00 2 0 2.86 Lt. Scale. 31 997 0 0.02 9 0 2.85 Lt. Scale. • 32 1028 0 0.01 3 0 2.86 Lt. Scale. i 33 1060 0 0.00 2 0 2.85 Lt. Scale. 34 1092 0 0 0 0 2.85 Lt. Scale. 35 1123 0 0.01 3 0 2.86 Lt. Scale. 36 1155 0 0.01 5 0 2.86 Lt. Scale. 37 1186 0 0.01 3 0 2.86 Lt. Scale. 38 1218 0 0.02 7 0 2.87 Lt. Scale. 0 39 1250 0 0 0 0 2.87 Lt. Scale. 40 1280 0 0.01 5 0 2.86 Lt. Scale. 0 41 1312 0 0.01 3 0 2.87 Lt. Scale. 42 1343 0 0.01 5 0 2.87 Lt. Scale. II IPenetration Body Metal Loss Body Page 1 • • PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT Tubing 2.992 in. 0.254 in. 20 ft 6,126 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 43 1375 0 0.00 2 0 2.86 Lt. Scale. 44 1406 0 0.00 2 0 2.85 Lt. Scale. 45 1438 0 0 0 0 2.86 Lt. Scale. 46 1469 0 0.00 2 0 2.85 Lt. Scale. 47 1500 0 0.01 3 0 2.87 Lt. Scale. 48 1531 0 0.01 3 0 2.85 Lt. Scale. 49 1562 0 0 0 0 2.85 Lt. Scale. 50 1593 0 0.00 2 0 2.87 Lt. Scale. 51 1625 0 0.00 2 0 2.86 Lt. Scale. 52 1657 0 0.01 3 0 2.86 Lt. Scale. 53 1688 0 0.01 5 0 2.87 Lt. Scale. 54 1719 0 0.01 3 0 2.87 Lt. Scale. 55 1750 0 0.00 2 0 2.87 Lt. Scale. 56 1780 0 0.00 2 0 2.86 Lt. Scale. 57 1812 0 0 0 0 2.84 Lt. Scale. 58 1843 0 0.01 5 0 2.86 Lt. Scale. 59 1874 0 0.01 5 0 2.86 Lt. Scale. 60 1906 0 0 0 0 2.86 Lt. Scale. 61 193 7 0 0.01 5 0 2.85 Lt. Scale. 62 1969 0 0.01 3 0 2.86 Lt. Scale. 63 1999 0 0.01 3 0 2.84 Lt. Scale. 64 2031 0 0.00 2 0 2.84 Lt. Scale. 65 2061 0 0 0 0 2.86 Lt. Scale. 66 2092 0 0 0 0 2.84 Lt. Scale. 67 2123 0 0 0 0 2.85 Lt. Scale. 68 2154 0 0 0 0 2.87 Lt. Scale. 69 2185 0 0 0 0 2.84 Lt. Scale. 70 2217 0 0 0 0 2.88 Lt. Scale. 71 2248 0 0 0 0 2.88 Lt. Scale. 72 2279 0 0 0 0 2.88 Lt. Scale. 73 231 1 0 0 0 0 2.86 Lt. Scale. 74 2342 0 0 0 0 2.87 Lt. Scale. 75 2374 0 0 0 0 2.88 Lt. Scale. 76 2405 0 0 0 0 2.88 Lt. Scale. 77 2436 0 0 0 0 2.88 Lt. Scale. 78 2468 0 0 0 0 2.88 Lt. Scale. 79 2499 0 0 0 0 2.88 Lt. Scale. 80 2530 0 0 0 0 2.88 Lt. Scale. 81 2562 0 0 0 0 2.85 Lt. Scale. 82 2592 0 0 0 0 2.83 Lt. Scale. 83 2623 0 0 0 0 2.85 Lt. Scale. 84 2653 0 0.00 2 0 2.84 Lt. Scale. 85 2684 0 0 0 0 2.85 Lt. Scale. 86 271 5 0 0.00 2 0 2.87 Lt. Scale. 86.1 2747 0 0.02 7 0 2.91 Pup Lt. Scale. U 86.2 2754 0 0 0 0 2.89 GLM 1 (LATCH @ 3:30) 86.3 2760 0 0.02 7 0 2.86 Pup Lt. Scale. U 87 2768 0 0.00 2 0 2.88 Lt. Scale. 88 2799 0 0 0 0 2.83 Lt. Scale. 89 2830 0 0.00 2 0 2.83 Lt. Scale. IPenetration Body Metal Loss Body Page 2 • 41-11 PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT Tubing 2.992 in. 0.254 in. 20 ft 6,126 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 90 2861 0 0 0 0 2.82 Lt. Scale. 91 2892 0 0 0 0 2.82 Lt. Scale. 92 2923 0 0 0 0 2.83 Lt. Scale. 93 2955 0 0 0 0 2.84 Lt. Scale. 94 2986 0 0.00 2 0 2.84 Lt. Scale. 95 3017 0 0 0 0 2.84 Lt. Scale. 96 3048 0 0 0 0 2.83 Lt. Scale. 97 3080 0 0 0 0 2.84 Lt. Scale. 98 3112 0 0 0 0 2.85 Lt. Scale. 99 3143 0 0 0 0 2.85 Lt. Scale. 100 3174 0 0 0 0 2.83 Lt. Scale. 101 3205 0 0 0 0 2.83 Lt. Scale. 102 3236 0 0 0 0 2.83 Lt. Scale. 103 3267 0 0 0 0 2.83 Lt. Scale. 104 3298 0 0 0 0 2.83 Lt. Scale. 105 3330 0 0 0 0 2.84 Lt. Scale. 106 3361 0 0 0 0 2.83 Lt. Scale. 107 3392 0 0 0 0 2.83 Lt. Scale. 108 3424 0 0 0 0 2.84 Lt. Scale. 109 3455 0 0 0 0 2.82 Lt. Scale. 110 3487 0 0.00 2 0 2.83 Lt. Scale. 111 3518 0 0 0 0 2.81 Scale. 112 3548 0 0 0 0 2.82 Lt. Scale. 113 3580 0 0 0 0 2.82 Lt. Scale. 114 3611 0 0 0 0 2.81 Lt. Scale. 115 3642 0 0 0 0 2.84 Lt. Scale. 116 3673 0 0 0 0 2.84 Lt. Scale. 117 3705 0 0 0 0 2.83 Lt. Scale. 118 3736 0 0 0 0 2.84 Lt. Scale. 119 3767 0 0 0 0 2.85 Lt. Scale. 120 3799 0 0 0 0 2.83 Lt. Scale. 121 3830 0 0 0 0 2.84 Lt. Scale. 122 3862 0 0 0 0 2.86 Lt. Scale. 123 3892 0 0 0 0 2.85 Lt. Scale. 124 3923 0 0 0 0 2.84 Lt. Scale. 125 3954 0 0 0 0 2.84 Lt. Scale. 126 3986 0 0 0 0 2.84 Lt. Scale. 127 4017 0 0.01 5 0 2.84 Lt. Scale. 128 4048 0 0 0 0 2.85 Lt. Scale. 129 4079 0 0 0 0 2.85 Lt. Scale. 129.1 4110 0 0 0 0 2.89 Pup Lt. Scale. 129.2 4117 0 0 0 0 2.83 GLM 2(LATCH @ 12:00) 129.3 4124 0 0.02 7 1 2.83 Pup Lt. Scale. 130 4131 0 0 0 0 2.81 Scale. 131 4163 0 0 0 0 2.83 Lt. Scale. 132 4194 0 0 0 0 2.84 Lt. Scale. 133 4226 0 0 0 0 2.83 Lt. Scale. 134 4258 0 0 0 0 2.85 Lt. Scale. 135 4289 0 0 0 0 2.80 Scale. 136 4319 0 0 0 0 2.81 Scale. IPenetration Body Metal Loss Body Page 3 • • tit 0, PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT Tubing 2.992 in. 0.254 in. 20 ft 6,126 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 137 4350 0 0 0 0 2.80 Scale. 138 4382 0 0 0 0 2.81 Lt. Scale. 139 4414 0 0 0 0 2.81 Scale. 140 4445 0 0 0 0 2.82 Lt. Scale. 141 4477 0 0 0 0 2.82 Lt. Scale. 142 4507 0 0 0 0 2.80 Scale. 143 4538 0 0 0 0 2.82 Lt. Scale. 144 4569 0 0 0 0 2.81 Scale. 145 4601 0 0 0 0 2.82 Lt.Scale. 146 4632 0 0 0 0 2.81 Scale. 147 4663 0 0 0 0 2.83 Lt. Scale. 148 4695 0 0 0 0 2.81 Lt. Scale. 149 4726 0 0 0 0 2.81 Lt. Scale. 150 4757 0 0 0 0 2.81 Scale. 151 4789 0 0 0 0 2.67 Scale. 152 4821 0 0 0 0 2.82 Lt. Scale. 153 4852 0 0 0 0 2.80 Scale. 154 4883 0 0 0 0 2.81 Scale. 155 4914 0 0 0 0 2.82 Lt. Scale. 156 4946 0 0 0 0 2.81 Scale. 156.1 4977 0 0 0 0 2.83 Pup Lt. Scale. 156.2 4985 0 0 0 0 2.80 GLM 3(LATCH ©3:00) 156.3 4992 0 0 0 0 2.82 Pup Lt. Scale. 157 4999 0 0 , 0 0 2.81 Scale. 158 5030 0 0 0 0 2.78 Scale. 159 5061 0 0 0 0 2.77 Scale. 160 5092 0 0 0 0 2.77 Scale. 161 5124 0 0 0 0 2.77 Scale. 162 5155 0 0 0 0 2.76 Scale. 163 5187 0 0 0 0 2.77 Scale. 164 5218 0 0 0 0 2.76 Scale. 165 5248 0 0 0 0 2.75 Scale. 166 5280 0 0 0 0 2.76 Scale. 167 5311 0 0 0 0 2.76 Scale. 168 5342 0 0 0 0 2.74 Scale. 169 5373 0 0 0 0 2.72 Scale. 170 5404 0 0 0 0 2.75 Scale. 171 5436 0 0 0 0 2.74 Scale. 172 5467 0 0 0 0 2.74 Scale. 173 5498 0 0 0 0 2.73 Scale. 174 5529 0 0 0 0 2.75 Scale. 175 5560 0 0 0 0 2.76 Scale. 176 5591 0 0 0 0 2.77 Scale. 176.1 5623 0 0 0 0 2.77 Pup Scale. 176.2 5631 0 0 0 0 2.83 GLM 4(LATCH C©7:00) 176.3 5636 0 0 0 0 2.81 Pup Scale. 177 5645 0 0 0 0 2.74 Scale. 178 5675 0 0 0 0 2.74 Scale. 179 5707 0 0 0 0 2.74 Scale. 180 5739 0 0 0 0 2.77 Scale. IPenetration Body Metal Loss Body Page 4 • • PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE IBT Tubing 2.992 in. 0.254 in. 20 ft 6,126 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 181 5769 0 0 0 0 2.75 Scale. 182 5800 0 0 0 0 2.73 Scale. 183 5831 0 0 0 0 2.63 Scale. 184 5862 0 0 0 0 2.73 Scale. 185 5894 0 0 0 0 2.73 Scale. 186 5925 0 0 0 0 2.73 Scale. 187 5956 0 0 0 0 2.72 Scale. 188 5987 0 0 0 0 2.71 Scale. 189 6018 0 0 0 0 2.72 Scale. 189.1 6047 0 0 0 0 2.73 Pup Scale. 189.2 6055 0 0 . 0 0 2.77 GLM 5(LATCH @ 9:00) 189.3 6062 0 0 0 0 2.71 Pup Scale. 190 6069 0 0 0 0 2.70 Scale. 190.1 6099 0 0 0 0 2.73 Pup Scale. 190.2 6106 0 0 0 0 2.73 CAMCO DS NIPPLE 190.3 6106 0 0 0 0 2.74 Pup Scale. 190.4 6113 0 0.03 10 0 2.76 Pup Scale. 190.5 6126 0 0 0 0 3.34 WLEG Penetration Body Metal Loss Body Pages • • PDS Report Cross Sections Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE IBT Analyst: C.Waldrop Cross Section for Joint 183 at depth 5,847.927 ft. Tool speed=49 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=31° 40. 1 rt, Minimum I.D.=2.630 in. Scale Minimum I.D.=2.63 in. HIGH SIDE=UP • • PDS Report Cross Sections Cita Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L-80 EUE IBT Analyst: C.Waldrop Cross Section for Joint 151 at depth 4,801 .1 70 ft. Tool speed= 51 Nominal ID=2.992 Nominal OD=3.5 Remaining wall area= 100% Tool deviation=36° Minimum I.D.=2.669 in. Scale Minimum I.D.=2.67 in. HIGH SIDE=UP • • Minimum Diameter Profile 144S, Well: 3H-26 Survey Date: July 7, 2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 4.892 inches Minimum Measured Diameters (in.) 1.75 2 2.5 3 3.5 4 4.5 ---■ 6,126 0.1 -. 6,131 1 mom 6,173 2 ti- � .0 E O 7 Z moms 6,216 C +• o a 3 6,259 4 -■ 6,301 5 • • PDS Report Overview Body Region Analysis Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 5.5 in. 17 ppf L-80 LTC Analyst: C.Waldrop Pipe Nom.OD Weight Grade&Thread Nom.ID Top Depth Bottom Depth 5.5 in. 17 ppf L-80 LTC 4.892 in. 6,126 ft. 6,309 ft. Penetration(%wall) Damage Profile(%wall) 10 - Penetration body =a• Metal loss body 0 50 100 0.1 8 6 4 1 2 0 0 to 20 to 40 to over 2 20% 40% 85% 85% Number of joints analyzed(total=6) 3 0 0 0 3 Damage Configuration(body) 10 8 6 4 ■-- 4 2 5 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos.Hole Number of joints damaged(total=0) 0 0 0 0 0 Bottom of Survey=5 = Perforations • • 1 illi PDS Report Joint Tabulation Sheet Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Analyst: C.Waldrop Company: ConocoPhillips Alaska,Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 5.5 in. 17 ppf L-80 LTC Casing 4.892 in. 0.304 in. 6,126 ft. 6,309 ft. Joint Jt.Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (in.) (in.) % (in.) 0 50 100 0.1 6126 0 0 0 0 3.76 Pulp Heavy Scale. 1 6131 0 0 0 0 4.20 Heavy Scale. 2 6173 0 0 0 0 4.22 _Heavy Scale. 3 6216 0 0.54 100 10 3.34 Perforations Heavy Scale. 4 6259 0 0.81 100 8 2.96 Perforations Heavy Scale. 5 6301 0 0 0 0 4.41 Perforations Scale. I Penetration Perforations Body Metal Loss Perforations 'Penetration Metal Loss Body Page 1 • S III Lig . PDS Report Cross Sections Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska,Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 5.5 in. 17 ppf L-80 LTC Analyst: C.Waldrop Cross Section for Joint 4 at depth 6,263.313 ft. Tool speed=49 Nominal ID=4.892 .:. Nominal OD=5.5 Remaining wall area= 100% Tool deviation= 16° i i %1 ::* I I I \\ 1 Minimum I.D.=2.962 in. Heavy Scale Minimum I.D.=2.96 in. HIGH SIDE=UP • • PDS Report Cross Sections LAO S Well: 3H-26 Survey Date: July 7,2017 Field: Kuparuk Tool Type: UW MFC 24 Ext. No.214040 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 5.5 in. 17 ppf L-80 LTC Analyst: C.Waldrop Cross Section for Joint 3 at depth 6,254.854 ft. Tool speed=48 Nominal ID=4.892 IONS Nominal OD=5.5 Remaining wall area= 100% Tool deviation= 19° Minimum I.D.=3.335 in. Heavy Scale Minimum I.D.=3.34 in. HIGH SIDE=UP KUP PROD • 3H-26 ConocoPhillips 01 Well Attributes Max Angle&MD TD Alaska,Inc. Weubore APvuWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cmoco,11.p 501032020800 KUPARUK RIVER UNIT PROD 39.20 5,149,90 6,660.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-26,6261201712'.37'.04 PM SSSV:NIPPLE 190 12/4/2016 Last WO: 4/29/2005 40.99 3/6/1994 Vertical athematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 6,330.0 5/17/2017 Rev Reason:H2S,TAG,GLV C/O pproven 6/26/2017 HANGER;37.8 .r,"'+,°�. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WILen(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(968) 'Set Depth)TVD)... Wt/Len(I...Grade Top Thread , , . SURFACE 75/8 6.875 40.9 3,142.8 3,140.3 29.70 L-80 LTC 4IIII Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread {{4 PRODUC©65TION 51/2 4.276 38.7 6,643.1 6,290.9 17.00 L-80 LTC rj 5.5s5" 52' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection I ,TUBING WO 31/2 2.992 37.8 6,126.0 5,793.1 9.30 L-80 EUE IBT Completion Details Nominal ID CONDUCTOR,40 9-121 0 Top(ftKB) Top(ND)(ftKB) Top Ind(*) Item Des Corn (in) 37.8 37.8 0.09 HANGER FMC TUBING HANGER 3.500 I504.2 504.2 1.16 NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6 21.13 NIPPLE CAMCO'DS'NIPPLE 2.812 NIPPLE;504 • 6,113.2 5,781.1 20.99'LOCATOR BAKER GBH-22 LOCATOR 2.850 6,113.5 5,781.4 20.98 SEAL ASSY BAKER BOT GBH-22 SEAL ASSY 2.85"DRIFT 2.980 Perforations&Slots I Shot Dens Top(ND) Btm(ND) (shots/f GAS LIFT.2765.7 - Top(ftKB) Btm(ftKB) (MB) (ftKB) Zone Date t) Type Corn 6,250.0 6,280.0 5,910.0 5,938.6 C-4,C-3,3H- 6/15/1998 4.0 RPERF 2 1/8"EnerJet,0 deg ph I 26 6,250.0 6,280.0 5,910.0' 5,938.6 C-4,C-3,3H- '4/9/1997 4.0 IPERF 1 11/16"PIVOTS,180 26 deg.ph • 6,306.0 6,336.0 5,963.4 5,992.2 A-3,A-2,3H- '6/24/1994 4.0 IPERF 2 1/8"EnerJet,90 deg. 26 ph Mandrel Inserts St SURFACE;40.93,142.8JI atl N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) )ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com -')` 2,765.7 2,763.5 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 1,242.0 6/24/2017 9 GAS LIFT;4,124.4 - - 2 4,124.4 4,096.2 CAMCO KBG-2- 1 GAS LIFT OV BTM 9 0.250 0.0 6/25/2017 111 3 4,987.6 4,836.7 CAMCO KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 1/3/2016 9 I4 5,630.9 5,351.9 CAMCO KBG-2- 1 GAS LIFT DMY DK-1 0.000 0.0 6/30/2005 9 /11 5 6,055.1 5,727.0 CAMCO KBG-2- . 1 GAS LIFT DMY DK-1 0.000 0.0 6/30/2005 GAS LIFT,4987.6 I9 Notes:General&Safety End Date Annotation 4/29/2005 NOTE:TREE:FMC 3-1/8""/GEN IV/5000 psi rated 11/26/2009 NOTE:View Schematic w/Alaska Schematic9.0 II GAS LIFT,5,630.8 1 II GAS LIFT;6.055.1 NIPPLE',6,106.2 ir t ' g SEAL ASSY,6,113.5 Z. Ai a RPERF,6,250.0-6280.0, .' (PERF;6,250.0-6,280.0 IPERF,6,306.0-6,336.0 J PRODUCTION 5.5x5'56552': dl rA 38.7-6,643.1 WrcE W • yyy O CD oN W L F- (471 ( 0 LU N >` v �rY -10 a— o � CO � o 0 z�_ - a, O L o s 3 � � � � C to (7) VE �V • c e- u ++ > n`. a v c >, O as +, ra .: a, fs W @ C a coC M _ v a < In o ¢ t"7 0 r v u 6 m + J 0 a � 0 l0 CO 14 > '� Y O �Q c C cp u L a V G N ~ N N N 0 U -0co 0 4-' Z0 a-) E u Z g. L v ,> O a +C+ u ''' co O 41 0 0 ci cp ru a) -0 Ln U a J J J J 4-Co _O y, W_ W W_ W_ a) '- F- LL it LL LL a C < J J J JC w r, L0Q Q Q Q U (0 a1 O Cr, '12222 a) L a) > ,O Cy LL LL LL LL CC L C > ��jrL. to +u, > N +' _c O L N E a u a a) u > O CS z w 00 > .r U R7 C O _ v. C O Or @ > u C .. Z fr n. C • C co a O o C O al .., u v = Q v a a m LL � a iri 'E C3 o QQNo 13N G m V U o ri E O cc 3 CD oo U ) U ? 0 \ o Leb ▪ a°h *6d N m W o Z 44 - . W V Z'. • IL o M / Ix ce CC re °�. W W W W4 L" > > > > z Y YMnDn LU ° CC cc Y Y W W W Q Q 2 LL 0. a a O. 111 0 C'V Y Y Y Y 0 pp O X in W {n W N O O NITI N V NN N0 N E 0 cc O 0 O O O OLu N W ' 0co 088 m O O O O W crs GO CO U) o 00o a CC '^ a. u re ' Li- O E 0 S @ O O O O +' O O O O O 73 : Q Mt 00 OO OO O 4,N O O r!) !� = a I(f*�V1 N N H — N 0 0 0 L N N N N vi • L Rs 8M M M c o o_ N O O O CO u 0 01 O O .,,. O O O O +' Y C O 121, G E a) o`_o . a W Nle `W cc N Ecc) E N To c A. e as v. Z M h0 mn_�1 z O N N 7 _� C 01 N N N d Q J N M M N VCI z w o o 'C r•rl C ^ CO O 0C/9 aa � aaF t- • • REDWED ConocoPhillips OCT 2 3 2015 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 October 20, 2015 o a r Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7t''Avenue, Suite 100 stow iMM 1 '1 L016 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, /ft MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor • S ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10120/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 .r.,„0), 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 3Q-21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing Change Approved Program Rug for Redrill Perforate New Pool r Repair Well r Re-enter Susp Well Other:Conductor Extension �'. 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pi Exploratory r _ 194-029 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20208-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025531 KRU 3H-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 6660 feet Plugs(measured) None true vertical 6308 feet Junk(measured) None Effective Depth measured 6653 feet Packer(measured) 6114 true vertical 6301 feet (true vertical) 5781 Casing Length Size MD TVD Burst Collapse CONDUCTOR 81 16 121 120 0 0 SURFACE 3102 10 3143 3140 0 0 PRODUCTION 6604 5.5 6643 5782 0 0 Prod Liner 506 5 6640 6228 0 0 Perforation depth: Measured depth: 6250-6280',6306-6336' RECEIVED True Vertical Depth: 5910-5939', 5963-5992' SCA NE t7F ( 1 5 zU15 OCT 1. 3 2015 Tubing(size,grade,MD,and TVD) 4.5, L-80, 6114 MD,5781 TVD AOGCC Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER BOT GBH-22 SEAL ASSY 2.85"DRIFT @ 6114 MD and 5781 TVD NIPPLE-CAMCO BP-61 LANDING NIPPLE @ 504 MD and 504 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p' Exploratory r Development J7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas r WDSPL r Printed and Electronic Fracture Stimulation Data IT GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-529 Contact MJ Loveland\Martin Walters Email N1878@ConocoPhillips.com Printed Name MJ Loveland Title WI Project Supervisor Signature AV7-17-r-da4Phone:659-7043 Date 10-11-2015 rTL /o`liy/- Form 10-404 Revised 5/2015 )CJRBDMS (11:1 14 2015 Submit Original Only • • 3H-26 • DESCRIPTION OF WORK COMPLETED SUMMARY Date10111/15 Event Summary 09/27/15 Welded 12"x16" .375 62# extension onto the existing conductor 10/09/15 Injected 4.3 gallons of RG2401 sealant into the conductor. • 3H-26 • L DESCRIPTION OF WORK COMPLETED SUMMARY OF �w-I j7,- ,v THE STATE Alaska Oil and Gas % �� of Conservation Commission ALAsKA. x_ _�j 333 West Seventh Avenue . GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 ALAS1�� ° Fax: 907.276.7542 SCpN www aogcc.alaska.gov MJ Loveland 094 WI Project Supervisor I ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-26 Sundry Number: 315-529 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. 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, P Cathy P Foerster Chair DATED this 86—day of September, 2015 RBDM 2015 SEP 0 9 Encl. • STATE OF ALASKA AL _..)KA OIL AND GAS CONSERVATION COM. ,SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Extension P-, 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc • Exploratory r Development r• 194-029 - 3.Address Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20208-00 ' 7 If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? / Will planned perforations require spacing exception? Yes r No ' KRU 3H-26 ' 9.Property Designation(Lease Number): 10 Field/Pool(s): ADL0025531• Kuparuk River Field/Kuparuk River Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total depth MD(ft) Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6660 - 6308 , 6653' - 6301' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 120' SURFACE 3102 10 3143' 3140' it F C E IV E D PRODUCTION 6097 5 5 6114' 5782' /3a S s lB l k s Prod Liner 506 5 6640' 6228' AUG 2 8 2015 AOGCC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6250-6280', 6306-6336' 5910-5939', 5963-5992' 4.5 0 6114 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SEAL ASSY-BAKER BOT GBH-22 SEAL ASSY 2.85"DRIFT MD=6114 TVD=5781 NIPPLE-CAMCO BP-61 LANDING NIPPLE MD=504 TVD=504 ,, 12 Attachments Description Summary of Proposal P. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r 4 Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/20/2015 WINJ r WDSPL r Suspended r OIL F - 16.Verbal Approval: Date GAS r WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland\Martin Walters Email: N1878@ConocoPhillips.com Printed Name MJ Loveland itle: WI Project Supervisor _ Signature Phone:659-7043 Date ��a S----15— Commission Use Only Sundry Number. Conditions of approval: Notify Commission so that a representative may witness 36- 5 2-. Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required l 4(.;4 na ssI E TAHPPRGOVNIEMD BY _� Approved by pp p To 11L months fro ttiC Iat�oTI3SOl01y Date: J n r. •. a ication is va val. i' g Iagis Submit Form and Form 10-403Rgl4/l.- ORIGINAL L7 rlRBDMS� SE�ttpcf�n2 �i Duplicate „,, ,A,4,__ � U J �u rd ~v • • ConocoPhillips Alaska RECEIVED P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AUG 2 8 2015 AOGCC August 25, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3H-26, PTD 194-029 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. / , / Sincerely,7MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. Kuparuk Well 3H-26 (PTD 194-029) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 25, 2015 This application for Sundry approval for Kuparuk well 3H-26 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 12". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD 3H-26 ConocoPhillips ' Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UW Field Name Wellbore Status ncl(^) MD(ftKB) Act Btte(ftKB) cr.ra4d+l:Ikps 501032020800 KUPARUK RIVER UNIT PROD 3920 5,149.90 6,660.0 ... µ~ Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3H-26,3/25/20158:41:10 AM SSSV:NIPPLE 140 12/25/2014 Last WO: 4/29/2005 40.99 3/6/1994 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,323.0 3/22/2015 Rev Reason:GLV C/O,TAG lehallf 3/24/2015 HANGER,37.6 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread ,,,,..,,m,.,.,,,.,,,,, SURFACE 75/8 6.875 40.9 3,142.8 3,140.3 29.70 L-80 LTC Casing Description OD(in) ID(10) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(L..Grade Top Thread _ PRODUCTION 512 4.276 38.7 6,643.1 6,290.9 17.00 L-80 LTC 5.5x5"@6552' Tubing Strings Tubing Description String Ma...ID iinl Top(1140) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/I1/ Grade Top Connection Mme_7,,,,TUBING WO 3112 2.992 37.8 - 6,126.0 5.793.1 9.30 L-80 EUE IBT Completion Details Nominal ID CONDUCTOR,40.9-17.1.0-+ Top(ftKB) Top(TVD)OMB) Top Incl('I Item Des Corn (In) 37.8 37.8 0.09 HANGER FMC TUBING HANGER 3.500 504.2 504.2 1.16'NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6 21.13 NIPPLE CAMCO'DS'NIPPLE 2.812 NIPPLE,504.2 6,113.2 5,781.1 20.99'LOCATOR 'BAKER GBH-22 LOCATOR 2.850 �� 6,113.5' 5,781.4 20.98 SEAL ASSY BAKER BOT GBH-22 SEAL ASSY 2.85"DRIFT 2.980 Perforations&Slots I Shot Den Top(ND) Ben(TVD) (shots/f j:--� Top(ftKB) Btrn(MB) (I1(B) (1tl(B) Zone Date t) Type Com GAS LIFT.2.765 7 `J 6,250.0 6,280.0 5,910.0 5,938.6 C-4,C-3,3H- 6/15/1998 4.0 RPERF '2 1/8"EnerJet,0 deg ph 26 6,250.0 6,280.0 5,910.0 5,938.6 C-4,C-3,3H- 4/9/1997 4.0 IPERF 1 11/16"PIVOTS,180 26 deg.ph 6,306.0 6,336.0 5,963.4 5,9922 A-3,A-2,3H- 6/24/1994 4.0 IPERF 2 1/8"EnerJet,90 deg. 26 ph ( Mandrel Inserts St ati SURFACE;10.43,142.8-A eto on N Top(ftKB) Top(ftKB) Make Model OD(in) Sery Tara LatchType Port TRO(psi) Run Date Corn 2,765.7 2,763.5 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.156 1,230.0 3/22/2015 9 Ili 2 4,124.4 4,096.2 CAMCO KBG-2- 1 GAS LIFT GLV BTM 0.188 1,281.0 322/2015 GAS LIFT;4,1244 9 3 4,987.6 4,836.7 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 322/2015 9 - 4 5,630.9 5,351.9 CAMCO KBG-2- 1 GAS LIFT DMY DK-1 0.000 0.0 6/30/2005 9 - - 5 6,055.1 5,727.0 CAMCO KBG-2- 1 GAS LIFT DMY DK-1 0.000 0.0 6/30/2005 9 GAS LIFT,49676 H Notes:General&Safety End Date Annotation 4/2972005 NOTE:TREE:FMC 3-1/8""/GEN IV/5000 psi rated 11/26/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT',5,630.8Ei GAS LIFT;6,055.1 I NIPPLE;6,106.2VA iti. SEAL ASSY;6,113 5 RPERF;6,250.06,280.0, - !PERF;6,250.0.6.280.0 s ..-. IPERF;6,306.0-6,336.0 PRODUCTION 5.56506552`, S 38.76.643.1 Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, March 20, 2015 2:12 PM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler Subject: Kuparuk producer 3H-26 (PTD 194-029) Reported with high IA pressure. Attachments: image001.png; 3H-26 90 Day TIO plot.JPG; 3H-26.pdf Chris- Kuparuk producer 3H-26 (PTD 194-029) was reported with sustained casing pressure above 2000 psi by operations on the 20th of March. The well was shut in for a failed safety valve test and has remained shut in since then. At this time diagnostic testing is scheduled using slick line, e-line and/or DHD to determine the source of high IA pressure and attempt to mitigate it. If the source of pressure cannot be mitigated the well will be secured and a plan forward for corrective action will be formulated. Pending the outcome of the diagnostics, the appropriate paperwork will be submitted. The well has 5.5 inch, 17 Ib, L-80 casing with a burst rate of 7740 psi. The IA is currently at approximately 2600 psi which does not exceed 3483 psi, which is 45 percent of the burst rate. Attached are a well bore schematic and a 90 day T/I/0 plot. Please let me know if you have any questions or disagree with the plan. Dusty Freeborn /Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907)943-0450 SCANNED MAR 2 4 2015 WELLS TEAM Conoccittillps1 w U_ CC LU w tel C9 w Le/ w a o �n � w a ar x y w m � w a. a U, w 1 0 u-i �6ap 0 in CO Ci 2 N U U, 1 1 1 1 1 1 1 1 u7 co N V C 3 CO r'a 7 V C Z Q y IYl 1 C W � 1 � T T N N `si > e C d = Q7 O M aN T M d a� = Q 2 S o < E :: C) / m : n • EU w o O 0 0 O 0 0 p :h } U Q Z O N D o0 U N o 00 o a' Dale oiati Cl>• Ndw ISd KUP PROD 3H-26 • ConocoPhillips t Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncI I') MD(hKB) Act Btm OMB) Maps 501032020800 KUPARUK RIVER UNIT PROD 3920 5,149.90 6,660.0 ... Comment NES(ppm) Data Annotation End Date KB-Grd(ft) `Rig Release Date 3H-26.8/28/2014 1.24.29 PM SSSV:NIPPLE 120 12/16/2013 Last WO: 4/29/2005 40.99 3/6/1994 Ventral schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,300.0 6/182014 Rev Reason:GLV C/O,TAG lehallf 6/26/2014 HANGER;3]8 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(hKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 40.9 121.0 121.0 6250 H-40 WELDED Casing Description "OD(in) ID(in) Top(BKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread ....,..................�.....-........... SURFACE 75/8 6.875 40.9 3,142.8 3,140.3 29.70 L-80 LTC I Casing Description 'OD(in) ID(in) Top(NKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len 0...Grade 'Top Thread ` PRODUCTION 5 1/2 4276 38.7 6.643.1 6,290.9 17.00 L-80 LTC i 5.5x5"@6552' Tubing Strings Tubing Description String Ma...ID)in) Top(hKB) Set Depth(ft..1Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection . TUBING WO 3 1/2 2.992 37 8 6.126.0 5,793.1 930 L-80 EUE IBT Completion Details Nominal ID Top(MB) Top(ND)(HMI) Top!not(°) Item Des _ Com (in) CONDUCTOR:40.8-121.0 37.8 37.8 0.09 HANGER FMC TUBING HANGER 3.500 504.2 5042 1.16 NIPPLE CAMCO BP-61 LANDING NIPPLE 2.875 6,106.2 5,774.6- 21.13 NIPPLE -CAMCO'DS'NIPPLE 2.812 NIPPLE,504.2 is 6,113.2 5,781.1 20.99 LOCATOR BAKER GBH-22 LOCATOR 2.850 6,113.5 5,781.4 20.98 SEAL ASSY 'BAKER BOT GBH-22 SEAL ASSY 2.85"DRIFT 2.980 • Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shotslf GAS LIFT,2.76E7 II Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Data t) Type Com 6,250.0 6,280.0 5,910.0 5,938.6 C-4,C-3,3H- 6/15/1998 26 4.0'RPERF '2 1/8"EnerJet,0 deg ph 6,250.0 6,280.0' 5,910.0 5,938.6 C-4,C-3,3H- 4/9/1997 4.0 IPERF 1 11/16"PIVOTS,180 26 deg.ph 6,306.0 6,336.0' 5,963.4 5,992.2 A-3,A-2,3H- '6/24/1994 4.0 IPERF 2 1/8"EnerJet,90 deg. 26 ph Mandrel Inserts St MI SURFACE:40.a-3,1428-A l= N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (MB) Make Model •OD(In) UV Type Type (in) (psi) Run Date Com -1 2,765.7 2,763.5 CAMCO KBG-2- ' 1'GAS LIFT GLV BTM 0.156 1,230.0 6/24/2014 9 2 4,124.4 4,096.2 CAMCO KBG-2- ' 1"GAS LIFT GLV BTM 0.188 1,281.0 6/20/2014 GAS LIFT.4,1244 C; 9 3 4,987.6 4,836.7 CAMCO KBG-2- 1 GAS LIFT OV BTM 0.250 0.0 6/21/2014 9 - 4 5,630.9 5,351.9 CAMCO KBG-2- ' 1'GAS LIFT "DMY DK-1 0.000 0.0 6/30/2005 9 5 6,055.1 5,727.0 CAMCO KBG-2- 1 GAS LIFT DMY DK-1 0.000 0.0 6/30/2005 9 GAS LIFT.4,097.6 I t- Notes:General&Safety End Date Annotation 4/29/2005 NOTE:TREE:FMC 3-1/8""/GEN IV/5000 psi rated - 11/26/2009 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,5,830.8 GAS LIFT;6.055.1 IIMMI NIPPLE;8.1002- SEAL ASSY.6 113 5 RPERF;8,25000,200.0 IPERF;8.250.0-0,200.0 1_.: IPERF;8,308.0-0,338.0 PRODUCTION 5.5x53G8552 a 39.7-0,843.1 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned bY: (~ Dianna Vincent Nathan Lowell TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si Page 1 of 1 Regg, James B (DOA) ~ ~`~~ -UZ`~ From: NSK Problem Well Supv (n1617@conocophillips.com] Sent: Thursday, November 12, 2009 10:15 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; CPF3 DS Lead Techs; CPF3 Prod Engrs; Edwards, Reid T Subject: 3H-26 (PTD# 194-029) Report Of TxIA Communication Attachments: 3H-26 Wellbore Schematic.pdf; 3H-26 TIO Plot.pdf Jim/Tom/Guy, ~/ Kuparuk gaslifted producer 3H-26 (PTD# 194-029) is suspected of having TxIA communication based upon a failed shut in TIFL on 11/09/09. A leaking gaslift valve is suspected so slickline wil repair i possible. CPAI will add -2 tot e SCP Report and the we wi be fixe or shut-in by 12/07/09. Attached area 90 day TIO plot and wellbore schematic. ~' Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 t. ~.Q ~ 11/27/2009 Name 3H-26 Notes: Date 12/1 /2009 120 :Date 8/3/2009 2000 1800 1600 1400 1200 .Q 1000 800 600 400 200 0 Annular Communication Surveillance IAP OAP WHT Aug-09 300 zso o zo a J m 150 0 U ~ 1000 500 0 Sep-09 Oct-09 Nov-09 160 140 120 100 LL 80 ~ 60 40 20 0 ~DGI ~MGI ~PWI ~SWI ~BIPD Aug-09 Sep-09 Oct-09 Date Nov-09 - p ~~~ _ KUP 3H-26 ~~}~OCC7t-f t~1~4p5 ~ I - Well Attributes __ _ --- - Max_An_ gle & MD ;Tp __ _ Wollb oro APIIUWI Field Name I Well Status Inc! (`) MD (fIKE~ Act Btm (fdCB) 501032020800 KUPARUK RIVER UNIT PRODUCING 39.20 5,149.90 6,660.0 Comment H25 (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Dal SSSV: NIPPLE 175 1/14/2008 Last WO: 4/29/2005 40.99 3/6/1994 6PM ~.. Annotation Depth (ftK6) End Date A nnotation Las _ _ _ Last Tag: 6,326.0 __-_ 11/19/2006 Rev Reason: GLV C/O _. _ _ ( Casing Strings _ -- String OD St Ing ID Set Depth Set Depth (TVD) String ~ Casing DeacriPtion tin) tin) ToP (ftK8) (ftK8) (ftK8) (Ibal r ~ ( CONDUCTOR 16 15.062 41.0 121.0 121.0 6'. SURFACE 75/8 6.875 0.0 3,143.0 3,140.6 2' l ~ PRODUCTION 5.5x5 51/2 5.000 0.0 6,640.0 6,287.9 1' HANGER, 36 ~3 Tubing Strin s - -- - - - String 00 St I g ID ~ SeI D pth Sot Depth (ND) String 1 Tubing D scr'ption (inl (I } Top (ftKa) (ftK8) (ttKDJ (Ibsl € TUBING 3 1/2 2 992 38 0 6 126.0 ~. 5 785.4 e ~- ~ e _.____~. _ _... __ _ .- _ _.. _. _ '~ - ~ t ~ Other In Hole All Jewel : Tubin ~-- _- rgl Top Depth ~ ~ t Run & Retrievable , Fish, eta~_ . __ _. (TVD) Tap Inc! ll CONDUCTOR, Toe fftKBl (ftK8) (•) ion I Comment 921 NIPPLE, 504 GAS LIFT, ~ ,„ A 2,785 f ('~ 6A 6'k-~ _ . f SURFACE, J 3,143 GAS LIFT, 4,124 GAS Grade String Top Thrd ' IBT A Perforations & Siots snot Top (ND) Btm (ND) Dens Top ftK8) Btm (ftK8) (ftK8) (ftK8) Zone Date lah... Type Comment 6,250 6,280 5,905.1 5,934.5 C-4, C-3, 3H-26 4/9/1997 4.0 IPERF 1 11/16" PIVOTS, 180 deg. ph ~j I 6,2501 6,2801 5,905.11 5,934.51 C-4, Cam, 3H-26 16/15/1998 4.0RPERF (-~ 6,306 6,336 5,960.0 5,989.5 A-3, A-2, 3H-26 6/24!1994 4.0 IPERF 1 -__..__.._ _.._.. --... ....... `" 'Notes: Ge_neral_& Safet ___ __ _ ' End Date Y ~ Annotation 4/29/2005 NOTE: TREE: FMC 3-1/6"" / GEN IV / 5000 psi rated 4/29/2005 NOTE: WORKOVER BY CTD -.~ I ~ ~; I "! '.1 NIPPLE, fi,10fi 1; °~ I LOCATOR, 6,112 SEAL. 6.113 IPERF, 6,250.8,280 RPERF, 6,250-6,280 IPERF, , 6,306-8,336 ~ COn ~ . ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ::i.~ ~ ~+*~~ire ~~~ . ` ~1'~!'~ ~ (~ - a o~-~' t~ ,^ ~ ~W 3~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~` 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, v~G~' ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 on eu ov o on n_~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ., ~ Corrosion inhibitor Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" Na 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" Na 21" Na 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . Na 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30@009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n!a 1.7 8/9J2009 3Q-12 50029216770000 1861890 7" n/a 7" Na 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' S.25 30" 7/30/2009 8.5 8/8/2009 From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, April 29, 2009 9:37 AM To: Regg, James B(DOA); Maunder, Thomas E(DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs; Edwards, Reid T Subject: 3H-26 (PTD# 194-029) Report Of TxIA Communication Attachments: 3H-26 Wellbore Schematic.pdf; 3H-26 TIO Plot.ppt Jim/Tom, Kuparuk gaslifted producer 3H-26 (PTD# 194-029) is suspected of having TxIA communication based upon a recent failed TIFL after a report of elevated IA pressure while the well was shut in. A leaking gaslift valve is suspected so slickline will troubieshoot and repair if possibie. The well will be added to t e producer SCP report and will be repaired or shut in and secured by 5/26/09. Attached is a 90 day TIO plot and a wellbore schematic. «3H-26 Wellbore Schematic.pdf» «3H-26 TIO Plot.ppt» °'" Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Probiem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 a'"-yl~t., z ~~'~~i ~~~ n ~ , ;.r , , ~ ~ t~`' .~ -" ~U r, ~, ~,:~ 8/6/2009 ~f z~l~ ~ i`t4-~zti IAP 250C Zooo OAP TII/O Plot - 3H-26 .......................................... ............................... ............ .................................. ..~.......~............ .... 1500 N a 1000 .... ..... .. ..... ... ... ......................... Well Shut In .. ... ...... 200 150 a E a~ 1 ~0 ~ Y O L c~ 50 500 0 ~~ 29-Jan-09 11-Feb-09 24-Feb-09 09-Mar-09 22-Mar-~9 04-Apr-09 17-Apr-09 Date 0 _ KUP ~ 3H-26 ~~/~y*y ~~~{.~"t ~ ~ ~~~ II~~ ~: ~ r~. _ N IIV = i Y . <~~~i ~ , a.ci r~. ~ .~ ~L~~~, `~ ~' ~''..~ k ~,~ ~~.s~ s .'~N ~ .l ila~ ' ;;. V# i~iLV~ 7 ~{ ~i Wellbore API/UWI Field Nama Well Statua Maximum Inclination ~°) Tohl Dapth (ftHB) ~~~• d~~ 501032020800 KUPARUK RIVER UNIT PROD 3920 6,660.0 ~ CommaM H2S (ppm) Date Mnohtion End Date KB-Grd (ft) Rig Release Date '~~ ,_ _.. .„ ..... SSSV: Nipple 0 7/12008 Last WO: 4/29/2005 40.99 3/6/1994 - ..:~ Annohtion Depth (ttKB) End Data AnnWation End Orie LastTag: 6,326. 0 11/1 9/2006 Rev Reason: GLV C/0 8/192008 8$ITi ~:$~ ~ -= r -~i ~' ~ P ~~fi ; ~~'~ - = F~°' -- 6et Depth SM DepM (NU) Wt ~ ~ ~ ~ CasinB Deacription OD (in) ID (in) Top (ttKB) (ftKB) (ftKB) (IbsIR) Orede Top Threatl CONDUCTOR 16 15.062 0.0 121.0 121.0 62.50 H-40 y~ SURFACE 75I8 6.875 0.0 3,143.0 3,140.6 29:70 L-80 HANOER 38 '~-~=~~ PRODUCTION 5.5x5 5 1/2 4.151 0.0 6,640.0 6,287.9 17.00 L-80 , - y~ ~~## ~ ~~~`i ~ ~ ry ~ _ ~) ~' ~ ii ta. ~" ~ ~ i ~ 4 .z t ' " ~ .. .. !: ~ , . '47n... SM Depth ~~~~~ 7ubin Description OD in ID in 70 (ttKB) (ftKB) Sat Dapth ND (ttKB Wt (Iba/ft) Omde Top Threatl TUBING 3112 2.992 0.0 6,726.0 5,783.3 9.30 L-80 IBT CONDUCTOR, '~ s' ` y ~y ~~~~ ~[~'~~n y~ ~1~ ~ i 1~ ~~~ ~y, -~ " - ~L- ~ ~ "~~=a ~ =': -{ .,t ~ m~~#S~l ~~~~~ " 121 Top (ttNB) Description ~ ,r , . ComTent Run Data ID ~in~ S - 38.O HANGER FMCTUBINGHANGER 429I2005 2.992 504.0 NIPPLE CAMCO BP-61 LANDING NIPPLE 4/29/2005 2.875 NIPPLE 504 2,765.0 GAS IIFT CAMCOMBG-2-9/1/GLV/DK-1/.156/1263/ Comment: STA 1 8/182008 2.900 , 4,124,O GASLIFT CAMCO/KBG-2-9/1IGLV/DK-1/.188/1305/Comment: STA2 8/16R008 2.900 " 4,987.0 GAS LIFT CAMCO/KBG-2-9/7IOV/DK-1/.25// Comment: STA 3 8/17/2008 2.900 5,631.0 GAS LIFT CAMCOIKBG2-9/1/DMY/DK-1/d Comment: STA 4 6/302005 2.900 6,055.0 GAS LIFT CAMCO/KBG2-9/1IDMYIDK-1/// Comment: STA 5 6/30I2005 2.900 GASLIFf, 8 106 0 NIPPLE CAMCO'DS'NIPPLE 4/29/2005 2.812 2.765 , . 6,712.0 LOCATOR BAKER GBH-22 LOCATOR NIPPLE 429l2005 2.850 6,113.0 SEAL BAKER BOT GBH-22 SEAL ASSEMBLY, 2.85" DRIFT 4/29/2005 2.980 a ~ ~ _ ~'i a ~ Ir~,w..' -~ '°. ~ ~i'~ T iN ~ i ~, ~I~~ I SURFACE. 3,143 .ci _ , = ' ~ ,, i _ u , wq Shot Top (7VD) Btm (ND) Dens ~` Top (RKB) Btm (ttKB) (nKe) (EKB) Type Zone Nha~- Date Comment 6,250.0 6,280.0 5,905.1 5,934.5 IPERF C-4, C-3, 3H-26 4.0 4/9/1997 1 11/16" PIVOTS, 180 deg. ph 6 ZSO O 6280 0 905.1 5 934.5 5 RPERF C-0 G3 3H-26 4.0 6/15/1998 21l8" EnerJet, 0 deg ph GAS LIFT, , . . , , , , a,~za 6,306.0 6,336.0 5,960.0 5,989.5 IPERF A-3, A-2, 3H-26 4.0 6/24/1994 21/8" EnerJet, 90 deg. ph ,w ~~B$;~ ~~ ~ '~~& ~ " ~a ~ ' -- i "`~`;` ~ t'~~~ ~' = ~ =~ .~~ =~..r:~ - - End Da ta Ann otation 4/292005 NOTE: WORKOVER BV CTD GAS IIFT, 4,987 li OA6 LIFT, 5.631 GAS LIFT, 6.055 r,,~ NIPPLE,fi,106 . LOCATOR, ° 6.112 ~~ ~ I SEAL, 6,113 ~ / IPERF. _:.:.. :: ........... 6,25P6,280 RPERF, 6.25Q8.280 IPERF, 6,3W-6,336 PRODUCTION 5.Sx5, 6.640 ~ " TD.6.660 i I STATE OF ALASKA - ALASKA)L AND GAS CONSERVATION ce. )v1ISSION REPORT OF SUNDRY WELL OPERATIONS RECE 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 025531 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structu ral Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): -- ~th2~-{;---TmT5------ IS! Repair Well 0 Plug Perforations o Pull Tubing 0 Perforate New Pool o Operation Shutdown 0 Perforate 80' 6660 6308 6653 6301 121' 3142' 6640' o Stimulate o Waiver . ! .0. T.irne Extension Ai3SIŒ OU1S1 ~li1S l;tm::L L~mml:¡;;,:dm] o Re-Enter Suspended Well f¡ ~ l"'inCtiil!Jf8fJe 5. Permit To Drill Number: 4. Current Well Class: IS! Development 0 Exploratory o Stratigraphic 0 Service 194-029 6. API Number: 50-1 03-20208-00-00 99519-6612 9. Well Name and Number: Kuparuk 3H-26 10. Field / Pool(s): Kuparuk River Unit / Kuparuk River Pool feet feet Plugs (measured) None feet Junk (measured) None feet Size MD TVD Bu rst Collapse 16" 121' 121' 7-5/8" 3142' 3140' 6890 4790 5" 6640' 6288' 10140 10490 SCANNED MAY 2 "{ 2005 6250' - 6336' 5910' - 5992' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Printed Name Terrie Hubble Signature -(Q}\l'u' fl ~ ~ Form 10-404 Revised 04/2004 3-1/2",9.3# L-80 6127' Tubing Size (size, grade, and measured depth): 504' Packers and SSSV (type and measured depth): Cameo BP-61 Landing Nipple Treatment description including volumes used and final pressure: RBDMS BFL MAY 2 7 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casinq Pressure 237 1,061 191 568 2,251 1,309 15. Well Class after proposed work: o Exploratory IS! Development 0 Service 16. Well Status after proposed work: IS! Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 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: Contact Howard Gober, 263-4220 NIA 13. Tubinq Pressure 136 161 Oil-Bbl Prior to well operation: 244 Subsequent to operation: 285 14. Attachments: 0 Copies of Logs and Surveys run IS! Daily Report of Well Operations IS! Well Schematic Diagram Title Technical Assistant Phone Date 05/4(0.<; Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only 564-4628 ORIGII~AL ) ) BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Code N PT Phase 4/21/2005 7.00 MOB P 10.50 MOB P 00:00 - 07:00 07:00 - 17:30 PRE PRE 17:30 - 18:00 0.50 MOB P PRE 18:00 - 18:45 0.75 MOB P PRE 18:45 - 22:15 3.50 MOB P PRE 22:15 - 22:35 0.33 MOB P PRE 22:35 - 00:00 1.42 MOB P PRE 4/22/2005 00:00 - 00:45 0.75 BOPSUPP PRE 00:45 - 01 :15 0.50 BOPSUR P PRE 01 :15 - 03:50 2.58 BOPSUR P PRE 03:50 - 05:00 1.17 BOPSUPP PRE 05:00 - 06:30 1.50 BOPSURP PRE 06:30 - 10:30 4.00 BOPSUR P PRE 10:30 - 17:20 6.83 BOPSUP P PRE 17:20 - 18:00 0.67 BOPSUP P PRE 18:00 - 18:45 0.75 BOPSUF P PRE 18:45 - 19:15 0.50 BOPSUP P PRE 19:15-21:00 1.75 BOPSUPP PRE 21 :00 - 22:30 1.50 BOPSUR P PRE 22:30 - 23:30 1.00 BOPSUP P PRE 23:30 - 00:00 0.50 BOPSUR P PRE 4/23/2005 00:00 - 00:30 0.50 BOPSUR P PRE 00:30 - 01 :00 0.50 BOPSUP P PRE 01 :00 - 04:00 3.00 BOPSUP P PRE 04:00 - 04:15 04: 15 - 05:00 0.25 BOPSUR P 0.75 BOPSURP PRE PRE Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 Continue rig down and prepare to move off of well 1 B-13. Move rig off 1B-13. Inspect pad with Operator. All in good, clean condition. Mobilize Tech Limit and Office trailers to 3H-26. 0830 hrs Start rig move from 1B pad to 3H-26 1300hrs passing CPF-3 1730hrs on location. Spot rig at entrance to pad and place drip liners. Crew change and pre tour safety meeting. Hold pre rig inspection of pad with 3H pad operator. Scrape pad with loader to finish pad prep. Spot rig mats. Place herculite around tree. Safety meeting with rig crew, pad operator, Toolpusher, Teamleader, and Company Rep prior to moving over the well. Move rig over well 3H-26. Set rig down. Accept rig at midnight. Continue with rig up. Pull BPV 1250 psi on tubing. Bleed pressure off to slop trailor. Well finally at 0 psi. Dry rod in BPV. Test from below to 500 psi by pumping down the IA. Held fine. Pre spud meeting with Howard Gober for night tour rig crews and day crews in the tech limits shack. RD circulation lines. Paint reference line vertically on tree. ND production tree. Found threads in hanger corroded and unusable. Continue NU BOPE and riser. Fill BOP stack and riser check for leaks. Found one in riser and fixed. RU circulation lines to IA. Attach pressure sensor to IA. NU bop. Body test BOP stack against IBP downhole. Held to 500 psi ok. Bleed off pressure. Make up shooting nipple in annular bag. Make up crossover and 7" lubricator to rig floor. Rig up Kuparuk valve crew lubricator and pulling tool. Attempt to pull BPV. No luck on first try. Repeat attempt. No luck on second try, and grapple from pulling tool broke off. Chugger out stack. Try to fish broken grapple OOH with dry rod and a hook made out of slickline wire. Recovered fish from top of BPV. FMC hand recommends a different configuration for further attempts to pull BPV. Send FMC hand for new equipment. Wait on equipment. Pull BPV with reconfigured eq. Recovered it ok. Lay down Valve shop and FMC equipment. Rig up to circulate out well. Pump down the backside with both pumps to circulate well clean. Pumping at 5.2 bpm, 1800 psi. Got lots of crude and parafin cut fluid back for first 140 bbls. Ended up junking about 100 bbls. Returns cleaned up, and we circulated an additional 700 bbls. Safety meeting with slickline crew prior to rigging up. Rig up shooting nipple and slickline unit to make drift run prior to setting weatherford retrieveable plug. Printed: 5/2/2005 7:55:16 AM ) ) Legal Well Name: Com mon Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 COde N PT phase 4/23/2005 05:00 - 06:00 1.00 BOPSUP P PRE Run down with slickline drift. Hang up at the tubing hanger. Reconfigure BHA, and drift again. Ok this time. 06:00 - 06: 15 0.25 BOPSUP P PRE PJSM with day crews. Review tool arming procedures and radio silence. 06: 15 - 09:30 3.25 BOPSURP PRE MU Weatherford WRP plug to Howco slickline. RIH to 50'RKB. Wait 30min. Firinghead failed. TOH. Download info. Problem in electrical system between capacitor and firinghead. Replace all tools between WRP and firing timer. RIH set WRP 50' below RKB. RD slickliners 09:30 - 12:00 2.50 BOPS UP P PRE Pull rig lubricator to floor. Pressure test inside/outside/HCR stack valves and choke manifold valves, blind rams and WRP. 250 low 3500 high 5min each. 12:00 - 13:30 1.50 BOPSURP PRE UD rigs lubricator. PU Baker Dual Grapple Spear and 1 jt 3-1/2" DP. RIH. Upper grapple too tight for tbg. Lower catch 9.2-10#, upper catch 9.2-9.8# remove upper catch. RIH to 37'RKB engage grapple with 20k. 13:30 - 16:00 2.50 BOPSURP PRE Resume testing BOP's 250/3500 5 min each. Draw down test accumulator. 16:00 - 16:30 0.50 BOPSUR P PRE, UD Baker spear 16:30 - 18:00 1.50 BOPSUP P PRE PU rig lubricator. RU slickliners. Pull WRP w/o problems. RD slickliners 18:00 - 18:30 0.50 BOPSUP P PRE Continue to rig down slickliners. 18:30 - 18:50 0.33 PULL P DECOMP Safety meeting with rig hands, TP, TL, Co Rep, FMC, HES spooler hand. Discuss pulling tubing with spear. 18:50 - 19:50 1.00 PULL P DECOMP Rig up to set spear below tubing hanger. 19:50 - 20:15 0.42 PULL P DECOMP Land spear pu 20 klbs to set spear. Backout lockdown screws. No pressure on backside. block hanging wt = 8 klbs. PU to 60 klbs, then broke back to 48 klbs. Good indication free of seal assebly. PU hanger to rig floor. 20:15 - 21 :25 1.17 PULL P DECOMP Lay down spear. Break off tubing hanger. Rig up to circulate out well. Note - Brought in Haliburton control line spooling unit today using usual method of lifting it on the pipe elevator and dragging it thru the pipe shed. The spooling unit was damaged during this process with the lifting bar being ripped off. No injury to personnel. 21 :25 - 22:30 1.08 PULL P DECOMP Circulate out well. Circ down the tubing and up the backside. Pumping at 5 bpm, 1500 psi. Pump 150 bbls (Round trip volume is 122 bbls). Circulation was clean with no oil and just a small burp of gas in the returns. 22:30 - 00:00 1.50 PULL P DECOMP Pull and laydown old 3-1/2" x 2-7/8" completion. Recovered 8 control line clamps on first 15 joints. On joint 15 the control line hung up and could not be retrieved with the spooling unit. 15' of tubing pulled without moving control line. Hooked up tugger to control line. Could not pull it free. Pull up on pipe and control line would move when pulled with tugger. Pull 1 for 1. Begin pulling control line in 30' pieces using a tugger as we tripped 30' jts OOH. No control line clamps recovered below jt 15. 4/24/2005 00:00 - 02:00 2.00 PULL P DECOMP Continued pulling tubing and control line OOH using the tugger. Getting consistent 1 for 1 when pulling. On joint #22 recovered another intact clamp on the joint with 2 additional Printed: 5/2/2005 7:55: 16 AM ') ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Date From.. To Hours Task Code 4/24/2005 00:00 - 02:00 2.00 PULL P 02:00 - 02:45 0.75 PULL N 02:45 - 03: 15 0.50 PULL N 03:15 - 04:10 04: 10 - 05:00 0.92 PULL N 0.83 PULL N 05:00 - 10:00 5.00 PULL N Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 Description of Operéltiqns DECOMP ones hanging on for the ride. No clamps down to joint 29 where we recovered a large knot of control line, and 1 clamp hanging free. The control line was parted below joint #29. Total amount of control line recovered to this point is 912'. Total number of control line clamps recovered to this point is 12. There is 923' of control line left in hole, and 22 control line clamps. Continued pulling pipe with no control line being recovered. Pulled to jt 36, then started pulling heavy and ratty (60 klbs). Normal up wt 40 klbs Every time we pull heavy, we slack back off 10', then pull clean. Pulled in this way until jt 38. 20' of jt 38 OOH, and pulled heavy, then couldn't slack back off. STUC DECOMP Can't go down. Try pulling to 80 klbs, and slacking off, can't go down. PU to 100 klbs, slack off, and can't go back down. PU to 120 klbs, and can't go back down. Work pipe up to 80 klbs, and slack off as fast as possible. Repeat 30 times. Can't go up or down. Maximum wt pulled to this point is 120 klbs. STUC DECOMP Make free point calculation using Baker Fishing Spreadsheet. PU to 20 klbs on string. Pull to 60 klbs, got 6" of stretch. Pull to 100 klbs, got 6" of stretch. Spreadsheet shows stuck point to be 1 026'. Total amount of pipe recovered is 37 joints, or 1158'. Current depth of Camco hydraulic landing nipple is 652', Most likely place of stuck point is hydraulic landing nipple. Call Baker fishing to discuss situation. They recommend rotating the string. Call town to discuss options. STUC DECOMP Wait on orders. STUC DECOMP Rotate pipe up to 2000 ft Ibs of torque. Work pipe up and down. No luck. Remove torque, and pull to max safe pull of 135 klbs. No movement. Slack off, still stuck. Cycle from 0 to 135 klbs 10 times. No success. Pull up to 120 klbs and slack off fast numerous times. No success. STUC DECOMP Call town again and discuss options. Coordinate with BP Wells Group and obtain 1 of their SLB e-line trucks. Gather tools for Free-Point, Chemical and Jet cut 3-1/2" 9.3# and 2-7/8" 6.5# tbg, and temp log. Call Baker Fishing and order 2-7/8" PAC workstring, 3-1/2" DC's and misc. fishing tools. RU XO and TIW valve to tbg. Circulate .5bpm with charge pump. Returns 78 deg. Occasionally work pipe to 60k then to neutral wt. RD circulation line. RU Schlumberger E-line unit. PJSM re freepointing with Schlumberger eline. RIH with Free point tool. Find free point at Camco Safety vavle nipple. Took a station 4' above it and was 100% free. Took a station 4' below it and was 80% stuck. Took additional stations to confirm. POOH. Stand back Schlumberger eline, and lay down free point tool. PJSm with Schlumberger prior to shooting string shot. Test SWS firing head. RIH with SWS string shot. Fire string shot over cut depth, 584'-596'. POOH. Stand back Schlumberger eline. Rig up to circulate. On line with rig pumps to warm hole prior to chemical shot. Pumping at 2.0 bpm, 350 psi down the tubing, and up the 10:00 - 16:00 6.00 PULL N STUC DECOMP 16:00 - 17:00 1.00 FISH N STUC DECOMP 17:00 - 17:15 0.25 RIGD N STUC DECOMP 17:15 - 20:30 3.25 FISH N STUC DECOMP 20:30 - 21 :00 0.50 FISH N STUC DECOMP 21:00 - 21:15 0.25 FISH N STUC DECOMP 21 :15 - 22:30 1.25 FISH N STUC DECOMP 22:30 - 22:45 0.25 FISH N STUC DECOMP 22:45 - 23:15 0.50 FISH N STUC DECOMP Printed: 5/2/2005 7:55: 16 AM backside. Hold PJSM with rig crew and Schlumberger eline to discuss chemical cutter rig up and safety. Final circ temperature was 77 degf out, 69 degf in. SI pumps. Rig down circulating head. Dress derrick hand in protective suit. Pick up SWS chemical cutter, and stab in tubing stub 20' over rig floor. Latch elevators on pipe and pick up to 12500 Ibs, neutral weight to cut depth, plus weight of blocks. RIH with chemical cutter. STUC DECOMP Chemical cut tubing at 596'. This is 2' below top of 10' pup just above Camco SSSV nipple. There should be 8' of stickup above nipple. Good indication of cut. PU with blocks, confirming that pipe is free. POOH with chemical cutter. STUC DECOMP Lay down chemical cutter BHA. All recovered ok. DECOMP Pull 20 joints of 3-1/2 BTC tubing and lay down. No control line bands or control line recovered with pipe. 900'+ of control line and 22 bands left in the hole. Pin ends of recovered pipe below joint 42 showed significant internal corrosion, and are probably no reusable. Lay down recovered tubing. Load pipe shed with drill collars and enough drillpipe to reach top of fish. Pickup fishing tools onto rig floor. Measure lengths of all crossovers, etc. PJSM re: making up fishing BHA #1. Make up fishing BHA #1, Rope spear to recover control line. Didn't have to go far 27' in and found control line. Worked rope spear up/down and around until to tight with a 36" wrench. Pulled and recovered pieces of line and 2 bands. Repeat this operation working further in hole and recovering control line and bands. Made it to top of fish 605' and torqued up tight. Work twice. Have rec'vd about 900' of control line and 20-1/2 bands TOH. No control line recovered. Bottom 8" of rope spear showed clear indications of entering tbg stub with rotational marks on under side of prongs. LID rope spear and PU Baker Spear w/ dual grapple. RIH PJSM with the night tour about the plan forward. Can't get into the top of the tubing stub. May have additional junk on top of it. Plan to circulate to fluff the junk up so the spear will engage. Rig up to circulate, and circulate with neat 10.5 ppg brine to try to fluff the debris up and engage fish. Also mixing 94 bbls of 2 ppb of biozan to assist in carring debris. Latch into fish by circulating. Begin jarring down. Repair weight cell. Resume down jarring. Continue to jar down on fish. Begin Up jarring. Jarred for 1 hour the the jars stopped working. We have moved the fish up hole 6" during this time period. Call for a new set of jars from Baker fishing. Resume jarring down while we wait for new tools to arrive. We lost the 6" we gained after jarring down a few licks. Got fish free. Shoved it down to the connection on last joint, about 12'. Able to move freely up and down, but when we pull Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Date From ~To Hours Task Code NPT Phase 4/24/2005 22:45 - 23: 15 0.50 FISH N STUC DECOMP 23:15 - 00:00 0.75 FISH N STUC DECOMP 4/25/2005 00:00 - 00:40 0.67 FISH N 00:40 - 01 :00 01 :00 - 02:45 0.33 FISH N 1.75 PULL P 02:45 - 04:30 1.75 FISH N STUCDECOMP 04:30 - 04:45 0.25 FISH N STUC DECOMP 04:45 - 06:00 1.25 FISH N STUC DECOMP 06:00 - 13:00 7.00 FISH N STUC DECOMP 13:00 - 14:30 1.50 FISH N STUC DECOMP 14:30 - 16:00 1.50 FISH N STUC DECOMP 16:00 -18:15 2.25 FISH N STUC DECOMP 18:15 -18:30 0.25 FISH N STUC DECOMP 18:30 - 19:10 0.67 FISH N STUC DECOMP 19:10 - 20:45 1.58 FISH N STUC DECOMP 20:45 - 22:00 1.25 FISH N RREP DECOMP 22:00 - 00:00 2.00 FISH N STUC DECOMP 4/26/2005 00:00 - 01 :00 1.00 FISH N STUC DECOMP 01 :00 - 02:00 1.00 FISH N STUC DECOMP 02:00 - 02:50 0.83 FISH N STUC DECOMP 02:50 - 03:30 0.67 FISH N STUC DECOMP Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 Descri ptipnofOperatioÒs Printed: 5/2/2005 7:55: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 From-To HÖurs Task Code' NPT Phase 4/26/2005 02:50 - 03:30 0.67 FISH N STUC DECOMP up to the original stuck point we start taking weight again. Work pipe up and down trying to flatten out debris. Pumping at 4 bpm, 3500 psi. Turn pipe 3/4 turn. Try to work past obstruction. Still hanging up at same depth. Continue to work pipe and circulate. 03:30 - 04:40 1.17 FISH N STUC DECOMP Making headway. Pulling slowly to surface. Still have junk around pipe. Pulling draggy and slow, having to pump our selves OOH, and work pipe up and down to make any headway. Make up circulation head to each joint as we go. Going to be a slow process. 04:40 - 09:00 4.33 FISH N STUC DECOMP Getting gas back. Stop pulling and circulate. Circulate at 2bpm through gas buster. 09:00 -11:15 2.25 FISH N DECOMP Stop pump. SI annular. Pressure up 500psi on annulus to test OA. No communication seen. Stop pumping altogether and monitor well. (thinking we might be inducing air to system) Gas rate did not decrease. SI well again to check SIP. Annuluar not holding. PU string 15' to better see down hole. Working several times and wash debris off element. Pipe movement caused an increase in gas to surface. 11 :15 - 12:15 1.00 FISH N DECOMP Circulate at 1 bpm through gas buster. Reduce annular closing pressure to 400psi and moving pipe 15' every 5 min. This may help in bringing gas to surface that's trapping below fish at 560'. 12:15 - 13:00 0.75 FISH N STUC DECOMP Discuss plan forward with rig team. Call town, discuss plan forward. Current fluid in hole is 10.5 ppg brine. BHP below IBP based on last pressure survey is 10.68 ppg. Call for dry product to weight mud up to maximum of 11.0 ppg. Shooting for 10.8+. While waiting for product to weight up mud, we plan to move fish closer to surface. We will not pull the fish thru the stack until the well is dead. 13:00 - 13:45 0.75 FISH N STUC DECOMP Continue to work pipe to surface. Pulling ratty, and draging. Pumping as we pull. 13:45 - 15:00 1.25 FISH N STUC DECOMP Hung up after pulling 20'. Working pipe. Gas in returns has cleaned up considerably. Pump pressure at 1 bpm was 384 psi. Pressure at 2 bpm was 1980 psi. Pressure at 3 bpm is 2430 psi. Continue to circulate and work pipe OOH. 15:00 - 17:00 2.00 FISH N STUC DECOMP Worked pipe past bad spot. Continue pumping and pulling. Plan to stop and circulate in heavier fluid with 2 drill collars left in hole. 17:00 - 00:00 7.00 FISH N STUC DECOMP On drill collar 6, 6 more to go. Pulling good. SD to circulate wellbore at 3.00 bpm while waiting on 12.0 ppg NaBr to be mixed up in Deadhorse. Spear/Top of fish at 208 ft Bottom of fish at 4,496 ft. Empty GLM Pocket at 3,267 ft and 4,446 ft MI still mixing at midnight, the wt is 12.25ppg before adding lube. 4/27/2005 00:00 - 04:30 4.50 FISH N DPRB DECOMP Circulate and wait on 12.0 ppg NaBr brine from MI Deadhorse. Fluid is clean circulating at 2.5 bpm MI mixed up 150 bbl of 12.4 ppg NaBr. Will cut to 12.2ppg with 8 drums of EMI-920 (Lube). 04:30 - 07:00 2.50 FISH N DPRB DECOMP Unload 150 bbl's kill wt fluid into to pits. RU to mix in 3 drums Printed: 5/2/2005 7:55:16 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 DPRB DECOMP of EMI-920 lube. Mixing in Lube DPRB DECOMP Circulate 12.2 ppg fluid down hole. Got heavy returns back almost immediately. Return weight of 11.3 ppg indicates about 50% fluid bypass at the fishing spear. Continue circulating down the tubing, and taking returns. Plan to circulate until in and out density stabalize, DPRB DECOMP 310 bbls since start of pumping. In and out density are pretty stable at 11.6 ppg. Mud man indicates that the volume of 10.5 brine needed to contaminate the 12.2 down to 11.6 indicates the entire wellbore down to the top of the IBP is swaped to brine. Discuss with rig hands. SI and check for flow. No gas observed. A slight trickle coming out the well from utubing. Begin pulling and laying down drill collars. Circulating each collar out of the hole. Pulling clean, with no drag observed. PU weight = 25 klbs. Less than yesterday due to bouyancy. 2 drill collars to go. Circulate for 100 bbls, and hold PJSM with rig crew prior to pulling fish and debris to surface. Circulate 2 drill collarsOOH. Recovedish to surface. Both bumper subs wrapped with control line. 2 bands on upper bumper sub. Fish wrapped with control line. Bits of control line debris were falling off as we pulled the fish to surface. Photos emailed to the Anchorage engineers. DECOMP POOH with old completion. Recovered all completion DPRB DECOMP Load out BOT fishing tools and completion equipment. DPRB DECOMP Chugger out BOP stack. install Test Plug and 2 RILDS. Pull BOP doors and clean out control line. Started to load pipe shed with completion tubing Recovered 1 band, 1 large piece of control line and several small pieces. DECOMP PT body against hydril to 400/3500 psi. Repair door leak. Backed out LDS and pulled test plug to surface. PU and inserted 7-1/16" 5k lubricator with shooting nipple in Hydril and closed. PJSM with Nordic, Halliburton and DS on RU and counducting WL work. RU Halco RIH with WL tool string with 4.5" WL grab. Light tag at 3,920 ft, pushing something ahead of us. Stopped at 4,110 f. POOH to look. Pulled tight in some spots. POOH to look at wire grab. Recovered 1 band and 12" piece of control line Run @2 working on junk at 4400 ft, getting a hold of something and when we PU 50 ft lose the junk. Working wire grab in the hole. DECOMP Tag up with wire grab run #2. Recovered 1, 12" piece of control line. DECOMP Wire grab run #3. Tagged up at 6095', pickup was clean. Tagged up at surface, and the wire grabbed with pinched down as if it had tried to enter the seal assebly. No control line recovered. DECOMP RIH with 4.75" junk basket gauge ring. Tagged up at 6095' SLM. Top of seal assembly is 6116' drillers depth. Work junk Date From- To HöUrs Task 4/27/2005 04:30 - 07:00 2.50 FISH N 07:00 - 09:00 2.00 FISH N 09:00 - 09:10 0.17 FISH N 09:10 - 10:10 1.00 FISH N DPRB DECOMP 10:10 - 10:55 0.75 FISH N DPRB DECOMP 1 0:55 ~ 12:00 1.08 FISH N DPRB DECaMP 12:00 - 21 :45 21:45 - 22:15 22:15 - 00:00 9.75 FISH P 0.50 CLEAN N 1.75 BOPSUR N 4/28/2005 00:00 - 02:30 2.50 BOPSUP P 02:30 - 02:45 0.25 CLEAN P DECOMP 02:45 - 03:50 1.08 CLEAN P DECOMP 03:50 - 04:20 0.50 CLEAN P DECOMP 04:20 - 06:00 1.67 CLEAN P DECOMP 06:00 - 06:15 0.25 CLEAN P 06:15 - 07:45 1.50 CLEAN P 07:45 - 09:00 1 .25 CLEAN P De§criptiÖnofQpC3 ratiOns Printed: 5/2/2005 7:55: 16 AM ) ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud· Date: 4/20/2005 End: 4/30/2005 Date From-To HöUrs Task Code 4/28/2005 07:45 - 09:00 1.25 CLEAN P DECOMP basket on bottom 5 times. Picked up clean each time. Looked like hard tag, probably top of seal assebly. POOH. Tag up at surface. Dump junk basket. Mostly clean except for 1, 5" piece of control line. DECOMP RIH with 3.795" junk basket gauge ring to drift seal assebly. RIH, got thru 16' seal assembly from 6095'-6111' SLM up and down 5 times. Saw good weight bobbles at the top and bottom as they went thru. Slick line operator confident that this was seal assembly. Ran in to 6150' SLM. Did not tag top of fill/junk. POOH. Dumped junk basket. No debris recovered. DECOMP Rig down slick line unit. RUNCMP New completion equipment mostly in pipe shed. Bring in last row, drift and strap. RUNCMP Slip and cut 50' of drill line. RUNCMP PJSM prior to running new completion. RUNCMP Run new 3-1/2" completion as per proceedure. On joint 68 at 05:45 hrs Spill drill at 19:00 hrs. Spill contained and cleaned up in 15 min, Ran 173 jts 3-1/2", well started to flow. DPRB RUNCMP Stabbed valve and closed annular. RU to circulate DPRB RUNCMP Circulate well through drilling choke at 5,507 ft. Qp = 2.65 /2.75 bpm Den = 11.6/11.6ppg. Circulated 50 bbl and the density in annulus dropped to 10.5ppg and then went to gas cut fluid. Cir 110 bbl, density = 11.5/11.5ppg, The 12.2ppg KWF fluid pumped with viscosity didn't flip in the well bore. SD and gas alarms went off, well has small flow, Cir another well bore volume of 120 bbl. Cir another well bore at 2.5 bpm Vp = 300 bbl, SD, monitor well, static with 11.5ppg Remove floor valve and make ready to run liner Running liner. ran 10 jts to 5,583 ft well started to flow up the tubing. Stabbed floor valve closed annular and RU to circulate. Circulate out 10.5 ppg fluid and trace of gas Circulated 150 bbl, SD and checked flow. Well still unbalanced. Circulate 80 bbl. Well balanced RIH to 6094 ft with a total of 191 jts. Circulate wellbore before stinging into PBR for space out Q= 3 bpm at 650 psi SI circulating. Break off circulating head. Check for flow. No flow observed. PU joint 192, and RIH with pumps at 1.38 bpm, 200 psi. Saw good pressure bump to 1000 psi, confirming that seals are engaged in seal assembly. SI pumps, RIH an additional 10', and tagged out on no-go. PU to string wt, and flag pipe. Lay down jt 192, and measure 25.3' to flag. Plan space out based on no go 23.3' below rotary table to allow for 2' space as per proceedure. Baker hand and Co Rep independently calculated space out required, and go the same number. Lay down jts 191, 190. Pick up space out pups, and jt 190. 09:00 - 10:15 1.25 CLEAN P 10:15 - 10:45 10:45 - 12:00 0.50 CLEAN P 1.25 RUNCOrvP 12:00 - 14:00 14:00 - 14:30 14:30 - 23:30 2.00 RUNCOMP 0.50 RUNCOMP 9.00 RUNCOMP 4/29/2005 23:30 - 00:00 00:00 - 01 :15 0.50 RUNCOrvN 1.25 RUNCOrvN 01 :15 - 02:30 1.25 RUNCOrvP RUNCMP 02:30 - 03: 10 0.67 RUNCOMP RUNCMP 03:10 - 04:40 1.50 RUNCOMP RUNCMP 04:40 - 05:05 0.42 RUNCOrvP RUNCMP 05:05 - 07:30 2.42 RUNCOrvP RUNCMP 07:30 - 09:00 1.50 RUNCOrvP RUNCMP Note - Top of seal assembly tagged at 6104.55 based on Nordic 2 RKB. This is 12.45' shallower than completion rig. Printed: 5/2/2005 7:55: 16 AM ") ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3H-26 3H-26 WORKOVER NORDIC CALISTA NORDIC 2 Start: 4/21/2005 Rig Release: 4/29/2005 Rig Number: 2 Spud Date: 4/20/2005 End: 4/30/2005 Date From-To Hours Task Code NPT Phase 4/29/2005 07:30 - 09:00 1.50 RUNCOMP RUNCMP 09:00 - 09:30 0.50 RUNCOrvtJ WAIT RUNCMP 09:30 - 10:00 0.50 RUNCOMP RUNCMP 10:00 - 10:50 0.83 RUNCOI\l1P RUNCMP 10:50 - 11 :30 11 :30 - 12:55 0.67 RUNCOMP 1.42 RUNCOMP The RKB difference between the 2 rigs is 12'. We are exactly on depth with the old tally's. Try to drift tubing hander to 2.91 ". It will not drift. Call for lock for landing nipple to drift with that to see if it will pass. Passed ok. Drift tubing hanger with lock for landing nipple. It drifted fine. Make up tubing hanger and landing joint. RIH with landing joint so that bottom of seal assembly is 2' above seal bore. On line with pumps, pumping 25 bbls of 11.6 ppg NaBr brine with 1% Baker Petrolite CRW132 corrosion inhibiter. Pumping down the backside at 3.0 bpm, 220 psi. Follow with 11.4 fluid out of the pits. RUNCMP RIH, land tubing hanger. RI LOS. RUNCMP RU to pressure test tubing. PT tubing to 2500 psi for 30 minutes. Tubing pressure test. Time Pressure Pressure Drop o min 2580 psi 15 min 2498 psi 82 psi 30 min 2468 psi 30 psi Total pressure drop was 112 psi. Good pressure test 12:55 - 14:00 1.08 RUNCOMP RUNCMP Bleed off tubing to 1525 psi, perform IA pressure test: Time Pressure Pressure Drop Omin 2480 psi 15 min 2450 psi 30 psi 30 min 2430 psi 20 psi Total pressure drop was 50 psi. Good pressure test. Bleed off the IA to check tubing pressure. Tubing pressured up as fA was pressured up. After bleed down, IAP=O, TP=1900 psi. (Termal expansion?) Pressure back up on IA to 2500 psi. Bleed down tubing to 0 to open SO valve. Pump 2 bbls to confirm. 14:00 - 18:00 4.00 RUNCOrvP RUNCMP Set test BPV. NO riser and BOP stack. Nippled up new FMC adaptor spool 18:00 - 18:15 0.25 RUNCOMP RUNCMP Crew change 18:15 - 23:30 5.25 RUNCOrvP RUNCMP Remove old adaptor Install tree and torque up bolts. Lined up as previous completion. Well on slight vacume. Installed tree, Pulled BPV and installed tree cap PT tree to 400 psi and 5000 psi for 10 minutes. Pulled tree test plug and install BPV closed MV & SV. Disconnected ESD from next door well. Conducted 23:30 - 00:00 0.50 RUNCOr RUNCMP RD make ready to move off well and move to 3M-13 RIG RELEASED AT 00:00 hrs 4/30/2005 00:00 - 0.00 RUNCOM RUNCMP Printed: 5/2/2005 7:55: 16 AM ) .: . <, ConocoPhillips Alaska, Inc. 3H-26 API: 501032020800 SSSV Type: NIPPLE Annular Fluid: TUBING (0-6126, OD:3.500. ID:2.992) LOCATOR (6112-6113, OD:4.500) PROD. CASING (0-6117. OD:5.500. \I\It:17.00) ~ LINER (6117-6640, OD:5.000. \I\It:18.00) Perf (6250-6280) - ""- Perf .,...-- (6250-6280) ~ Perf - - (6306-6336) - Well Type: PROD Orig Completion: 3/6/1994 Last W/O: 4/29/2005 Reference Log: 38' RKB Last Tag: 6180 (â} IBP last Tag Date: 4/17/2005 Casing String - ALL STRINGS Description CONDUCTOR SUR. CASING PROD. CASING LINER Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 6250 - 6280 5915 - 5944 6306 - 6336 5969 - 5997 Gas Lift MandrelsfValves St MD TVD Man Man Type V Mfr V Type Mfr 1 2765 2763 CAMCO KBG-2-9 2 4124 4096 CAMCO KBG-2-9 3 4987 4836 CAMCO KBG-2-9 4 5631 5352 CAMCO KBG-2-9 5 6055 5730 CAMCO KBG-2-9 Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 38 38 HANGER 504 504 NIP 6106 5778 NIP 6112 5784 LOCATOR 6113 5785 SEAL 6117 5789 XC General Notes Date Note 4/29/2005 WORKOVER BY CTD 4/29/2005 TREE: FMC 3-1/8" / GEN IV /5000 psi rated Ref Log Date: 1D: 6660 ftKB Max Hole Angle: 39 deg (â} 5150 Size 16.000 7.625 5.500 5.000 Top o o o 6117 Bottom 6126 TVD 5797 Zone C-4, C-3 A-3,A-2 Status Ft SPF 30 8 30 4 ) KRU 3H-26 Angle ~ TS: 19 deg ~ 6220 Angle ~ TO: 11 deg (â} 6660 Rev Reason: PulllBP, set GLV design Last Update: 5/16/2005 Date Type Comment 6/15/1998 RPERF 2 1/8" EnerJet, 0 deg ph 6/24/1994 IPERF 2 1/8" EnerJet, 90 deg. ph VOD Latch Port Bottom TVD Wt Grade Thread 121 121 62.50 H-40 3143 3141 29.70 L-80 6117 5789 17.00 L-80 6640 6288 18.00 L-80 Wt Grade Thread 9.30 L-80 IBT GLV 1.0 DK-1 0.156 1263 GLV 1.0 DK-1 1.875 1305 GLV 1.0 DK-1 0.250 1404 GLV 1.0 DK-1 0.250 1396 OV 1.0 DK-1 0.250 0 Description FMC TUBING HANGER CAMCO BP-61 LANDING NIPPLE CAMCO 'DS' NIPPLE BAKER GBH-22 LOCATOR NIPPLE BAKER BOT GBH-22 SEAL ASSEMBLY, 2.85" DRIFT SBE XO 5 1/2 X5 to 6133' TRO Date Run 5/6/2005 5/6/2005 5/6/2005 5/6/2005 5/6/2005 Vlv Cmnt ID 2.992 2.875 2.812 2.850 2.980 5.000 Re: 3H-26 BOP Test ) ) Subject: Re: 3H-26 BOP Test From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Fri, 22 Apr 2005 15 :25 :23 -0800 To: "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> CC: AOGCC North Slope Office <aogcc-prudhoe_bay@admin.state.ak.us> \<\l-\_ Ö d~ Aras, This confirms our discussion. I also understand that you will be doing a body test of the stack against the new tubing plug prior to pulling the BPV. This is prudent. Good luck with the activities. Tom Maunder, PE AOGCC Worthington, Aras J wrote: Tom, We plan to test the blind rams against the wireline retrievable plug before spearing the hanger. Aras -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admìn.state.ak.us] Sent: Friday, April 22, 2005 2:07 PM To: Worthington, Aras J Subject: Re: 3H-26 BOP Test Aras, HOw will you test the blind rams?? Tom Maunder, PE AOGCC " SCANNED APR 2 5 2005 ,~ ( Worthington, Aras J wrote: Tom, By way of summary of our discussion via phone today: 3H-26 is a Kuparuk producer that Nordic 2 is rigging up on today to do a workover (tbg swap). The well has a BPV installed, Kill-weight fluid in the tbg & annulus and an IBP set below the tbg tail (in the liner). We nippled down to the top flange on 3H-26 to find the hanger lift threads corroded badly enough to predicate make-up of a BOP Test plug. Our plan forward is to nipple up BOPs and run a wireline retreivable plug in the tbg and proceed with our BOP test using the wireline retreivable plug to pressure test against. The tbg hanger will be speared with the test/landing joint both to test annular and pipe rams against and, after the test, to pull the hanger. Aras Worthington Wells Engineer ConocoPhillips Alaska Inc. (907) 265-6802 1 of 1 4/22/2005 3 :25 PM ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report S u bm it to: .W.n..X.Œ:l9.@.ªgLt~.tLU?tªtfLª-~J¿.§ ª9.~aç.\~...QLU~ij.l~!g..Jdª-Y@.ft\i!J.ÜLL~~tª.~ª.:ª~:.~~ Þ.Q.tLngÇ.~~m§'\ºjn@ªgm.tLU?tªtfLª.~J¿.§ Rig No.: 2 DATE: 4/23/05 Rig Phone: 659-4398 Rig Fax: 659-4356 Op. Phone: 659-4393 Op. Fax: 659-4356 E-Mail ~.~m~iY1.çlrJim.m:g¡~~;?t~!9.111!d§.b.~~[@.~1P:.Ç¿~!J PTD # 194-029 11/09/04 Contractor: Nordic Rig Rep.: Holmes-Igtanloc Operator: BPX Rep.: SARBER-FEKETI Well Name: KRU 3H-26 Operation: Drlg: Test: Initial: XXX Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Well Sign Dr!. Rig Hazard Sec. BOP STACK: Quantity Size/Type Stripper 1 Annular Preventer 1 7 1/16" #1 Rams 1 Blind / Shear #2 Rams 1 #3 Rams 1 2 3/8" X 3.5" #4 Rams 1 #5 Rams N/A Choke Ln. Valves 1 3 1/8" HCR Valves 2 3 1/8" Kill Line Valves 1 3 1/8" Check Valve 0 N/A CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P 1 Workover: XXX Weekly: Annular: 250/3500 TEST DATA Test Result P P P Test Result NT P P NT P NT NA P P P NA Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly NT Lower Kelly NT Ball Type 1 P Inside BOP 1 P MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Visual P P P P P Alarm P P P P P Quantity Test Result I nside Reel valves NT ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 2300 P 200 psi Attained 20 sec P Full Pressure Attained 59 sec P Blind Switch Covers: All stations Y Nitgn. Bottles (avg): 4@ 2150 Test Results Number of Failures: º Test Time: ª Hours Components tested 25 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: .HH1...r.i29g@ªgm.tLU?tªt&~ª-~J¿.§ Remarks: There was a 1.5 hour gap during testing to repair a leaking riser air boot. YES 24 HOUR NOTICE GIVEN XXX NO Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector Date 4/21/05 Time Test sta rt 0930 Finish Coil Tubing BFL 11/09/04 Waived By Jeff Jones 07:30 Witness Rob Robinson 1600 Nordic 2 BOP 4-23-05p.xls ol, ggFO STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate _ Pull tubing Alter casing Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska. Inc. Development X. 80' RKF 3. Address: Exploratory_~. 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service ~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1384' FNL, 281' FWL, Sec 12, T12N, R8E, UM 3H-26 At top of productive interval: 9. Permit number/approval number: 2592' FNL, 39' FEL, Sec 11, T12N, R8E, UM 94-29 At effective depth: 10. APl number: 2563' FSL, 63' FEL, Sec 11, T12N, R8E, UM 50-103-20208-00 At total depth: ! 1. Field/Pool: 2562' FSL, 63' FEL, Sec 11, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 6660 feet Plugs (measured) None true vertical 6308 feet Effective Deptt measured 6653 feet Junk(measured) None true vertical 6301 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 200 Sx CMT 121' 121' Surface 3105' 7-5/8" 500 Sx AS III & 3143' 3141' 300 Sx Class G Production 6602' 5" 210 Sx Class G 6640' 6288' Liner Perforation Depth 0//~/~,~//~/¢,~~ measured 6250'-6280'; 6306'-6336' true vertical 5915'-5944'; 5969'-5997' Tubing (size, grade, and measured depth) 0 L,. 1[' ~ Mixed 2.875", 9.3 Ib/ft, L-80 & 3.5", 9.3 lb/fi, L-80 @ 6117' Packers and SSSV (type and measured depth) ~S~(~ 0il & GEtS 0011S. Anchorage Packer: None'; SSSV: None, Camco BP61 Nipple @ 1836' 13. Stimulation or cement squeeze summary Fracture stimulate "C" sand on 6/18/98. Intervals treated (measured) 6306'-6336' Treatment description including volumes used and final pressure Pumped 213.643 lbs of 16/20. 12/18. & 10/14 ceramic proppant into formation, fp was 7232 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 497 251 1260 1368 177 Subsequent to operation 842 404 2708 976 176 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil _X Gas _ Suspended _ Service _ 17. I herebyic, edify that the foregoing is true and correct to the best of my knowledge. Signed ~~.~----------___ Title: Production Engineering Supervisor Date ~//f.~-'/~ c~ Form 10-404 Rev~6fl/5/E~] SUBMIT IN DUPLICATE. ~, KUPARUK RIVER UNIT /ELL SERVICE REPORT 3H-26(4-1)) WELL JOB SCOPE JOB NUMBER 3H-26 FRAC, FRAC SUPPORT 0611980904.7 UNIT NUMBER DATE 06/18/98 DAY 3 FIELD ESTIMATE DAILY WORK C SAND REFRAC OPERATION COMPLETE I SUCCESSFUL ] KEY PERSON ~ Yes O No ~_~ Yes O No DS-GALLEGOS AFC# lOC# J DAILY COST ACCUM COST KD2413 230 DS36H L $132,449 $165,555 InitialTbg IFinalTbg IlnitiallA IFinallA IlnitialOA IFinalOA ITTLSize 1490PSll 1200PSll 490 PSI 500 PSI 0 PSI 0 PSI 0.000 " SUPERVISOR JORDAN Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY C SAND REFRAC SCREENED OUT 37 BBL INTO FLUSH AT 7232 PSI MAX TREATING PRESSURE. 213,643 LBS PROPPANT PLACED IN FORMATION WITH 6,547 LBS PROPPANT LEFT IN WELLBORE. [Frac-Refrac] TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT - GALLEGOS; APC PUMP. TGSM, 19 ON LOCATION. 09:51 PT LINES TO 12,199 PSI OK. 10:00 PUMP BREAKDOWN AND SCOUR STAGE ACCORDING TO PROCEDURE. PERFORM STEPDOWN TEST AT END SD AND OBTAIN ISIP 1808 PSI. 11:27 PUMP DATA FRAC ACCORDING TO PROCEDURE. SHUTDOWN AND MONITOR PRESSURE DECLINE. ISIP 2046 PSI. ADJUST PAD SIZE. 13:20 PUMP FRAC ACCORDING TO FRAC SCHEDULE. RAMP PROPPANT FROM 2 PPA TO 14 PPA. HELD 2PPA AND 1 PPA STAGES FLAT ACCORDING TO SCHEDULE. 15:04 SCREENED OUT 37 BBL INTO FLUSH. MAX TREATING PRESSURE 7232 PSI. 213,643 LBS PROPPANT PLACED IN FORMATION. 6,547 LBS PROPPANT LEFT IN WELLBORE. 17:00 RDMO DS FRAC UNIT. TURNED WELL OVER TO CTU. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $21.00 APC $13,000.00 $13,200.00 DIESEL $0.00 $609.00 DOWELL $136,449.00 $136,449.00 HALLIBURTON $0.00 $4,460.00 LITTLE RED $0.00 $4,255.00 SCHLUMBERGER $0.00 $6,561.00 TOTAL FIELD ESTIMATE $149,449.00 $165,555.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 2592' FNL, 39' FEL, Sec. 11, T12N, R8E, UM At effective depth 2563' FSL, 63' FEL, Sec. 11, T12N, R8E, UM At total depth 2562' FSL, 63' FEL, Sec. 11, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6660 feet Plugs (measured) 6307 feet 6653 feet Junk (measured) 6300 feet 6. Datum elevation (DF or KB) RKB 80 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-26 9. Permit number/approval number 94-29 10. APl number 5o-103-20208 feet 11. Field/Pool Kuparuk River Field/Oil Pool None None 0RI$1NAL Casing Length Structural Conductor 8 0' Surface 31 0 2' Intermediate Production 6632' Liner Perforation depth: measured 6250'-6280', true vertical 5915'-5944', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6127' Packers and SSSV (type and measured depth) Size Cemented Measured depth True vertical depth 1 6" 200 Sx CMT 1 21' 1 21' 7-5/8" 550 Sx AS III & 31 43' 31 39' 300 Sx Class G 5" 210 Sx Class G 6640' 6288' 6306'-6336' 5969'-5998' PKR: Baker Loc Seal Assmbly @ 6117'; SSSV: None, Camco Nipple @ 1835' 13. Stimulation or cement squeeze summary ' ' Perforate 'C' Sands on 4/9/97. -41astC~'Oil&.6as Intervals treated (measured) ........ (,UIIIiTliSS,' ,[~ .F~[ ' - · 6 2 5 0' - 6 2 8 0' '" ~rlu~iorai).¢ Treatment description including volumes used and final pressure Perforated using 1-11/16 pivot guns w/22GM RDX charges @ 4 SPF, fp was 1925 psi 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 656 413 921 937 156 Subsequent to operation 825 532 1009 952 158 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~~ ~,~,~ Title Wells Superintendent Form /~-~0,4/ Cf'er/ 06'7~578~ / Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~' K1(3H-26(W4-6)) WELL JOB SCOPE JOB NUMBER 3H-26 PERFORATE, PERF SUPPORT 0127970757.1 ,, DATE DAILY WORK UNIT NUMBER 04/09/97 PERFORATE "C" SANDS F/6250 - 6280' ELM UNIT #1 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O No (~) Yes O No SWS-BAILEY B;~i~_K~-.t--.~ FIELD AFCff CC# DALLY COST ACCUM COST Si ~_,2 ESTIMATE KAWWRK 23ODS36HL $36,983 $37,406 ,, Initial Tbq Press "Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann' ~ ~=inal Outer Ann 1250 PSI 1925 PSI 0 PSI 1250 PSII 0 PSI 0 PSI DAILY SUMMARY PERFORATE "C" SANDS F/6250 - 6280' ELM W/1-11/16" PIVOTS W/22GM RDX CHGS @ 4 SPF & 180 DEG PHASED. TIME LOG ENTRY 09:00 MIRU SWS (WALSH/BAILEY & CREW). MU DUMMY PIVOT RUN (1-11/16" CCL/GR)TL-15'. TGSM. PT BOPE TO 3000 PSI. 10:30 RIH TO 6340' ELM. TIE IN W/GR. NO PROBLEMS ON DUMMY RUN. POOH. 12:00 MU GUN RUN#1 (10'- 1-11/16" PIVOTS/CCL)TL-15'. PT. RIH TO 6340' ELM & TIE IN TO DUMMY RUN & 3/20/94 SWS CBT. 14:00 PERFORATE F/6270 - 6280' ELM W/1-11/16" PIVOTS W/22 GM RDX CHGS @ 4 SPF PHASED 180 DEG. SAW SURFACE INDICATION. POOH F/2ND GUN RUN. 15:00 O©H. ALL SHOTS FIRED. MU GA#2 (SAME AS BEFORE) & RIH TO 6340' ELM. TIE IN (A LITTLE TIGHT PULLING UP) & PERFORATE F/6260 - 6270' ELM W/SAME GUNS, ETC AS BEFORE. POOH F/LAST GUN RUN. 17:45 OOH. ALL SHOTS FIRED. MU GA#3 (SAME AS BEFORE) & RIH TO 6260. TIE IN & PERFORATE F/6250 - 6260' ELM W/SAME GUNS, ETC AS BEFORE. POOH. 21:15 OOH. ALL SHOTS FIRED. RD SWS & TURN WELL OVER TO PRODUCTION TO BE BROUGHT ON. OFF LOCATION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $500.00 $500.00 HALLIBURTON $0.00 $423.00 SCHLUMBERGER $36,483.00 $36,483.00 TOTAL FIELD ESTIMATE $36,983.00 $37,406.00 P E R I,~/Ii T B, A, T/:, T. D A ¥,4\ ~..[:, L LJ S g/4. ..... 0c29 CBT L. ~200 .... 6.%1z~ ga..'-02.9 ~'1 OS. ,g&~ .... 029 b~i',IT'-'G/DC ge., -~-029 ~37 9-~ '--. 029 9~"~029 ~'I LD T 9a.'~- 029 ~¢., 168 L 4200~ 6z~.3 (S T 6 I 00 --- 64~ 2/-~ ~ (3 I.,t .... I~E B. I T / C N T (~ L 6090 ..... 6~'.~5C.i T 6 I00-6z135~ L 6 100 .... 6~50 L 6102---6~50 ;S }"1 ---C N T,S 7' 6100--6A,.38: CH'~t--ILDT [Da'Re: IR tJ '1 '1 ,j '1 '1 1 '1 0/t./' '1 C) / 9 6 C)/!../C) 6 / 9 t+ 04~//0 (3 ,/' 9 ~, 05/09/9/.~ () 5//C) 9 ,,,,' 9/4- r.i) 5/3 '1/9 05 / ~ '1 / (i) L~. 0 '?//(36 / .~?, 0 '? / 06 ,/' 9/4. ar'e dr'y d~'tch W a s t h e w e 'i 'i samp i es. coi."ed ? r'equ'):r'ed"? yes ~cJ r'ece'i'veri'',~ yes yes (~~ys'i's &: d~scr'lpt')'or~ r" <~ ,::~'~ ',,/ ,r~ ,ct '..,' ,A,i--'e we i i Well a's C C' H h'i~:. ~ bi T S y E: S t'l O ARCO Alaska, Inc. Date: July 1, 1994 Transmittal #: 9111 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATe- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 18-15 18-16 18-14 18-14 18-14 18-16 18-16 18-16 18-16 / 18-14 18-14 18-15 18-15 18-15 18-13 18-13 18-17 1B-17 3H-26 18-18 ~118.188-18 HLDT 05-02-94 6650-7300 HLDT 04-05-94 7250-6730 HLDT 03-30-94 9640-9200 CDR 03-18-94 5650-9980 CDR Enhancement 03-18-94 8900-9970 CNT-G 04-05-94 6670-7350 CDR 03-24-94 4370-7450 CDR Enhancement 03-24-94 6440-7430 TDTP 03-28-94 6640-7340 TDTP 03-25-94 9200-9770 CNT-G 03-30-94 9200-9770 CNT-G 05-02-94 6650-7260 CDR Enhancement 04-14-94 6450-7440 CDR 04-14-94 4100-7450 CDR Enhancement 04-20-94 6800-7890 CDR 04-20-94 4420-7890 CDN 04-20-94 4420-7890 CDR 03-29-94 4160-6640 CDR Enhancement 03-29-94 4240-6640 HLDT ~¢ ~ ~ 04-05-94 6102-6450 .~ Dual Induction-SFL-GR 04-29-94 4254-7778 j(5' Phasor Processed) Compensated Neutron- 04-29-94 4254-7754 Lithology Density (Raw Data) ,/'Compensated Neutron- 04-29-94 4254-7754 Lithology Density (5" Porosity) Acknowledged: RECEIVED Date: j Alaska .0il .& Gas Oo.s. C0mmissiQ,~ Anoho~age DISTRIBUTION: D&M Drilling Catherine Worley(Geology) NSK State of Alaska (+Sepia) Bob Ocanas STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL r'-'-I GAS F-I SUSPENDED ~ ABANDONED [] SERVICE I~I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 94-29 3 AddressORIGINAL 8 APINumber P.O. Box 100360, Anchorage, AK 99510-0360 ' 50-103-20208 4 Location of well at surface ~ ........... ~ 9 Unit or Lease Name 1384' FNL, 281' FWL, SEC 12, T 12N, R 8E, U~ [~/),'r~/ ~ -'~ , KUPARUK RIVER At Top Producing Interval~i, .... L¢~/~_~._..~',,~" '~' ~ l,~T~C~¢~Flllr~ 10 Well Number 2688'DepthFSL, 39' FEL, SEC 11, T 12N, R 8E, UM i;:' ~J~':~.];~ !; ¥'~.,~~~..,~.~.,.~,,.~, , 3H-26 At Total !~ ~--.,~--4~"~--.. i~ .~' 11 Field and Pool 2562' FSL, 63' FEE, SEC 11, T 12N, R 8E, UM ~ il KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 80', PAD 39' GLI ADL 25531 ALK 2657 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore J16 No. of Completions 27-Feb-94 05-Mar-94 05/19/94(RR)-Perfed 06/24/94I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost 6660 MD, 6307' TVD 665-3z MD 6300' TVD YES X~ NO LII LN @ 1835' feet MDI 1600' APPROX 22 Type Electric or Other Logs Run CBT, CET, CNL, CFD, CNT-G 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEME]'~I' RECORD 16. 62.5# H-40 SURF 121' 24" 200 SX CMT 7.625 29.7# L-80 SURF 3142' 9.875" 550SX ASIII, 300 SX CLASS G CMT 5. 18# L-80 SURF 6640' 6.75" 210 SX CLASS G CMT 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9.3# L-80 6127' 6117'(Top of Seal Bore Ext.) 6306'-6336' @ 4 spf md 5969'-5998' tvd 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC *Perfed w/2-1/8" BH Enerjet 06/24/94. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ FIowTubing iCasing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OiL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ¢.., ,;.~i,,r, Oil & Gas Co~s, ~.;r~rnmis Anchors.qo Form 10-407 Submit In duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29, I 30, ,. GEOLCX~IC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gra MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 6218' 5885' BASE KUPARUK C 6286' 5950' 31. LIST OF A'I-rACHMENTS REPORT OF OPERATIONS, 2 COPIES OF DIRECTIONAL SURVEY 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. Signed..~~~'~ Title ~.. ~)..,-./__~_/-- ~"'~.,,..J/~ . DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measuremer given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cemen' lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". _.CO ALASKA INC. WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3H-26 NORTH SLOPE BOROUGH KUPARUK RIVER KUPARUK RIVER ADL 25531 ALK 2657 50-103-20208 94-29 DAILY OPERATIOn PAGE: 1 ACCEPT: 02/27/94 07:00 SPUD: 02/27/94 05:30 RELEASE: 05/19/94 12:00 OPERATION: DRLG RIG: PARKER 245 WO/C RIG: NORDIC 1 02/27/94 ( 1) PARKER 245 TD: 121' ( 121) MOVE RIG F/3H-25 TO 3H-26 16"@ 121' MW: 0.0 VIS: 0 MOVE RIG 165' F/3H-25 TO 3H-26. 02/28/94 ( 2) PARKER 245 TD: 121'( 0) 03/01/94 ( 3) PARKER 245 TD: 3155' (3034) 03/02/94 ( 4) PARKER 245 TD: 4000' ( 845) DRILL 9-7/8" HOLE 16"@ 121' MW: 9.6 VIS: 58 FIN MOVING RIG F/3H-25 TO 3H-26. NU DIVERTER SYSTEM & TEST SAME. FILL ANN & CHECK F/LEAKS. BOBBY FOSTER W/AOGCC WAIVED WITNESSING TEST. REFAB PIPE GUARD ON TOP DRIVE FOR 4" DP. MU 4" HANDLING TOOLS. PU 2 STDS DC'S, 10 STDS 4" HWDP, & 20 STDS 4" DP, RABBIT SAME. PU 9-7/8" BIT & NAVIDRILL MOTOR. CLEAN OUT CMT & ICE F/75'-121' DRILL 9-7/8" HOLE F/121'-297' W/MOTOR & 3 STDS HWDP. STAND BACK 3 STDS HWDP & MU BHA. ORIENT MWD. REPLACE BRUSHES IN BOTH DRAWWORKS TRACTION MOTORS. ORIENT UBHO GYRO SUB & MU 2 STDS DC'S. DRILL 9-7/8" HOLE F/297'-1670', TAKING GYRO SURVEY @ 652', 928', 1385' ND DIVERTER 7-5/8"@ 3141' MW:10.0 VIS: 42 DRILL 9-7/8" HOLE F/1670'-3155' CBU. SHORT TRIP. CIRC & COND MUD. POOH TO RUN CSG. HOLD SAFETY MEETING. RUN 7-5/8" 29.7% L-80 LTC CSG W/SHOE SET @ 3143'. RU DOWELL & CMT W/500 SX ASIII 12.1 PPG CMT FOLLOWED BY 300 SX CLASS G 15.8 PPG CMT. DROPPED TOP PLUG, PUMPED 20 BBLS WATER & DISPLACED W/RIG PMP. DISPLACED TOTAL OF 140 BBLS. LOST RETURNS 60 BBLS INTO DISPLACEMENT. NO CMT TO SURF. RECIP CSG. RD CSG TOOLS. LD LANDING JT. ND DIVERTER. DRILLING 6-3/4" HOLE 7-5/8"@ 3141' MW: 8.7 VIS: 34 RU DOWELL. RIH W/i" TBG & CMT'D THE 7-5/8" X 16" ANN W/16.5 BBLS CLASS G ASI(TOP JOB). MU 11-3/4" BTC X 11" 3M FMC STARTING HEAD. NU BOP. CHANGED OUT PIPE RAMS TO 4" IN TOP & BTM CAVITIES. MU TEST PLUG. TEST BOPE TO 300/3000 PSI. CHANGED OUT LOWER IBOP. MU BHA & SURF TESTED MWD. RIH W/SAME. CLEANED OUT 7-5/8" CSG TO FC. CIRC. TEST 7-5/8" CSG TO 2000 PSI FOR 30 MIN. DRILL OUT FC, CMT, FS, & 10' OF NEW FORMATION TO 3165'. CBU. PERFORM FIT TO 12.9 PPG EMW @ 3165'/3163' DRILL 6-3/4" HOLE F/3155'-4000' RECEIVED JUN 2 8 i994 (Jii & Gas Cons. Commission Anchora~Qe .~LL: 3H-26 API: 50-103-20208 PERMIT: 94-29 PAGE: 2 03/03/94 ( 5) PARKER 245 TD: 6035' (2035) 03/04/94 ( 6) PARKER 245 TD: 6053' ( 18) 03/05/94 (7) PARKER 245 TD: 6630' ( 577) 03/06/94 ( 8) PARKER 245 TD: 6660' ( 30) 03/07/94 ( 9) PARKER 245 TD: 6660'( 0) 03/14/94 (10) DOWELL TD: 6660 RIH W/6-3/4" BIT 7-5/8"@ 3141' MW: 8.9 VIS: 35 DRILL 6-3/4" HOLE F/4000'-4559' SERV RIG. DRILL 6-3/4" HOLE F/4559'-5021' CBU. SHORT TRIP. DRILL 6-3/4" HOLE F/5021'-6035'. SURV W/MWD & CBU. POOH W/BIT. LD MACH 1 MOTOR & SLIM 1 MWD PROBE. MU 6-3/4" BIT & ROTARY BHA. RIH W/SAME. RIH W/6-3/4" BIT 7-5/8"@ 3141' MW:ll.7 VIS: 44 RIH W/6-3/4" BIT & ROTARY ASSY TO 6000'. ATTEMPT TO CIRC W/3500 PSI. DRILL STRING PLUGGED. POH W/WET STRING & CLEAN OUT LCM F/HWDP, DC'S & BIT. BIT PLUGGED W/LCM & SCALE. TIH W/6-3/4" BIT & ROTARY BHA BREAKING CIRC EVERY 2000' CIRC & COND MUD. FINISH ADDING 30 PPB LCM TO MUD SYSTE~. CIRC & RAISED MW TO 11.7 PPG. NO LOSSES. DRILL 6-3/4" HOLE F/6035'-6053' DRILLING 6-3/4" HOLE 7-5/8"@ 3141' MW:ll.7 VIS: 52 DRILL 6-3/4" HOLE F/6053'-6202' HOLE F/6202'-6630' SERV RIG. DDRILL 6-3/4" RUNNING 5-1/2" X 5" CSG 7-5/8"@ 3141' MW:ll.7 VIS: 47 DRILL 6-3/4" HOLE F/6630'-6660' CBU. SHORT TRIP. CIRC HOLE CLEAN & DROPPED SURV. SERV RIG. POOH W/6-3/4" BIT. LD HWDP & BHA. CHANGED OUT TOP 4" PIPE RAMS TO VBR'S & TESTED BONNET SEALS TO 3000 PSI. RU CSG TOOLS & HOLD SAFETY MEETING. RAN 12 JTS 5" 18# L-80 LTC CSG. ATTEMPT TO MU 5" LTC X 5-1/2" LTC CROSSOVER/SEAL BORE EXT. GALLED THREADS IN 5-1/2" BOX OF SBE/XO, BROKE OUT SAME. W/O SBE. MU NEW SBE/XO & RAN 5-1/2" 17# L-80 MOD LTC CSG TO 7-5/8" CSG SHOE @ 3143' CIRC HOLE CLEAN. RUN 5-1/2" CSG. FINAL REPORT 5-1/2"@ 6640' MW: 0.0 ViS: 0 FIN RUNNING 5-1/2" CSG. TOTAL OF 12 JTS 5" 18# L-80 LTC & 144 JTS 5-1/2" 17# L-80 LTC. 5" FS @ 6641. CIRC & COND MUD WHILE RECIP CSG. RU DOWELL. CMT W/210 SX CLASS G CMT. CIP @ 10:10 HRS 03/06/94. RD CSG TOOLS. PU STACK. MADE ROUGH CUT ON 5-1/2" CSG. SET BACK BOP STACK. MADE FINAL CUT ON 5-1/2" CSG & INSTALLED PACKOFF. NU TGGHEAD & VALVE. TESTED TBGHEAD TO 3500 PSI. FREEZE PROTECT ANN W/150 BBLS FW FOLLOWED BY 52 BBLS DIESEL @ 750 PSI. CUT DRILL LINE. CHANGE SAVER SUB & GUIDE BOWL TO 5". LD 4" DP F/DERRICK. RELEASE RIG @ 2300 HRS 03/06/94. 5-1/2"@ 6640' 03/14/94 (11) DOWELL TD: 6660 DO ARCTIC PACK JOB. 5-1/2"@ 6640' RECEIVED ,jijh! 2 8 1994 Oil & Gas Corm. r.;orr~missior, Anchorage .~:LL: 3H-26 API: '- 50-103-20208 PERMIT' 94-29 PAGE: 3 05/18/94 (12) NORDIC 1 TD: 6660 PB: 6653 05/19/94 (13) NORDIC 1 TD: 6660 PB: 6653 05/20/94 (14) NORDIC 1 TD: 6660 PB: 6653 NU TBG SPOOL 5-1/2"@ 6640' MW' 0.0 MOVE RIG F/3H-23 TO 3H-26. ACCEPT RIG @ 0300 HRS 05/18/94. BLEED PRESS OFF 5-1/2" X 7-5/8" ANN. ND DRY-HOLE TREE & TBG SPOOL. CHANGE EXISTING 5-1/2" PACKOFF, INSTALL NEW ARCTIC-GRADE PACKOFF. NU SPOOL. RU OTIS SL 5-1/2"@ 6640' MW:ll.7 NaC1 FIN NU TBG SPOOL, BOPS. TEST CSG & BOP'S TO 3500 PSI F/30 MIN. OK. FIN LOADING PIPE SHED, SLM & DRIFT TBG. PU COMPLETION EQUIP, INSTALL SEAL RINGS. RUN 127 JTS 3-1/2" 9.3# L-80 TBG W/2-7/8" TBG ABOVE & BELOW EACH GLM. SPACE OUT, LD 2 JTS. POOH TO BP 61 SSSV. SPACE OUT W/3 PUP JTS, lo. ' 6', & 2' EUE 8 RD L-80 . MU CONTROL LINE, TEST TO 5000 PSI F/10 MIN-OK. TIH W/TBG & CONTROL LINE, BANDING 1/4" LINE TO TBG. USED 34 BANDS, UP WT 42,000, SLK WT 36, 000, LAND TBG. RILDS. TEST ANN TO 2500 PSI F/15 MIN-OK. TEST TBG TO 3000 PSI F/15 MIN-0K. RD TEST LINES, SET TEST PLUG. ND BOP, NU TREE & TEST TO 250-5000 PSI-OK. RU OTIS SL, TEST LUB TO 2000 PSI. RIG RELEASED 5-1/2"@ 6640' MW:ll.7 NaC1 RIH W/WL, PULL PACKOFF F/CAMCO BP61 LANDING NIPPLE @ 1835' & RIH, PULL D/V FROM GLM #1 @ 6066' CIRC 58 BBLS DIESEL DOWN TBG, LEFT 53 BBLS IN TBG & 5 BBLS ON BACK SIDE FOR UNDERBALANCE & FREEZE PROTECTION. RIH & SET D/V IN GLM #1, RESET PACKOFF IN LANDING NIPPLE. 1250 PSI DIFF PRESS ON TBG. BLEED PRESS OFF TBG. MONITOR TBG. RD OTIS. CLEAN PTIS & PREP RIG FOR MOVE TO 1H PAD. CAMP ON ROAD @ 1100 HRS, RIG @ 1200 HRS. SIGNATURE: . (drilling~s r~) DATE: RECEIVED Cas Cons. Commission Anchorage~. Date:06/27/94 Page: 1 ARCO ALASKA INC. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL:3H-26 TYPE:DEV RIG. ACCEPT: 05/18/94 CODE:3 06/24/94 (15) TD:06660 PB:06653 SUPV:BB SECURE WELL AFTER PERFING 5-1/2"@6640 MW:ll.7 NaCl RU SWS. PT LUB T/1200 PSI. RIH W/GUN #1, 2-1/8" BH ENERJET, 2 SPF, ORIENTED 90 DEG CCW FROM HIGH SIDE, TIED IN. FIRED GUN #1, PERFED 2 SPF F/6306'-6336' (30' TOTAL). POOH W/WL. WELLHEAD PRESS, INC F/250 PSI T/1350 PSI. (PERFED 1,OOO PSI UNDERBALANCE). PU GUN #2, ORIENTED 90 DEG CW FROM HIGH SIDE. P/T LUB TO 1200 PSI. RIH W/GUN 92, TIE IN AND PERF F/6306'-6336' (30' TOTAL). POOH W/WL. ASF ON GUNS 1 & 2. SECURE WELL & RIG DOWN. FINAL TBG PRESS=1350 PS~. TBG & CSG ANN PRESS=0 PSI. LEAVE LOC @ 1700 HRS 06/24/94. RECEIVED JU q 28 ]994 /,.~,Ska (iii & ~as Cons. Coi'~lmissior~ Anchora,.je ORIGINAL fi ft de---: CLO~JR, E TOOL FACE DLS DL~T ft deg de~l(VJft deg/lOOft*~.2 12!,0 !2i,£4) 0,00 0,~ 0,00 0,00 0,00 0,00 0,00 0,00 0,00 0,00 5,~t-c) 543,9'7 i 1,;~- 0,~0 0,0r, n.rF~ 0,'3) 0,07 ~,0 ~7,~ 2,00 3,~ 0,76 -145,{~ -i45,00 -~,92 1,42 1~,49 1,64 0,51 1264,0 i263,07 t=~ ~ !742~0i -O,&6 2,~ -0,14 -7,13 -I~,13 -I,49 0,00 O,OC' 0 15 0,02 ,~-'1,5 m-Pig,A8 0,00 2,34 O,C~' t'-, ._.. . -.~,,~ -iT!,~A -2,67 -64,% 96,91 0,i2 0,0! ~'74~6 2592,63 -0,10 2,24 -0,03 3,57 -156,25 0,96 -79,3B 126,4~, 0,05 0,02 ~J66,6 3064,15 -0,!5 2,07 -0,03 -2,82 -161,07 -0,6~:' -96,~,3 146,28 0,04 3213,8 32!!,~:' 0,3! 2,~ 0,21 -5,53 -1~,60 -3,76 -102,08 37,92 0,26 0,15 ~2,3 3~?,~ O,~J 3,20 O,E8 -57,00 -~,E~ -4~,10 -45,76 156,~8 2,33 I,~ 3422.3 341%17 4.00 7.20 4.44 -17.50 -241.10 -19.44 -106.00 30.50 4.73 2.67 3522.0 317.53 4.~ 1i.40 4.2! -6.10 -249.20 -B.12 -103.14 21.34 4.40 362.3 3615.64 0.10 II.50 0.10 1.50 -247.70 1.50 -96,46 72.16 0.31 4.06 ~.i~. i.~ 12.70 1.21 2.BO -244.~0 -94.37 2.7.~. 1.34 1.03 ~21.2 360~57 2.50 15.33 2.52 2.~ -242.10 2.82 -105.63 103.73 2.60 1.27 d--"2=,J ~ruj,xx 2,20 i7,40 2,20 4,30 -237,60 d,~$ -68,~ 30,82 2,5! ~JC6~3 3?85.38 i.90 19.3:, 2.26 0.70 -237.10 0.83 -67.16 6.96 2.28 0.27 4!00.3 ~:)73.97 3.70 23.00 3.69 -0.70 -237.60 -0.74 -85.65 4.~ 3.90 1.71 4194.1 4159~72 1.80 24.~ 1.92 1.40 -2~..40 1.49 -&4.20 18.13 2.01 2,02 4263.6 4240.33 1.'~ 26.70 2.12 -0.60 -237.(~) -0.67 -90.79 16.46 2.14 0.1~ 43~,1 ~o ~ 2,00 28,70 2,23 1,:-Q. -23,70 i,45 -81,96 17,40 2,33 0,21 4502,? 4432,15 0,5:) ~',20 0,~' 0,70 -2~5,C~ O,SM -81,47 34,47 0,47 1,44, 4594,8 q5i2,20 2,90 32,10 3,16 -1,~ -2~,,00 -1,09 -81,01 10,40 3,20 4760,4 4667,05 2,70 ~z -c ~-" ~"- 29 .,,~ ..1.45 -2,60 -~so,.~v -~.,~-~ -7~,76 ,0~ 1,..~ ~, . u,=< -1,74 -83,00 6,06 1,04 0,33 5i49,9 4965,~; 3.70 39.20 2. i0 1.10 -240.70 0.59 %4.66 10.13 2.13 0.5~ .~,:~ -i,uu ~,~:) -u,oo ~,4u ~.,~ ?3 -46,30 139,34 0,88 0,82 5452,4 ~" "~ _. 2,~n -237, ' '= =~v~,~ -2,i0 ~F,,IO -1,~? ~ 10 ~,~J -41,06.' 148,~ I,M 0,~$ 5635,4 "~=~.,, ~:'~, -4,20 31,iQ -2,2~ 0,00 -237,10 O,d~. -37,15 0,00 2,26 0,35 _57%,~ C~N,O? -2,10 '29,~0 -i,3I -3,~0 -2~0~70 -2,24 -~7,07 7~,~ 1,74 0,34 ~:~J ~ ~z=o,81 ',m~ _m 07 ,. ~=,, ~ -o w 23,~C' ~,~. -5,60 -2~A,30 -3,15 -19,46 159,66 3,66 1,06 S~NCLE SHOT AP~,O ~ ~- ~w i~v _ , -8,46 167,01 2,15 0,24 THE '^~ .... "~" 6AE,:),u.. ,,~w,v~ O, C,,00 0,~:) -2~:,,D v,w -9,33 90,00 0,00 3,91 ~21.53 478.i 2219.66 ~.,~o 373,3 25~2,63 30¢%,64. 471,9 3064,15 3213,80 147,2 3211,20 33~,30 116,5 3329,55 3422,30 90,0 ~19,17 3~22,00 99,7 317,53 3622,30 100.3 3615.64 3721,1~q 97,5 3713,13 3821,20 99,4 3609,59 3921,73 I00.1 3905,(6 4005,30 84,0 3f'B5,36 410~,30 95,0 4073,97 4194,10 93,6 4159,72 4263,60 ~?,5 4240,33 4a, 3,10 69.5 4319,57 ~02,90 129,6 4433,15 4594,&:~ 91.9 4512,20 47~,,40 185,6 4667,05 4963,60 163,4 4617,19 5149,90 166,1 4965.~ 5300.?0 151.0 5083,14 ...~,.~ 151,5 5203,BB 5636,40 164.0 5356,39 57%,80 160,4 5f'74,70 177.9 5652,81 SINGLE SHOT S~VE¥ 6605,00 630,3 6253,02 Tile LAST ~URVE¥ IS F'ROJECT£D 66~?,00 ~,0 6307,01 *******~* ~4ADRILL *************~ SU~JEY CALCULATIDI'~ ****~ RADIUS OF CUP, VATURE METHOD********TP~Gl~ STATI~ AZIiqUTH LATITUDE S~CTIg~ IHCU~, ~-S £/-~ ft deg deg f~ ft 0,00 0,00 6~,CQ 0,00 0,00 -2,65 1,25 69,00 1,65 4,31 -10,10 3,25 264,~:) 9,45 3,83 -10,93 3.00 286,00 16,30 -20,0(, -11,07 2,34 260,67 21,~7 -41,69 D£F'ARTU~£ DISPLACEEEH? at AZIMUTH ft 0,00 0,00 4,61 69,~ 10,20 22,06 ~,65 309,10 47,0B 297,66 -7,66 2,34 267,16 23,23 -61,15 65,41 ~0,60 -3,76 2,24 Z?O,~ 22,96 -76,06 79,46 266,B0 0,77 2,09 267,93 22,76 -93,91 96,63 263,62 2.64 2,40 262,40 22,27 -%',65 102,11 262,60 6,91 3,20 205,40 19,00 -104,14 !05,B6 260,34 15.02 7,20 187,90 11,22 -106,47 107,06 276,01 30,86 11,40 179,B0 -4,84 -107,b5 107.66 267,42 50,22 11,50 181.30 -24,76 -107,74 110,55 2~,06 70,67 12,70 164,10 -45.59 -108,72 I17,B9 247,25 94.36 15,20 166,90 -69,44 -lll,OZ 130,95 237,9B 122,34 17,40 191,20 -97,17 -115,44 150,69 229,91 148,75 19,30 191,~ -123,06 -120,73 172,41 224,45 182,99 23,00 191,20 -156,66 -127,59 ~2,04 219,16 220,96 24,60 192,60 -193,64 -135,4~ 236,46 214,~4 259,63 26,70 192,00 -231,83 -143,71 772,76 211,79 301,41 26,70 193,~3 -272,42 -152,82 312,36 209,29 364,24 29.20 194,00 -333,47 -167,65 373,24 206,69 411,06 32,I0 193,00 -379,02 -176,5E 41B,99 205,23 5!3,2B 34,B0 190,40 -479olb -199,33 518,99 202,59 616,15 35,30 187,20 -583,26 -215,44 62i,77 200,27 730,08 39,20 186,30 -694,B5 -230,62 732,12 198,36 B24,12 36,20 189.70 -7B8,10 -245,39 625,42 15'7,30 915,45 36,10 191,90 -B77,96 -262,54 916,37 196,65 1018,24 31,90 191,90 -~78,6! -283,75 1018,92 196,17 1100,26 29oB0 168,30 -105~,57 -298,17 110Q,73 1~5,72 1179.52 23,80 182,70 -l13E.~ -305,85 1179,68 195,03 1366,6B 11,00 195,73 -1323,56 -340,71 1366,71 194,44 1377,14 11,00 196,73 -1333o50 -3~4,06 !377,17 194,47 DLS deg/ lOOft 0,00 0,30 1,64 0,07 0,15 0,12 0,05 0,04 0,26 2,33 4,73 4,40 0,31 1,34 2.60 2,51 2,26 3,90 2,01 2,14 2,33 0,47 3,20 1,65 1,04 2,13 1,64 2, 2B 1,74 3,66 2,15 0,00 ARCO Alaska, Inc. Date: July 5, 1994 Transmittal #: 9116 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3H-26 LIS Tape and Listing: 05-23-94 HLDT 1 B- 18 LIS Tape and Listing: 06-03-94 DITE, LDTD, CNTG, GR Depth Shifted Tape Receipt Acknowledged: _r~ DISTRIBUTION: Bob Ocanas 94162 94194 Date: ~~~.. State of Alaska % ARCO Alaska, Inc. Date: May 27, 1994 Transmittal #: 9097 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3M-28 ,//[_IS Tape and Listing: 05-03-94 CDR/CDN-2 Bit Run with QRO Processing LIS Tape and Listing: 05-05-94 3H-26 / 3 Pass CNTG Receipt Acknowledged: ~~ :~~/~ DISTRIBUTION: 94046 94159, .. ' Date: , '~,~ _ ~ ' Bob Ocanas State~of~Aiaska~. ARCO Alaska, Inc. Date: May 27, 1994 Transmittal #: 9096 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. ,/3M-28 c~._. f~ (, 3M-28 ",3M-28 .A~DN '/'CDR Very-Enhanced Resistivity TDTP Acknowledged: DISTRIBUTION: D&M 1/30-2/3, 94 1/30-2/3, 94 1/30-2/3, 94 0~4 5950-13200 5950-13230 12400-13210 6100-6450 Briiling Catherine Worley(Geology) ~'~' £~ NSK ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9078 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. receipt and return one signed copy of this transmittal. Please acknowledge /3H-25 5~q-~[{¢ k/ 3H-25 . %.3H-25 /3H-31 ~-'"1~ ~,, 3H-3! '~3H-31 9~H-23 H-23 H-23 \ 3M-23. --------&3M-23 .._ /3M-26 '" ~ \ 3M-26 ....'~~H-26 /'3M-24 ~'~''tqS~''',3M-243M'24 /3M-25 ~---l'¢l (~ 3M-25 \3M-25 '/CDR '/'CDN ,,"CDR Very-Enhanced ~lesistivity v'CDR ¢'CDN ,,' CDR Very-Enhanced Resistivity v'CDR DR Very-Enhanced Resistivity ¢13DR ¢'CDN ,,dCDR Very-Enhanced Resistivity "'CDR ,'"CDN '"CDR Very-Enhanced Resistivity ¢'~NT-G ,,"CDR ,/'CDN '."CDR Very-Enhanced Resistivity DN ,/'CDR Very-Enhanced Resistivity 2E- 17 ',/CNT-G ,,. Acknowledged: 02-22-25-94 02-22-25-94 02-22-25-94 02-9-12-94 02-9-12-94 02-9-12-94 02-16-18-94 02-16-18-94 02-16-18-94 12-21-28-93 12-21-28-93 12-21-28-93 01-13-16-94 01-13-16-94 01-13-16-94 04-28-94 01-20-25-94 01-2O-25-94 01-20-25-94 01-2-5-94 01-2-5-94 01-2-5-94 4-22-94 Date: DISTRiBUTiON: 4650-12414 4650-12414 11800-12300 4950-10734 4950-10734 10100-10700 4080-9358 4080-9364 8795-9296 5350-12740 5320-12740 11750-12740 4282-9625 4750-962O 4282-9625 6O9O-6450 520O-12490 5170-12480 116O0-12480 505O-1O890 50151-1O888 10100-10820 8700-10OO0 ARCO Alaska, Inc. Date: May 06, 1994 Transmittal #: 9079 RETURN TO: ARCO Alaska, Inc. Attn: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. and return one signed copy of this~ transmittal. 3H-31 ,,,LIS Tape and Listing: 04--25-94 94066 - "' LWD CDR/CDN 1 Bit Run 3H-25 LIS Tape and Listing: - 04-27-94 94083 ¢"I..WD CDR/CDN 1 Bit Run 3.u_23 ~.!,., Tape and ., ,..,ou. ,~. 04-25-94 94075 ,'/LWD CDR/CDN 1 Bit Run 3M-23 ~LIS Tape and Listing: 04-22-94 94018 '/CDR/CDN-4 Bit Run with QRO Processing 3M-26 ,kiS Tape and Listing: 04-27-94 94023 v'CDR/CDN-4 Bit Run with QRO Processing 2E- 17 LIS Tape and Listing: 05-03-94 94102 '""2 Pass CNTG Cased Hole Edit 3M-25 ,,/~_lS Tape and Listing: 05-02-94 94027 _, Run with QRO Processina Receipt Acknowledged: _¢p, Please acknowledge receipt DISTRIBUTION: Bob Ocanas State of Alaska ARCO Alaska, Inc. Date: April 05, 1994 Transmittal #: 9051 RETURN TO: ARCO Alaska, Inc. ATTN: Sarah Bowen Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. Please acknowledge 1B-14-' Cement Bond Log CBT 3-22-94 ¢-\ 1 B-16 ,~ Cement Bond Log CBT 3-26-94 3H-26-" Cement Bond Log CBT 3-20-94 ¢.,~ 3H-23,- Cement Bond Log CBT 3-17-94 3H-31-" Cement Bond Log CBT 3-19-94 1B-14,-' Cement Evaluation Log CET 3-22-94 1B-16`/ Cement Evaluation Log CET 3-26-94 ¢,. 3H-26"" Cement Evaluation Log CET 3-20-94 3H-23'/ Cement Evaluation Log CET 3-17-94 3H-31,,,, Cement Evaluation Log CET 3-19-94 8480-9728 5 6200-7340 4200-6414 5 7650-9206 5 8700-10549 8480-9753 5800-7344 5 4200-6436 5 765O-9220 5 8700-10566 Receipt ~/~. //'~,,-z ~5 Date: Acknowledge: DISTRIBUTION: Drilling State of Alaska(+sepia) NSK ALASKA OIL AND GAG CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 February 24, 1994 A. W. McBride Area Drilling:Engineer ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3H-26 ARCO Alaska, Inc. Permit No: 94-29 Sur. LoG. 1384'FNL, 281'FWL, Sec. 12, T12N, R8E, UM Btmhole Loc. 2429'FSL, 69'FEL, Sec. 11, T12N, R8E, UM '. Dear Mr. McBride: Enclosed is t~e approved application for permit to drill the above referenced well. · The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until ~all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that.a representative of the Commission may witness the test. Notice may be'given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. J~hnston ~a~ma~ BY ORDER OF T~E CO ISSION dlf/Enclosures · CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. :~".?~, pru,t,'d r,~ ¢,,cy~.:led paper b 7 C.D. STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry [] Deepen ~ Service [] Development Gas [] Single Zone X Multiple Zone [] 2.. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 80', Pad 39' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25531, ALK 2657 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1384' FNL, 281' FWL, Sec. 12, T12N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2640' FSL, 34' FEL, Sec. 11, T12N, R8E, UM 3H-26 #U-630610 At total depth 9. Approximate spud date Amount 2429' FSL, 69' FEL, Sec. 11, T12N, RSE, UM 2/26/94 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3H-7 6672 MD 2429' ~ TD feet 7' ~ 900' MD feet 2560 6263 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 3300' feet Maximum hole angle 32.1 6° Maxirnumsurface 1 865 psig At total depth (TVD) 3460 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Weight Grade Couplinc, i Len~lth MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 3110' 41' 41' 31 51' 31 50' 370 Sx Arcticset III & 270 Sx Class G 6.75" 5.5" 17.0# L-80 LTCMOD 6129' 41' 41' 6170' 5838' 170SxClassG 6.75" 5.0" 18.0# L-80 LTC ~ 61 70' 5838' 6672' 6263' Top 500' above Kuparuk 19. To be cempteted for RedrilI, Re-entry, and Deepen Operations. ~ /~.),~,.-- ~--'/?'/-~/Z~/,T..~ ~'~(7~- ,...~--~_/_~ Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Intermediate Production Liner FE'E~ '] ~ I994 Perforation depth: measured Alaska 0ii & Gas boilS, bu~lit~S~u" true vertical Arlch0ra~e 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge //~/./~///~,,,. Title Area Drillin~l En~]ineer Date 2.//~/~,// Signed ~'~, /-'" ' ' - Commission Use Only Permit Number I APl number I Approval date I See cover letter for ,~.~"" ~.. ? 50- /~),-~" ~ O ~ <:3~~' ~, '"r.~' ~'~'~? other requirements Conditions of approval Samples required ~ Yes J~ No Mud log required [~ Yes ,~ No Hydrogen sulfide measures r~ Yes j~ No Directional survey required ~ Yes D No Required working pressure for BOPE [~] 2M ~I 3M [~] 5M r-~ 1OM r~ 15M Other: Original Signed gy by order of Approved by David W, Johnston Commissioner the commission Date '~/.'Ly~ · .. Form 10-401 Rev. 7-24-89 ~ubmi'i in triDlicate o . . . . . . . 10 11 12 13 14 15 16. 17. GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3H-26 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3151')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (6672') according to directional plan. Run and cement 5-1/2" × 5" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve & NU tree assembly. Move in and rig up Nordic #1. Install and test BOPE. Test casing to 3500 psi. Perforate and run completion assembly. Test tubing x casing annulus. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. ,CEB i8 1994. Alaska Oil & Gas uons. ~,u,,m~s',¢~, A nchora,18 20O0 I I v 0.50 1.50 BEGIN NORTHWEST NUDGE TVO--700 TMD=700 DEP=O BUILD .5 C~G / ~00' 't 'ARCO ALASKA, Inc. Structure : Pad 3H Well : 26 Field : Kuparuk River Unit Location : North Slope, Alaska END INITIAL BUILD TVD=llOO TMD=llOO DEP=O B/ PERMAFROST TVD=1630 TMD=1630 DEP=O jCreated by jones For: G ,~,¥ORD jDote plotted : 3-Feb-g4 'Plot Reference is 26 Version #3, Coord nates ore in feet reference slot #26. jTrue Vedical Depths ore reference wellhead.! i i ! Baker Hughes INT£Q i , T/ UGNU SNDS 'PZD=1900 TMD=1901 DEP=4 T/ W SAK SNDS TVD=2480 TMD=2481 DEP=-4 B/ W SAK SNDS TVD=3010 TMD=3011 OEP=-1 5O0 400 30O I I I I I ~ ESTIMATED SURFACE LOCATION: 1384.' F'NL, 281' F'WL SEC. 12, T12N, RBE CASING PT TVD=3150 TMD=3151 DEP=~ K-la TVD-3285 TMD=5286 DEP-~ 2.12KOP TVD=3300 TMD=3301 DEP,--1 7.06 12,92 3 DEC / 100' DOGLEG 18.87 24.85 30.83 EOC Tv~=4325 TMD=4582 DEP=293 K-5 TVD=4680 TMD=4802 DEP=516 S 14.08 DEG W 1295' (TO TARGET) · ,**PtA,NE OF TARGET LOCABON: I 2640' FSL 54' FEL SEC. I1. T12N. RSE TARGET WD=5923 TMD=6270 DEP=1295 SOUTH 1256 WEST 315 AVERAGE ANGLE 32.16 DEG i i i i i i i i i i i i i i i i i i i 200 0 200 400 ¢~00 800 1000 1200 1400 Scate 1 : 100.00 Verllcal Section on t94.0~ ozlmuth with reference 0.00 N, O.OO [ from slot jl26 200 Wesf .... lOO o lOO i i i i i i II 1(3o o 2oo 5oo _ _600 Z 70o _800 _ _ _ f 200 ~4.oo 1§aa TD LOCATION: 2429' FSL. 69' FEL SEC. 11. T12N. RSE I I V __.TARGET - T/ ZONE C TVD=5923 TMD=6270 DEP=I295 T/ ZONE A WD=5990TMD=6349 DEP=I357 KUP SNDS WD=609¢ TMD=6472 DEP=1402 ¢~ TI) C$C Pt TV~=Oeea ?MD=6672 DEP=IS08 RECEIVED Alaska Oit & Gas G0ns. Anchorago 14.0 12o I I ARCO 1 O0 80 I I I I I ALASKA, Inc. Structure : Pad 5H Well: 26 Fl~ld: Kuporuk Rtwr Unl~ Loeoflon : North ~lol~, Alike 3400 ,3500 5700 3800 5900 4000 Wesf Scale 1 ' 20.00 6O 4O 2O 0 2O 4O 1400 8O _ 60 _ 40 _ 20 _ 0 _ 20 _ 40 _ 60 _ 80 _100 _120 RECEiVE, b Alaska Oil & 6as ~ons. Anchorage DRILLING FLUID PROGRAM Well 3H-26 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 7-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 ___10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drillinc~ Fluid System' T~ndem B~andt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.7 10-18 8-12 35-50 2-4 4-8 4-5 thru Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1865 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3H-26 is 3H-07. As designed, the minimum distance between the two wells would be 7' @ 900' MD. The wells would diverge'from that point. Incidental fluids developed from ddlling operations will 'be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by arctic pack upon completion of fluid pumping. *Spud mud should be adjusted to a FV between 50-80-sec/qt to drill gravel beds. Alaska 0il & Gas Cons. Anchorage, Casing Design/Cement Calculations 18-Feb-94 Well Number: Surface Csg MD: ~Surface Csg TVD: ~Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Target, TMD: Top of Target, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 3H-26 3,151 ft 3,150 ft 6,672 ft 6,263 ft 2,481 ft 6,270 ft 5,923 ft 3460 psi ** See Page 4 For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe 3,150 ft 1,865 psiJ Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 3,460 psi 5,923 ft 150 psi 11.7 ppgJ Design lead bottom 500 ft above the Top of West Sak = 1,981 ft Annular area = 0.2148 cf/If Lead length * Annulus area = 426 cf Excess factor = 70% Cement volume required = 723 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 370 sxJ Surface tail: TMD shoe = 3,151 ft (surface TD - 500' above West Sak) * (Annulus area) = 251 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.2578 cf/If Cmt required in casing = 21 cf Total cmt = 272 cf Excess factor = 15% Cement volume required = 313 cf Yield for Class G cmt = 1.15 Cement volume required =[ 270 sxJ R C E i¥ r' '~ . ~:~ Alaska 0il & ~s uons. Anchorage Casing Design / Cement Calculations Production tail' 18-Feb-94 TMD = 6,672 ft Top of Target, TMD'= 6,270 ft TOC 500' above top of Kuparuk = 5,770 ft 5" casing x 6-3/4" annulus = 0.1121 cf/If 5" annular volume = 56 cf 5-1/2" casing x 6-3/4" annulus = 0.0835 cf/if 5-1/2" annular volume to 500' above top Kuparuk) = 33 cf Length of cmt in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 98 cf Excess factor = 100% Cement volume required = 195 cf Yield for Class G cmt = 1.15 Cement volume required =1 170 sxJ TENSION - Minimum Design Factors are' T(pbi=l.5 and T(js)=l..8 Surface (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 683000 lb 3,151 ft 29.70 Ib/ft 93584.7 lb 16385.8 lb 77198.9 lb 8.8J Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 566000 lb 3,151 ft 29.70 Ib/ft 93584.7 lb 16385.8 lb 77198.9 lb 7.31 Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 397000 lb 6,672 ft 17.00 Ib/ft 113424.0 lb 20158.1 lb 93265.9 lb Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WEft) Buoyancy = Weight of displaced, .m...u~. Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 Alaska 0ii & Gas Cons. Anchorage 33800O lb 6,672 ft 17.00 Ib/ft 113424.0 lb 20158.1 lb 93265.9 lb 3.61 Casing Design/Cement Calculations 18-Feb-94 BURST- Minimum Design FactQr = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ 6890 psi 1864.8 psi 3.7J 5-1/2" Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres(3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ 7740 psi 7317 psi 2899 psi 4419 psi 1 .Si COLLAPSE - Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =! 4790 psi O.6O9 Ib/ft 984 psi 4.9J 5-1/2" Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 6290 psi 0.609 Ib/ft 3817 psi 1.6J Calculations are based upon 5-1/2" casing as it has lower burst & collapse than the 5". Alaska Oil & Gas boris. Anchora{.ie Casing Design / Cement Calculations 18-Feb-94 Surface Casing Choices OD ID lb/ft Grade Metal X-Section I 7.625 6.875 29.7 L-80 8.5412 sq. in. Jt Strength Body Strength Collapse 566000 lb 683000 lb 4790 psi Burst 6890 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section 1 5.500 4.892 17 L-80 4.9624 sq. in. I 5.000 4.276 18 L-80 5.2746 sq. in. Jt Strength Body Strength Collapse Burst 338000 lb 397000 lb 6290 psi 7740 psi 376000 lb 422000 lb 10490 psi 10140 psi REC 'fV Anch0rag~ ~UPARUK-'RIVER UN' '~-~¥' ' . .. _ . 20" DIVERTER SCHEMATIC 5 6 4 5 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION , UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WEII RORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. . Alaska 0ii & Gas Cons, ~J'u~,~;~'~s~ Anchorage 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 20" - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 13 5/8' 5000 ; SI BOP STACK ACCUMULATOR CAPACITY TE~T , - 1. CHECK AND FILL ACCUMULATOR RESERVO~ TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE tS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. & OBSERVE TIME, THEN CLOSE ALL UNITS SII~JLTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS N:iE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES (~ KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AI~ CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTC&I PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTjlIND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PtUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 1P_ TEST KELLY COCKS AND INSIDE BOP TO 3a30 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOP~ 14. PERFORM COMPLETE BOPE TEST ONCE AWEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11 ' - 3000 PSI CASING HEAD 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5(X)0 PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES E 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR R EC E iV Alaska Oil & Gas Cons. Anchora~o WELL pERMIT CHECKLIST ADMI~'ISni'I~.ATioN ...... DATE 1. Permit fee attached ................... . N 2. Lease number appropriate ............... '6 N 3. Unique well name and number .............. ,c__~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary...~ N 6. Well located proper distance from other wells ..... ~_~ N 7 Sufficient acreage available in drilling unit ..... ~ N 8. If deviated, is wellbore plat included ........ .~ N 9 Operator only affected party .............. .~ N 10 Operator has appropriate bond in force ......... N 11 Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... .~Y~ N , ,, WELL NAM~ GEOL AREA . _PROGRAM: exp ~ dev [] redrll [] serv [] UNI~# /?/~ ON/OFF ssoRE o~j REMARKS 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ .~ N 16. CMT vol adequate to circulate on conductor & surf csg. N 17. CMT vol adequate to tie-in surf csg to next string .... Y 18. CMT will cover all known productive horizons .... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ '9 N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N--~/~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~d~ psig~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... Y N 28. Work will occur without operation shutdown.. 29. Is presence of H2S gas probable ............. Y GEOLOGY APPR ~ATE ; 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/. 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones .......... 33. Seabed condition survey (if off-shore) ......... I N 34. Contact name/phone for weekly progress reports .... / Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW~o - A:~FORMS~cheklist rev 01/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. b!ELL i~aF J 3~-26 FI~i~D ~A~E ~ KUPARUK ~OROUGN ~ ~ORTH $~OPE ~PI NU~BE~{ : 50-I03-20208 I[$ ~'a~e verIficat.~.on Listinq chluF',berg~r AlasKa Compt.lt.~.r~(: Center 3f; - 26 501032O208 ~RCO Ar,ASKS, I. SCHL!.Ib'iBEPGRR i~:Eb!, SEPVICF,$ J 3-N,~Y-94 JC PY F;O~ I 384 ' , O0 39~ , OPE~: HOLE Ca$Iag DRIbLEaS CASING SIT SIZE (I~) SIZE (1~) D~PTH (FT) WEIGHT (LB!FT) 7.625 3143,0 29.70 5,5G0 6117.0 ~7,00 6,750 5,000 6640,0 18,00 ,IS ~a~e veri. ficatJon !~istino ;chlumber(,:'ier ~o~,lasaa Computing,: Center 23-!~IAY-] 994 10:]9 PAGE: ;!'NE LiFPTH CORPECTIO~':$ SWOW.~'i AB~VE REFLECT PASS ONE GRCH OF TI~E ~LDT S}iIF~ED Ti,) TNE CET/GR DATED 20-~.A~-n4. ~nt, ~T~ER NLDT CUgVES ~ERE SHIFTED TNE V FRS I{.~}~i : OU!C'Ol DATer = 9~!0:5/~3 ~X {~?C SIZE : 1024 FILF TYPF3 : shifted end cl. ip~ed curves ~or each Pass in separate files, K R: ,,, ~IS Taoe Verification bistJno ;chlu!~berqer A,!as<a Compt',,t. lr:~a center 10:19 PAGE: 6 .a 0 2,0 ~4.~'4 b397,~ 6393, $ 6392 . 5 63E;~ ~ 6360.5 6353,5 634e ~ b345,5 6344,5 6341 ,5 6340.5 633~, 5 ~336'5 6333,5 633 ~. 5 6325.5' 6324, ~ 63i6.5 63!3.5 f~403.5 ~397.5 636g.~ 6367.0 635g.0 63~.9,5 634~. 0 6342.0 6334,0 6329,5 6326,0 631~,0 6309,5 6997,5 6293,5 6285,~ 6392,5 6389.0 6385,0 .~3~0.5 6344.5 ~341,0 ~336.5 0333.0 6329.0 6324.5 6316,5 6313.0 629:7,0 6292,5 62a~.5 U N 6H I FT~D UEPTH .......... ;ch!umberger A. lasKa Com~)uti~ Center 23-~AY-1994 10119 PAGE: 5~56.5 ~56. o 525~.5 6~53.0 ~24~.5 6~4R.0 0~4~. 5 6243.5 .. --¥ ky I - 5232 5 ~232 5 6225.5 6~26.0 b'2!7.5 L~17.5 b~',il;5.5 ~05.5 {~20~ .5 6204.5 6700.5 520~.. 0 6! 77.5 {~ 76'5 61.76,5 ~173.K 6J7,:.5 6! 69.5 6~.6q.5 e! 57,~ ~,~157.5 0156,5 6!53.5 61,54.5 !40 5 6~z~O 5 !.j7'" " . ,5 6J, 37.0 ~';~ 36,5 E~136.5 6,!,29.5 6~29.5 t~,! 2~,5 6129.0 6125.5 6!26.0 6!2!,.5 6i22.0 ! O0.O !00.0 ~.00,5 [chlumberg~r ~:%]asKa Compute, ha Center 10:!9' PA~E: AC-JU;~T~'rS S~,.~'~?,~ A~UVE R~'iE~T P~5S ~2 3HZFTED TO P~SS ** ~A'I'A FoRe'AT SPECIFTC~.T!Of'i ~(;Ct]N!.~ ** 1 6~ 0 3 73 3~ 4 66 1 6 73 7 65 ~ 68 0,5 i5 66 6~ i6 66 1 0 66 0 ** SET ~t'~'*"' - C" ?' ODE "[0 ORDE~ ~ bOG TY?E CL~SS ~{JD ~[J~B SA~P ~LE.M C' '~ ..... ............. ...---.--;; ..... .--.; .................. . .... --------,,----,,,,,,,,--- ~)~;pT ~'T 000 0 0 I 1 1 4 O0 , ... . . O0 000 O0 ,9 I 1 i 4 68 0000000000 R~!OB [!59N G/C3 DPHn ,StT~ G/C3 O0 000 O0 0 1 ! I 4 68 0000000000 LSR~'~ ~'{SDg! G/C3 OO 000 O0 0 1 1 I 4 68 0000000000 Sg~t~ !'~$P~ (;7C3 O0 OOO 00 0 i ~ ! 4 68 000000OOO0 CCL ~$n~ v oO o00 O0 0 1 1 1 4, 68 0000000000 C~LT qSDN i~ OO 900 O0 0 1 I I 4 68 0000000000 ~;'~$ ~sn{,~ ~ oo ooo O0 0 ! t t ,4 6~ 0000000000 GPC~ ~8~H G~PI O0 000 O0 0 I ! I 4 68 OOO0000000 ~iS Ta~e veri, fi. cation Llsti, nq ;ChlUm'berqer AlasKa Comp~tfhg Center' ...1.0:19 ?. 42.6 0,0 0 3 -999.250 0.~o6 -0 332 LSI~H. HSDN -999,250 l.,S~ H . H.SDN 4: , 5 b_':t TEp~S.HSDN 2.758 2490.000 -999.250 2390.000 ~ L I C O01CO1 o ,.% t o !024 !., F Ir l.~ E: HEADER Curves and log header data ior each pass in separate DEPTH ! ~'{C.~E~,~ENT: 0,5000 I,rEN[)OR T~,(JL COO~.; ST~B:T DEPT~ S%OP DEPT.H i,~G iiF, AD~3P DATA DATE: L, OGF;ED: S[]FTWARE VERSION: · [) i.'~RIL[.,ER (FT): flles~ raw bacKoround pass in last fi OS-APR-g4 38.2 ~01.5 05-APR-94 6553.0 ,I$, Tar,,e verification. ....... L1sti. nc~ ;Chlu~berg~r AlasKa ComputInh Center 23-~AY-1994 10:19 PAGE: 7 oOPEHULE A~'-~U C~6I~4G DATA (~F'E~ HbLE ~3IT ST~K I.,OGGE~S ~gSiuG L)~PTN ~URFACE T~:FPERAT~PE (DE~F): FLUID 8ALIb~I'i'Y (PPa): ~,ATER CUTS it>CT): (;~StOTb Ra'.fIO: B~,UELIh}F'. CC."~!~aT RA'.Pk~ i'~UR~A!,,~tZATION iN OIL TOP N[,}~'4./LTZINg ~,?I~;~DO;~ (FT)I Bti..,UELIaE CCib~,~T RATE SCAbieS SFT BY FIELD E~'~GINEER ~AP C[)[Y~'~ RATE LOW SCALE (CPS): WA~ COU?,~T RATE HIG}{ SCa. L~7 (CPS): ?~{E~R CCbUT RATE LOW RCALE (CPSJ: ~-}'E~R COOt~T gATE UIGH SC/4LE (CPS)~ F~?~.R~'.'5: TIED l~'.~TO CET DATEL> 3120/94 610oo0 6438 , 0 90O. 0 1,{} O i, NUMBER CA - A-3O TCC-.B-42 ~ SGC-SA-59B 3!43,0 BR!~'~E tl.70 i7C.O SANDSTONE 2.65 Tape Verificati, on Listi, nq ;chlumberqer AlasKa Computino Center 23-NAY-!994 10:19 LSRH Hbl G/C3 PEFL tLL! PFFS UL ! PEF HL 1 bS~ HL!. CD8 LS~2 HL) CPS bS~,~ 3 "hl. CPS LSat'4 HL! CPS L8¢~5 Hbl CD8 58 ~;.? 3 HL! CPS 88¢~4 Hb! CPS 88W5 HR! CPS CS EL1 Ftbr~ TF~ S HLt C~bT Hbt. i~,~ AN ** r'~p ....... API :':'''P t..,OG TYPE CLASS O0 000 O0 O0 000 O0 00 000 00 O0 000 O0 00 ~') O 0 00 0 0 0 0 0 0 0 00 000 00 o 0 0 O n 00 OO 000 O0 00 000 00 O0 000 O0 0 0 0 00 O 0 O0 OOO gO O0 000 O0 O0 000 O0 O0 OOO O0 00 000 00 0O OOO O0 O0 000 on OO eGO O0 O0 000 O0 FILE . ~B NUMB IZE REPR P OCES$ NUmB SA~V~P ELEM CODE (HEX) 2 I. I 4 68 0000000000 2 1- ! 4 68 0000000000 2 I ! 4 68 0000000000 2 1 I 4 6~ 0000000000 2 1 I. 4 68 0000000000 2 ! 1 4 68 0000000000 2 1 I 4 68 0000000000 2 1 i. 4 68 0000000000 2 t 1 4 68 0000000000 2 ! 1. 4 6e 0000000000 2 1 1 4 68 0000000000 2 I ! 4 68 0000000000 2 ! 1. 4 68 0000000000 2 ~ I 4 68 0000000000 2 t 1 4 68 0000000000 2 1 t 4 68 0000000000 2 I i 4 68 0000000000 2 ! ! 4 68 0000000000 2 ! ! 4 68 0000000000 2 I I 4 68 0000000000 2 1 1 4 68 0000000000 ,IS Taoe verification L, istJn~ ;chlt)mberger AlasKa ComputinO Center 23-~AY-,'t, 904 !0:t9 PAGE: p~F~ ~L1 o5 0nO P~F.!-~t,1 27 500 bSW1.HL! 89.0~3 LS~ 3. ~t ~. 46~.500 LSw ~I,. HI, 1 318.750 LSWS.HL! ]64.~50 SS~I.HL1 SS~2,HL! !.~O,OOU SS~;~{. HI~i 4!4~,000 SS~.HLI 2048,000 SS~5,HLI R'~F~'~ UL1 2.264 DR;4{] '-~Yi -0 525 CS.HLi 1069 000 ., ....... , .... . . C~LT.?~LI 3.713 fir. {"~L, 1 B0.3i3 CCb,HL1 0'003 DP~ .6i~}l,00u [,SRH. ?,r,1 2.600 $SR.H, :-iL 1 3.172 PEFL P~F-., ]FL! ~2.875 PEF. H[,I 25.875 LS~I.HI, I 14~.500 LS~-,.3.UL1 777.500 [,SW4.HLI 556 500 [,[;W5,MLI 479.750 SS~v! .gbl SSK~?.~-~Lt ~"62, ~ .O~b, SSW3.!.~LI, 57~4:0na, ~ .... SSW4.HLI 2420.000 SS~5. ~uOP.HL1 2.201 DRNO.~b! -0.~00 CS.H51 1036.000 CALl' .9L! ~.5a3 G~{. i'i[, 1 ~1.750 CC~. i!b 1 0.085 27.500 167 125 544!500 259 25O 1~20 000 25.875 374.500 659,500 271.750 2405,000 **** F !..L ~ Ti~AiLED **** FILE ~4A~4g : ?UII' .002 S~':RV IC~. : wLIC V ~as I 0:::~ : 00!.C01 DATE : 04105123 F!L~' T'YDPj : LO L~:ST FIbE **** FILE FI'bE ~'~A~'~E : FOIT .003 SERVICg ~ ERS IO!~:~ : 09iC01 oaTF : FILE TYPE : LO k, bST F I. [,, E~ 23-~<AY-i 99~f 1.0:!9 AGE ,: 10 STOP OEPTH 09~.0 TOglL, STPiUG (TO[' TO ~i [,, D'r 3oEt~ HOT.,E~ BIT SIZ~ g G ~" ~] }'i 0 !~ E CONDiT LObeS ~"I.~ U I D TYPg= . Y. ( b ~O'FTO~4 HUbE I','E~aPERATUPE FLUID S~LINITY f'PP~4) FLUID LEVEL (FT) Fbijl[) RATE ~,T ~,'~TER CUTS fPCT) GaS!O!L~ CHOKE (DE;G)~ Tab[, TYPE (EE'IT[.iERN~b !.iDLE CO~RFC?I~N 05-APR-94 38.2 10!5 05-APR-94 6553.0 b442.0 6!O0.a 6438,0 900.0 NO TOOL NUMBER CAL-YA-30 TCC-B-42! SGC-SA-598 HLDS-B~-20 3!43oO BRINE ! 1..70 170,0 NEITHER SANDSTONE 9.65 ~OP NO~IZI~ WINDOw (~T): IS Taoe i~erificatI, on [,istinc~ chlumberger AlasKa Comptlting Center 23-~4AY-1994 10:!,9 ii E;C g [.~ (CPS): 0 SCALE (CPS): 0 $ ** r'A~'A FOR~hT SPECIF!CATTO~,7 RECORD ** ** $E7 'r'kPE - CHAN ** . . . h h ~.E SM, LiNI? ICE ~Pi API A FIbE N~ 'NUMB SIZ REPR PRO SS Ti:, r~i~l:>i.,,:q~ ~ i,~OG TYPE ,,,h, ' [)D 'NUi~B SA~P EbEM CODE (ilEX) ...... .. -;;---..- ........ ..........;.... ..... D6;PT 00 . O O0 0 3 ]. 4 8 0000 000 SSR~ ~,~b2 G/C3 00 000 00 0 3 I ~. 4 68 0000000000 FEF[., ~¢ t.,, 2 O0 OOO O0 0 3 ! I 4 68 0000000000 PFFS ~L2 00 00n 00 ~ 3 1 I 4 68 0000O00000 P~F ~-~ 00 000 00 0 3 I i, 4 68 0000000000 Tame Verl~:l. cation [.,istincl chlumberoer Al. asKs Co,~.puti.nq Center 1,0119 PAGEI 12 IL, S. 1. H~.,2 CPS S~' . L~ ~, ~ ub2 SS ~,,. 1 ~b2 C~,5 SS~ 2 ~L2 C , SS ~ 5 rtL, 2 CD~ Ji~H~ ~b2 G/C3 'I F ~-~S ub~ 6P ~L2 G~PT TYPE CbASS ~4~;"]f:~ ~,~[,J~8 .SAHP E[,E?~ CODE mmmmmmm~mmmmmm.mmmmmmm~mmmmmmmmmmmmmmm , * )) A '£ A * * [,2 2.754 SSRh. HB2 3.49 1.,2 29.672 LSW1.Hb2 62.62 L2 341.250 r, sws,al, 2 305 75 t, 2 4352.000 SSW4,H52 2072.00 1,2 -0.519 C8.HL2 984.50 1,2 67.188 CCb. HIJ2 -0.04 !:.,2 2,648 SSRH.HL2 3 223 L2 23.938 bSW1.HL, 2 140::37 1,2 486.250 bSWS,tdh2 422~ O0 L, 2 5512.000 SSWt. Hb2 2360.09 [,2 ~-0..408 CS.I{L2 1075;00 52 79.375 CCL,Hh2 0.00 0 PEFL.Hb2 5 ESW2.Hb2 0 8SWl,H[~2 0 S8~5 gL2 rE,.~S: 1 2 PEFL.Hb2 LSW2.HD2 SSWI.HE2 0 SSW5 HE2 0 0 29.672 192.625 585,000 250.500 1390.000 23.938 363,000 651.000 267,750 2365,000 IS *a~e verlfication l'~istin, c~ chiumberqer AlasKa comF, utinq Center 10:19 Cdrves a,.n~i lo(:! r:eoder data for each mass in separate I-~ I< P T 6 4 4 q.. ,. bOG HEAD'Ere DATA STOP' DEPTH b099. O ~ATE bOG(~ED: TD I)~ILLfR "~D LOGGgRiVT): TOP l,OC Tt~E~VAb LOGGIi.ct7 SPEE;I'~ (FP~[~): vE~'-~f)OR ~'OOL CODE Ti. Il]l, TYPE ....................... HLD'r T EI.~4ETR'f CARTRIDGE; OPEN files; raw bacKoround pass in last 05'APR-94 38.2 !01.5 6553.0 6442.0 6J. 00.O 900,0 05-APR-94 o TCC-B-421 SGC-SA-598 HLDS-BA-20 3143.0 BRIiIE 1t..70 170,0 IS Tone verification t,l. stinq chlumberqer A'J. asKa Compt,:~t:f.r..q Center 23-NA¥-!994 i0;1.9 14 2,65 R~!,~af{t(S'. TI'E?') t{,.iTO C<T i)ATFD 3/20/94 ~v,~t,t]l~i 3 PA. SSES Am 900 FPP, $ LIS [:('iR:AT r)ATA SET TYPE - 64gB ** 1. 66 . 3 73 92 4 60 5 66 6 73 7 65 ~ 6g 0 5 1I, 60 il 12 68 i, 3 6~ 0 !4 65 ET i~ 66 68 ,IS 'fane Verification Listih~ ;chl, U~,herger Alas<a Com~ut!,nO Center 23-~AY-I994 10:19 PAGE: 15 1,6 66 1. · 0 ~ ~ 1 ~,,~ SR T SERV~CR . ~P~ APl m P 0 ii L) P P T F m 00 bSkM ~ [,~ ] G/C3 O0 0o0 UO C' 5SRu Hb3 GIC3 O0 oOO O0 0 PKF[, ~tL3 O0 OOO OO FFF qb3 (]0 000 OO 0 LSd1 :41., 3 CPS O0 000 O0 bS~? ~b3 CPS O0 000 O0 O bS~;3 PI.,] CP~ O0 000 O0 0 bS~ ~. ~b3 CPS t)O 000 O0 0 bS~'5 ~g3 CPS O0 coo oo o SS~I ~b3 CPS oO 000 O0 SS~ ~3 CPS O0 00(~ uO O Sgw3 Hg3 CPS oo gOO OO 0 S~W~ ~'~L3 CPS On o0o OO 0 88~5 ~L3 C~S O0 000 O0 0 .. ,. ~ . C 8 ~'~ b 3 F ! ~t ~ O 0 0 00 O 0 0 T~NS Ub3 bg O0 OOO O0 0 g~ Nb3 GAPI O0 000 O0 0 CCh ~3 V O0 OgO O0 0 ILE bi P, NOM~: SI REPR PRO Im4mmm~mmm,mmm~mmmmm'~mmmmmmm~mmmmmmmm~mmmm~mmmmmmm~mm 4 1 1 4 68 00000 4 ! I 4 68 O00OO 4 ~ 1 4 68 00000 g ! 1 4 68 O00uO 4 I 1 4 68 00000 4 ! 1 4 68 00000 4 ! 1 4 68 00000 4 1 t, 4 68 00000 4 1 1 4 68 00000 4 ! 1 4 68 OOO00 4 ~ 1 4 68 00000 4 1 i 4 68 00000 mmmmmm 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000- 0000000000 0000000000 go00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 m#mmmmmmmmmmmmmm , r- ? v,. . .....~3.~L3 509 250 ~"." ~-iL3 386 ~"0~ ~h3 2.2!9 DR~O.I:~!,3 -0 R , ~.~ . . , C~LI'. b3 3 742 g~:,~.b.I..3 75 .756 $SRA.H'[,3 3 520 234 LSW'!,Hb3 97:063 ,250 [,,$~!5.HL3 347.500 ,537 C5,tib3 1034o000 .563 CCL,HL3 0,157 PEFL.HL3 LSW2.HL3 88~1.NL3 TENS.Nh3 PEFL. HL3 * SW2 HL3 SSNI.HL3 SS'N 5. 2 4 I' 2 3 4 157,125 503'500 240; ! 25 1.415.000 30,500 332.750 632'500 25 !. 750 2440,000 I8 Tace Verificot.ion Listinq chlnmberger AlasKa Computing Center 23-b~.AY-1994 !0:!;9 1,6 **** RFE[, T~' AI !.,E~ **** D~TF : 04/05/23 OPlGI~! : ~b!C REE;T~ ~,~ A ~ E CQNTIN[!~TIO~4 ~ : PREVIOUS REEL CO~*~E~'~T : ~tiC~ ALASKA, i~,~C,, KUPARUK ~IVER, 3H'26, 50-103-~0208 O0 Z~ZMZZZZZ ,ZZZZZZZZZ ,tt~I~t!.11, tt1~!~,I!111'~,1~, Dig],tal Eqt](,pment Corporation - VAX/VN~S Version V5 5 2 11'!ii!1,!.I !.:1:~:.:[~I~i~ !,!,!~.!.:!..!~t1,~:~.'1.~!.~1!-i.~.1~1~1~111I 1111. I1.11,11111!I~1'1.1!!!1~1~1!!..,.1 (!OMPA'~,. NA~ : ARCO ALASKA, INC. WElL NA,~, : 3H - 26 FIELD NANE : KUPARUK RIVE~ BO~(JUGH : N[]~TR SLOPE STATE : aL,~S~A API ~U~bE}~ : 50-I03-2020~-00 REFE~E~Cw ~0 : 94159 RECEIVED MAY b 1 1994, 0/1 & ~as Cons. Com~j[8~ Anchorage IS Tane Verlficat.l, on r!lstinn cblumberq~r AlasKa ComPuti.n,.~ CeDter g-~AY-tgg4 09:09 DSTW : q4tgS/ 5 OP!~I~! : FbTC Cm~E~;T : AI~CO &I, ASKA Ii~C, 3H -26 ,50-~03-2020~ **** T~PE !4EADKR DnTF : ~4/05/ 5 OPIglN : FDIC TSP? NA~E : 94~50 CONTI~tJ~TIOM # : 1 C~uE~!T : A~CO ALASKA linC, 3N -26 ,50-~03-~0208 K!~P~R[,'K RIVER LOG~I~,~G COHPA~,~Y: T~P~ C~ATION D~TN; LOGG,I~JG ~MG!NEE~; ODE~ A'~L3R WITNESS: SY~RFACE FSb ~ ELF, VATIrltqCFT FROM ~¢~SL 0) KEbLY RUS?{!NC: W?L[,~ Cf~,SI~l(',; RECORD !ST STRI~'G 3R~ ST~I[~G 3H - 26 50~ 03202080(3 ARCO AbASK~, SCHI~UMBEI~GER ~ELL SERV ..... CES 94159 JACK RATMERT m[.3~ ~NGLEN 1384 80,00 ~0'00 39, Oo []PEN HOLE CASIN~ DRILLERS CASING BIT SiZE (I5~) SIZE (I~) DEPTH (PT) WEIGNT (LB/FT) ............ ' ';~''''''625 ''''''''''3143.0 'i~;''2 .... ''' 5,500 61,17,0 J, ,00 ~.750 5,000 6640.0 18'00 # CURVE SglFT D,~T~', - ~LL PASS~S TO ST~ND;~PD(~iEASURED DEPTH) IS Tame Verlfica~ion Listln~ Chlt]mberqer AlasKa Computtn~ Center ~AS.bT. LI~'~E C~:'.RV,~ FOR 5,LtlFTS g-~AY-'190,4 09:n9 1 20-~AR-94 SC~LH~4BERGER ~ELL SERVICES .......... EOUiVAI,ENI UNShiFTED DEPTH .......... BAS~iLI~E DEPTH G~CH 6256.5 6356.0 6355.5 6334.0 6335.0 632~,5 b329.0 6321.a 632!.5 6321,5 6321.5 6309'0 6308.5 3c36, o 6306.K .277.6 6~46,5 0246°0 6~23,0 6~24.C) 6191,5 6!90,0 619t 6~67o0 6!62.0 6147,~ 6146,0 6144.,~0 6110 5 $ DEPTH ADJUSTp,4ENT$ ,q.H©wl, ABOVE REFLECT CASED HObE PAGE: **** FILE }{E~gER **** FILM ~A~E : EDIT ,OOl 8TRV!C~ t FL!C VFRSI~N : O0~CO! DATE : 94105/ 5 ~lX R~C S!Z~ : 1024 L a S T F I L E : FTL~ ~U~B~R: I. memth shiite~ and ciiomed curves ~or each mass wane Veriifcati. o. !..,istina chlumherc;er AlasKa Computino Center ,q. '-~AY-!, 994 DFPmH ! .~\! C P E,"~ E,N T: 0.5000 FTL,? WDTP 6440. STOP D~PTH 6~.00.0 CI)RVE SWlrT DATA PASS Tr) PASS(dEASUREh DE 'IH) nASEL!NE CURVE P~SS HU~B~R~ PE~A. RKS: TII.{S FiLE C~NTATNS THE FIR5~ PASS OF THE TDTP, NO PASS Tf' ~-~ASS SNiP'rS WERE APPLIED TO THIS DATA. I~TS F'ORN~AT DATA PAGE: **. I?ATA FOR~',~AT SPECIFICATION IS TaD, Verificati. on l~istino cblumberqer Al. ask'a ComDut.~nc~ ('e~ter R-~AY-1904 00:09 PAGE: ERV L!,. T ,KEPVTCK ~ i PI hPI A O0 O0 O0 O0 OO O0 O0 O0 SDSI "'!)TP Cl.! a~0094 O0 OOn O0 BaC~ TD~P CPS 480694 O0 000 O0 E'~AC ~'DTP CPS o:8o694 On 000 O0 TCAW mi)TP n80604 O0 OOn O0 TCi~D T[)TP CPS 480e~4 O0 000 O0 TCF'D m [)'~p CPS 4,80694 O0 000 00 TSCM TDTP CPS 480694 UO Ot)O OO TRCr *DTP CPS 480694 00 000 O0 I~N~ TDTP CPS 480694 O0 000 O0 INF~ ?PWP CPS 480604 00 00O 00 G~CW TDTP GAPI 480~94 O0 000 O0 TKN~ ~[)~P LB 480694 O0 OOO O0 GP ~},t GAPI ~80694 00 000 00 FiI,E [: ~ NtJEB REPR PR CESS I . 000 ~ 000 0 1 ! J 4 68 0O00000000 0 1 ~ ~ 4 68 ooo0000000 0 I ~ ~ 4 68 0 1 1 1 4 68 0000000000 0 1 1 I 4 6~ 0 i ! ! 4 68 0000000000 0 1 1 I 4 68 n000000000 0 i 1 ! 4 68 oO00nO00OO 0 1 ! 1 4 68 PO00000000 0 ! I 1 4 68 0000000000 0 1 1 1 4 68 OOOO000000 0 1 1 1 4 68 0000000000 0 1 t 1 4 68 ~000000000 0 ! 1 1 a 68 OOO0000000 0 1 I ! 4 68 0000000000 0 I 1 I 4 68 GO00000000 0 1 ~ !. 4 68 0000o0noo0 0 i ! ! 4 68 0000000000 0 1, 1 1. 4 68 0000000000 0 I 1 !. 4 68 0000000000 0 1, 1 1 4, 68 0000000000 mmmmmmmmm#~mm~mmmmmmmmm#m.mmmmmmm.mmmmmmmmmm DEPm. 6446.500 SIGS.TDTP SBB~!.,r[)TP -999. 250 8IGC. TDTP 8DSl TDTP -999' 250 RACK ,.rr>Tp '"C ' ~" ~'- -999 TSCF. q'l.)~P -999,250 I?~rD.TDTP TENS,T[)~P -999.25G GR.O~ D~PT. 6400,000 SiC~4.TDTP S~}iN,TDTP 57.45U SIGC.TDTP SDST,TDTP 0.499 BACK.TDTP TCA~.TDTP 1~869,0~9 TCN[).TDTP TSCW,TD~P 558'690 INND.TDTP TFNS.TDWP !585,()00 GR,O~ D ~ P ? 62 n 0. (~ o 0 S I G i'.l. T P T P S g H ~.! T [:,'T p 62,977 S I G ~. i ',. P ~ T~ ~ ,., . . TCAV.TDTP ~684 063 ' CND T~TP ,rSCF.T[)~P 238 634 It:ND ~rr, q'p -999.~50 -999 o99'250 63,719 31,484 0.693 52,303 14!~9.160 152t.2.69 o3,719 43.675 0. l OO. 020 11605.06~ 1649.156 67.438 TPHI.TDTP $IBI'I.TDT¢ FBAC,TDTP TCFD,TDT¢ !NFD.TDTP TPH!.TDTP SIBa.TDTD FB~C,TDTP TCFD,TDTP IMFD,TDTP TP}~I.TDTP 8IBH.TDTP FBAC.TDTP TCFi2,TDTP INFO,TDTP -999.~50 -099.250 -999.250 -999.250 -999.~50 54.004 93.t06 13.984 347i.256 376.174 7~.072 lOO.lO0 20.586 255~.?19 349.~42 SBHF.TDTP TRAT.TD~P TCAN.TDTP TSCN,TDTP GRC~t. TDTP SBMF.TDTP TRAT.TDTP TCAM.TDTP TSCM,TDTP GRCH,TDTP -999 250 -999~250 -999.250 -999,250 -999~250 48,905 1. 886 40775' 672 1798,031 48i938 58.230 i,846 35839.125 919.758 58.8!3 IS Tame Vo. rif.,icat.i.,on Listln-q chlumherger Alaska Computino Center $2H~f,TbTP -9q9,250 SIGC.TPTD SDS~.~UTP -909.250 ~ACK, TFNS.T~p -999.250 G~. (~+{ [)WpT. 5800.000 SIG~. TnTD S~H~'3.7DmP -9o9.250 SiCC.TDTP SDS~.~DTP -999,250 BACK,TDT~ TCAF.TDTP -999.250 TCND,TDTP T$CW,T0~P -999,250 TU~[). TDTP T~NS. T[)~p 999,250 CR, DMpw. 5400.000 $I~.TDTD SRH~.TDWP -999,250 SIGC.TDTP SDS~,TD~P -999.250 BACK,TDTP TCA~.TDTF -9~9.250 TCND.TDTP TSC~,TDTP -909,250 INND,TDTD TFMS.TDTP -999.250 5200 ()00 SI=,~. -999 250 Si ,C.rPl. -9~9,250 BACK, -999.250 TCND.TDTP -909,250 !NNB DEP'~'. 5000 000 SI ?I.TDTP SBH~;.TD"rP -999,2~0 ........ ~!GC,'rDTD ...... TCAF wD, p 909,250 TC~D.~P 'fSCF' ~'DTP -999,250 I¢4MD TDTP DEPT, 4800,000 SIC!~!. TDTP Mn H~,f. TD~*P -999,250 SIGC,TDTD SDSI,TDTP -999.2E0 BACK.TDTP TCAF. TDT~ -909,250 TC TFNS. TDTP -999,250 CR D~PT. 4600.000 SIG~4.TPTP SB~.TDTP -999.250 $$GC. Tr~TP S ~ $ I, T I.) · P - 9 q 9.250 P, h C K. "' '~ TCAF., D.FP '999 250 TCND TDTD TSCr, ml)~'P -999,25f~ I''': ~' r T TKNS.TD~P -999,250 GR.OH a-.uA.Y- ~. 994 09:o9 -999. -999. -999. -990. -999, 118. -990, -~99, -99o. -99q. -999. 85. -999. -999. -999. -999. -999 -999, -99~. -999. -099. -999, 7~, -999. -999, -99~ -999' -999' B4, -99~, -999, -999, -999, -999, 7~. 99. -990, -99~, -099 -~99. -999, -999. -999, -99~, 74, 9bO TPNI.TDTP -999.250 250 SiBH,TDTP -999.~50 ~50 FBAC.~DTP -999.~50 ~Sn TCPD.TDTP -999.~50 ?50 INFO.TDTD -999.~50 ~25 ?50 TPHI.TDTP -999.~50 250 SIBH,TDTP -999.250 ~50 FBAC.TDT~ -999.250 ~50 TCFO.TDTP 999.~50 ~50 INFD.TDTP 250 TPMi.TDTP -999.250 250 SIFH.TDTP -999.250 ~50 ~B~C.TDTm -999.25.0 250 TCFD.TDTD -999.~50 250 !NFF).TDTP -99~.250 75O 250 TPHI,TDT¢ -999.250 ?50 SIBH,TDTP -999.250 250 FBAC.TDT~ -999.250 ~50 TCFD,TDTP -999.250 250 tNFO.TDTP -999.250 750 ~50 TPHi.TDTP -999.250 250 SIB[t TDTP -999.250 ~50 ~B~C' . ,.TDTP 999,250 "P~ ~ 2999.250 250 TCFD.I...r. 250 INF[),TDTD -999'~50 250 TPHI.TDTP 999.P50 ~50 Si~ii,TOTP :999.250 250 F[~AC,TDTP ~999.~50 250 T' , . ..CFI) TDTP 999 250 ., , r~ . ~50 !NFD TDZ. 999.~50 1.25 250 TP~!,TDTP ~999!250 250 $iBH..TDTP 999 250 250 ~'Bac.'rDT~ 999 ~5o 250 TCFD,TDTP -999.,50 ~5075 !NFD,T~T~ -999.250 250 TPHI.TOTP -999.250 ~50 SIB~i,TOTP -999,250 250 FBAC'TDTP -999.250 250 TCFf),TDTP -999.250 ~50 !NFD,TDTp -999,~50 SBHF.TOTP TRAT.TDTP TCAM.TDTP TSC%~.TDTP GRCH.T[)TP 8BMF.TDTP T~AT.TDTP TCAN.TDTP TSCM.TDTP GRCM,TDTP SBHF.TDTP TPAT.TDTP TCAU.TDTP TSCN.TDTP GRCM.TDTP SBHF.TDTP T~AT,TDTP TCAN,TDTP TSCW.TDTP GRCM.TDTP SBHF. TDTP TRAT, TDTP TCAM TDTP TSCi~ ~ TDTP GRCM, TDTP SBHF,TDTP TRAT.TDTP TCAW,TDTP TSCN.TDTP GRCH,TDTP SBhF.TDTP TRAT,TDTP TCAM,TDTP TSCN.TDTP GRCH.TDTP SB~9'.TDTP TRAT TDTP ~CA.~:TDTP TSC~ TDTP PAGE: -909.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999 250 '999i250 -999 250 -999 250 '999,250 '999.250 '999 250 -999i250 -999 250 -999 250 '999i250 -999:250 '999 250 '999,250 '999. 250 .-999' 250 999,250 ,-999,250 .999,250 -999 250 -999 250 -999 250 -999 250 -999 250 :999.250 999,250 -999,250 -999,,250 -999,250 -999. 250 -999. 250 99 250 -999 ~ 250 IS Tape verificat~.on Listlno cblumberq~r AlasKa Computino Center ~-MA¥-1994 09:09 PAGEt DEPT. 4400.00{3 SIGM.TDTP SmB~.~.TDTP -999.250 SIGC.ThT¢ ~DST.TO~P -999.250 ~AC~.TDTP TCAF.TDT¢ -999,250 TCND,TDTm T$CF.TI)TP -999.250 INND.TDTD TFNS.T[>~P -999.250 eR.ON · ~e(~.000 SIG~I TDTP DFPT 4z.: ...... SmH~.TDTP -999.250 $!GC:TDTP MDST,~D~P -9~9.250 BACK.TDTP TCAF.TDT? -999.250 TCMD.ThTP T$CW.TDTP -999.250 TNWD,TDT~ TFNS.TDTP -999.256 DFPT. 4196.000 SIGM,TDTP SnH~.TDTP -999,250 $1GC,TDTP SD$I.TDTP 999,250 BACK TDTP · .. .? ~ ~ T$CV,TbTP -999.25~ N~D TCTP T~Ng.TDTP -999,25~ ** EWD (DF' DATA ** -090.250 -999.250 -999.250 -999.250 80.625 -999.250 -990.250 -999.250 -999.250 96.625 -999.250 -090.250 -99o,~50 -999.250 -999,~50 ~i0,625 TPHI.TDTP SiBh. TDTP FB~C.TDTD TCFD,TDTP TPHI.TDTP S!BM.TDTP FBAC.TDrP TCFD.TDTP INFD,TDTP TPHI.TDTP SIBH.TDTP FB~C.TDTP TCFD.TDTP !NFD,TDTP -999.250 999 250 -'990:250 -999.~50 -990,250 -999.250 -999.250 -99~.~50 -999.250 -999.~50 -999.250 -990.250 -999,250 -999.250 -999.250 SBMF.TDTP TRAT.TDTP TCAN,TDTP TSCM.TDTP GRCW.TDTP SB~F.TDTP TPAT.TDTP TCAN.TDTP TSCM.TDTP GPCM.TDTP SBHF.TDTP T~AT,TDTP TCAM.TDTP TSC~.TDTP GPCM.TOTP 99,250 99,250 99,250 :9999. o 99.250 -999 250 -999:250 -999.250 -999.250 -999,250 -999,250 -999 250 -999:250 -999,250 -999,250 **** FIL~ WRglI, ER **** FIbE NA~E : EDIT .0ol ~RVICE : FblC VFRSiON : 001COI D~?F : 94/05/ 5 FJLF TYPE : LO LgST FII~E : F!LF MAME : EDIT .002 $~RV'ICE : FLIC VERSION : 001C0! D~Tr, : 04/05/ 5 M~X RFC STZ~ : FILF TYPE ! LO I,,~Sw FibE Depth sh~,fted P~SS DFP*H t~CRE~E~T: 2 and clipped curves' for each 2 0,5000 PaSS in separate files. IS Wane Verification l.,J..sti, nq cblumherqor AlosKa Comput!nc Center 8-HAY-l, 9q~ (i) 9:09 PAGE: !.DWG TOO[., CO~[ START DEPTH TDTP ~42~.5 CI~RVE $HIFT DATA - pass Tf) PASS(~FASU~ED DEPTH) PASE~,i~E C!!~VL FOR SHIFTS LD~G CU~VF CONE: G~C}.~ P~SS ~U~F~: I STOP DEPTH 6100,0 6100.0 ~ASEL!NE DFPTh GRCh TDTP ~88 .0 6430.5 6420,5 6~96,0 6395,5 63~7.0 6386.5 6357.5 0356.5 6356,0 6355,5 6331,5 633!,0 6327,5 6327.0 6~21.5 6320.5 6 ....q 0 6~9~ 5 6796~0 6292.5 6292,0 6~fi3.5 6~3.0 6?80,5 6~80.0 6267,~ 6266,5. 6247,0 6246.5 6~24,0 6~23,0 6218,5 6218,0 6192.0 6190,5 6!89.5 6~67'5 6!67.0 6149,5 6!48.5 6145.5 6!44.5 ~OO.O 99.0 PEI~APKS: THIS WILE C~i~TAINS T~iE SECOND PASS OF THE TDTP. TME [)EPT~ BDjUST~,.iEI~;'r$ SHOWN ABOVE REFLECT PASS ~2 GRCH TO ...Pq~5S ~1. (~PCH A~F~ PASS ~2 $IG~-~ T~ PASS ~1 $IGM~uALL (..,~V~:S WERE C~RRI~D ~IT~ ~Hr Slo,-, S~IFT I.,!5 FORaAT f~ATA ........ EOI;I A!.,ENI UNS~IFTED oEPTH ......... IS Tare Ver.lf. icat.~on ~,istin~ ChlUmbe~qer A-!as~a Comit)ut.~n~ CeDter R-!U, AY- 1. 994 PAGE: ** PATA FgP,~,~T SP?.CTF[CATI[')I~,~ rTECOPD 1 66 0 2 66 0 3 73 ~ 73 7 65 9 65 11 66 12 12 68 13 66 0 14 65 !5 66 68 16 66 0 66 ** SET TYPE - CHAN ** NaM ~RV UN! gERVICE A I AP! AP1 I FILE UMB NUMB REPR n? "'YPE CDASS ~OD NUMB. SAuP EDEN CODE (HEX) ID OR~ER ~ L,.(, ~ .... ' ........ X;';""' .... ,"'"'"",'""'"'"'"'"'"'"""'"'",,,,,,,,"' F? .. 0 94 O0 O0 O0 ~ ! i 4 65 0 0 SIG~,~ TDTP Cl.! 480694 O0 000 O0 0 ? ! 1 4 68 TPHT TDTP PU-S d80694 O0 000 O0 0 2 I I 4 68 S ~ H ~' T D T P C I.~ ~ 80694 00 0 O 0 00 0 2 i I 4 68 8~HN TDTP C,[., 480694 O0 000 O0 0 2 1 1 4 68 STGC T[)mp CU 48069<~ oO 000 O0 0 2 1 I 4 6B STBN T D'.r P CIJ ~80694 O0 000 O0 0 2 1 I 4 68 T~AT TDTP 480694 O0 000 O0 0 2 I 1 4 6~ SDST TDTP Cfi 480694 00 OOO O0 0 ~ ~ 1 4 68 : ~. ~ '"~ BaC~ TDTP CPS .~F0604 O0 000 O0 0 ~ 1 I 4 68 F~AC TD~P CPS 480604 oO 000 O0 0 2 1 I 4 6e TCAS? T !r) TP 4'80694 O0 000 O0 0 2 1 I 4 68 ~.'OA W T[)TP ~8069~ O0 000 O0 0 n ~ ..... ~, ! 1 4 68 TCND TDTP CPS 4~80694 O0 OoO O0 0 2 I I 4 68 TCF~ TOmP CPS 480694 O0 ()00 O0 0 2 ! 1 4 68 TSCN TDTP CPS 480694 O0 000 O0 0 2 1 1 4 68 TSCW TDTP CPS ~80694 O0 000 00 (:) 2 I 1 4 68 I ~,~N ~ TDTP CPS 48069~: O0 000 O0 0 2 1 1 4 68 I~TFm ?[)mp CP$ a80694 0() i)O0 O0 0 2 I 1 4 68 G~Cr~ TD~"P GAP]: 480694 00 000 00 0 2 1 I 4 68 T~NA TDTP bFt 48nbq4 O0 000 0(,) 0 2 1 i 4 6~ 0006000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Taoe Verification List, inq chlumberQer AlasKa Co~potIno Center 8-~AY-1994 09:09 PAGE: DFPT. 6426.500 SIGM.TDTP SDS!.TDTP 0,6~4 BACK.T~T~ TCA~.TDTP ~737.000 TCNO.T~T~ TSCF.TD~P 346.698 !N~D,T~T~ TFNS.T)TP 1594.~66 DWPT. 6400.000 S1GM.TDTD S~H~.TDTP 58.1~4 SIGC.%DTD SDS~,TDTP 0.4~6 ~CK.TDTP TCA~.WD~P 12751.500 TCND.TDTP T~C~,TDTP 589.688 IN~D.TDT~ DEPT. 6200.0~U g!C~.TDTP SBH~.TDTP 60,657 SIGC.TDTD SDS~.TDTP 0,7~2 BACK.TDTD TCAF,TDTP q56~.063 TC~D TDTP TSC~'.TDTP 230.6!'7 ii~ND~TDTD TFNS.TVTP 1562.~56 37.81!. TPNI.TDTP 0 400 SIBH,TDTP 1191707 FBAC,TDT~ 124~6.250 ?C~'D,TDTP 162~.969 INFD,TDTm 63.853 108.870 3!.679 2829.313 342.273 30.603 TPHI.TDTD 53.127 0,782 SIBH,TDTP 95.0S5 !23.380 FBAC,TDTP 27.838 14369,000 TCFD.TDTP 349a,438 1579.344 INFD,TDTP 360.697 43.902 TPHi.TDTP 0,063 $IMB,TDTP 145,161 FBAC,TOT~ 1099~.~03 TCFD,TDTP 1661.398 INFD,TDT? TPH!.TDTP SIBH,TDTP FBAC'TDTP TCFD,TDTP INFD.TDTP 0 ! 49 075 1,18~3 502 1640 323 74.553 102.387 30.728 2382.914 326.180 71 393 102i463 32910 2669.~88 362.089 SBHF.TDTP TRAT.TDTP TCAM.mDTP TSCM.TDTP GRCH.TDWP SBMF,TDTP TRAT.TDTP TCAN.TDTP TSC~.TDTP GRCM.TOTP SBHF,TDTP TRAT,TDTP TCAN,TDTP TSCN,TDTP GRCM.TDTP SBHF.TDTP TRAT.TDTP TCAN,TDTP TSCN.TDTP GRCH,TDTP 56.455 1.854 32540.000 ~217 750 999:250 48.908 1.895 43740.000 1887,]75 112,750 57.087 1.891 39610,500 909 445 92:063 43104.641 936,665 98,125 **** FILE TRAII, E~' **** FILF ~,,'A~E : EDIT .002 S~RVICE : FLIC VERSIO~ t OO1COl D~.TF : 94/05/ 5 .~:i~X R~C SIZE : ~.094 F!L~ TYPE : !,O LA8W FILE ~ **** FILE F/bF NA~E D ~ T E FTL~ TYPE HEADER **** : ~DIT .003 ., oO1COl : o4/©5/ 5 : 1024 IS !ra~e verificat,)on Listi, nn. chlUmberqer AlasKa ComPuting Center ~-MAY-]994 gq:09 PAGE: 10 FTLF HEADER EDIWE~ CURVES ne~th shifted and clt~pped curves for each Dass ~n separate files, P~SS NU~SKR: 3 DFP~ I~'C~E~E~T: 0,~000 FIL~ StJ~a~RY .. ~t 6 · DTP 6433,0 6~00,0 CURVE SHIFT DATA - PASS TO PASS(MEASURED DEPTH) P~$ELINE CURVE] FOR b~WG CURVE CODE: ~RCH PhSS ~U~B~R~ 1 ~ASELI~E DEPTH 6431,0 6386.5 b35~ 5 6357~0 ~30.5 6326 0 6324 5 630~ 0 630? 5 6286 5 6279 0 6237 0 6225 0 6~93 ~ 6171'n 6148'0 6136,~ 6111,0 6~55,5 6~29,0 6323.0 6306,0 6?77,0 TDTP 0 6385.5 6356.5 6324.5 e3oo,5 6246.5 6235.0 6223.0 6221,.0 619~.0 61~9,5 6~69.5 6~66,5 6146,5 6!34.5 6~2~,5 6109,5 9~.5 99,0 THIS VILE CONTAINS TBE THI~ PASS OF TgE TDTP, THE DEPT~ gDO[IST~!~TS $~{OWN ABOVE REFLECT PASS #3 GRCH TO P~SS ~i GPC~ ~i~D PASS ~3 SICM TO PASS ~1. SIGM, Ab[, OTa~ P~$$ ~3 C[!RVES WERE CARRIED WITH THE SIGM S~IFTS. IS Tame Verification List~no ChlUmberoer AlasKa Compt!t~Bq .Center 8-~AY-!994 09:09 PAGE~ 1! ** ~ATA F'C~R~AT SP~CTFICATION ~ECURD ** ** SET TYPE - 64~ ** 1 66 0 2 66 3 73 4 66 5 66 6 73 7 65 8 68 0.5 9 ~5 1! 66 ~2 1) 66 0 14 65 PT 15 66 68 16 66 0 66 ** SET T~PE - C~AN ** '"'" ..... '"" "'" ........... '" '~['" " ' ~E '" ~;~[;~" ID ORDER # bOG TYPE CLASS gOD NUmB gAAP EbEM CODE (HEX) '~p,, ~"'"'g'4~..~g~ ...... oo"','"'""","'"'",oo oo ~ ...... ~'"",'"'"'"",,,,,"'"''" ~ ooooo STGu TDTP CU 480604 00 000 00 0 3 ! 1 4 68 TPHI: TDTP PU-S 4@0694 00 000 00 0 3 I 1 4 68 8BHF TDTP CU 480~94 00 000 00 0 ] I 1 4 68 Sgfl~ TDTP CU ~80694 O0 000 O0 0 3 ! ~ 4 68 SIGC TDTP CU 480694 O0 000 00 0 3 1 ! 4 68 $1BN TDTP CU ~80694 O0 000 O0 0 3 1 1 4 68 TRAT TDTP a80694 O0 000 00 0 3 I I 4 68 SDS? TDTP C!J 480694 00 000 00 0 ] ! i 4 68 BACK TDTP CPS 480694 00 0G0 00 0 3 I I 4 68 F~AC TDTP CPS 480694 00 000 00 0 3 1 1 4 68 TCA~~ ~DTP 480694 O0 000 0O 0 3 I 1 4 68 TCAF TDTP 480694 O0 000 O0 0 3 ! i 4 68 TCND TDTP CPS 4.80694 00 000 O0 0 3 1 I 4 68 TrF~ TDTP CPS 480694 OO 000 O0 0 3 I 1 4 68 TSC~ ~[)?P CPS ,a806~4 O0 000 O0 0 3 1 I 4 60 TSCt ?D~P CPS ~8()~94 O0 000 O0 0 ] I I 4 68 INND TD?P CPS 4~0694 00 000 00 0 3 i I 4 6~ !~FD TDTP CPS ~,80604 O0 000 O0 0 ~ 1 I 4 68 GPC~ TOTP GAPI ~:80694 O0 000 O0 0 3 ! I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ,IS Tane v~r.tfication Li. stlna R-,~Y-t994 09:09 Cbl,mberq~.r Alaska Co~put.inq Center 12 TD ~NDE~ ~ LOG ~'¥PE CbA~S ~OD NUmB SAng EL~R CODE (HEX) ............ ....... ........ .............. ........... ..... ~'p LR 4~ 6.. O0 .. O0 . 3 ! 4 . OOO00 0 DFPT 6433.{)00 $IGM.TDTP 33.727 TPMI.TDTP 49.572 SBHF.TDTP .~ ~,.,-~.. 0.85G SIBH.TDT? ~04.q0~ TRAT.~'DTP $OSI 'rl]tp 0.649 ~ACK TDTP ~90.444 rBAC ~.tP 51 120 TCAN.TDTP ... ~ .... TnTP 3234 913 T$C~.TDTP TCAF,TI~¢'P 10439.34z TCMD.Tn~;~ 12984.500 TKCV.T[)TP 467.475 INND.TPTP 164~.188 !NFD,rDt 304~320 GRCN.TDTP TW~VS.TOTp ~400,000 DKpT. 6400.(;00 $1GM.TPI'P 30.277 TPHI.TDTP 55.39! SBNF.TDTP $~MN.TDTP 56.37u S!GC.T~TP 0.752 SIBH..TDTP 89.977 TRAT.TDTP SDST'~D~ 0.451 BACK.TDTP 152.168 FBAC'TDTP 33.990 TCAN'TDTP TCAF ~DTP 119n7 500 TCND q,P~ ~3994.~25 TCFD. . . . TDT~ 339~.813 T$C~.TgTP bTP 570.7~9 INNDiI~'~TP ~620.789 INFD.TDTD 345.053 GRC~.TDTP DrPT 6200 0OO SIG ~.TPTP 43 291. TPHI.TDTP . I'.TP 0.~45 SIBH TDTP SmH~. T[)TF 61,830 SIGC.' TD~"P 0.7~I BACK TDTm 165.89~ FBAC.TDTP SBST ' T[)TP 9363 500 TCN[):,~D. · , I .... IP ~009t,~72 TCFD TDTP TCAF, ~'~'r , , . TDTP TSC~,Tu~'P 2~2 2~1 INND 1.....TP 1675 875 INFD, TFNS,TD~ ~, 1550, DMPT, 6100 . "'o'",; .,,,v SIG~,~.TDTP 43,273 TPHI. TDTP SBiiN~ Ti)TP 60 7aC SiGC TDTP 0 763 SIgH.rD,. . . ""~P 022 FBAC. TDTP SDS'T,mt)TP 0 780 BACK.I~Di'- 169. TDTP TCAF,TDT. 10187 006 CND.TDTP 11881,912 TCFD, TSCW,TOT~ 256.570 I. NN'D.TDTP 1698.329 INFD,TDTP 72.229 105 777 33 029 2416 500 325.211 62 932 o :,7 4 35.645 2714o765 362.437 SBHF,TDTP TRAT.TDTP TCAM.TDTP T$CN.TDTP GRCH.TDTP SBMF.TDTP TRAT.TDTP TCAN.TDTP TSCN.TDTP GRCM.TDTP 57,873 1,703 33935,703 1420.652 -999.250 53.064 1.9~6 41958.0 0 1904 125 125~500 54.404 1,861 34486.~.~3 909. 9 116.750 54,348 1.7t. 2 40715,773 9!7,156 !19,000 **** FILE TRAILER **** FILF NAME : MDI![ ,g03 SERVICE : FbTC V'~R$ION : O01C01 D~T~ : 94105/ 5 M~X RFC SIZE : !024 F!L~ TYPE; IS mare ~erif~.cation t, isti. nq ChlUmher,aer AlasKa ComDut~r,~ Center ~-MAY-1994 09:09 PAGE: 13 V~RSIO~-~ : ,~01CO1 D~Tr : 94105/ 5 ~,~X REC 5tZ~ : ~024 Compensated ~,leutron: Arithmetic average o~ edited ~asses ~or all curves. .ulsed Neutron; Unaveraqed edited Pass I Gamma Rav and Dackround counts~ arithmetic average of edited static basel~.ne passes for all ot~er curves. DFPTH INCRE~ENT 0.5000 P~S~E8 !NCLIIDED l~ A'VERAG~ T~OWG TOOI~ CODE PASS NU~BER8 ~E~'~A~S: T~IS FILE CONTATNS THE ARTT[I~ETIC AVERAGE DF THE T}iRE~ TDTP PASSES, ALL DEPTH CORRECTIONS WERE APPLIED BEFORE TN~j AVERAGE ~A~ CO~APUTED. FDR~,~ AT DATA DATA FOR~AT SPgCIFTC~TION ~ECORD ** SET TYPE - b4gB ** ~S REPR ODE V 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 7.3 7 65 8 68 0,5 9 65 FT 11 66 14 !~ 68 1~ 66 0 14 65 ~T !5 66 68 IS Tame Verification L, istin~ chlumberqer AlasKa Computing Center ~-~AY-t994 09:09 PAGE: 14 ** DFPT SIG~' ~VE CU ~PHT AVE PU SnH~ AV~ CU STGr ~V~ C~? S!~T~ AV~ T~AT B~C~ ~V~ CPS F~ AV~ Tr~? AV~ TCN~ ~V? CPS T~F~ ~V~ T$C~ ~V~ C~S GPCW AY? G~PI TYPE - CNAN * ORDER # LOG 480694 O0 480604 00 4~0694 O0 aso6q4 oo 480694 O0 4~0604 O0 4~0694 O0 ~806g4 nO 4~0694 O0 ~80694 nO ~8n694 oo ~069~ O0 48069~ O0 ~80694 O0 48..694 O0 4806g~ O0 mmm.mmmm mmmmmmmmm mmmmmmmmmmmm. 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 OOO O0 0 4 l I 4 68 0000000000 000 O0 0 4 1 1 4 6R 0000000000 000 O0 0 ~ i 1 4 68 0000000000 000 O0 0 4 i I 4 68 0000000000 000 O0 0 4 l I 4 68 0000000000 000 O0 0 4 i 1 4 68 0000000000 000 O0 0 4 1 I 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 I 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 1 4 68 0000000000 000 O0 0 4 1 I 4 68 0000000000 000 O0 0 4 i i 4 6~ 0000000000 000 O0 0 4 I t 4 6~ 0000000000 000 O0 0 4 1 1 4 6~ OOO0000000 ** D3Tg ** DEPT. Team. AY? TMCV,AVE DEPT. SnH~.A, VE SBS~,~VE TCAF,~VE TSCF,AV~ o...$1 AVE TCAF" ~V~ 6440.t~00 -999,250 -999.250 -999.250 -999,250 6400.000 57,31~ 0,459 i~17~.7~3 572,975 62O0,000 0,600 ~869.654 233,797 $1GM'oAVE. -999..250 TPHI.A E,, ' V"' -99g.,250 SBHF.AVE St, ~C AVE -999 250 SIBH, AVE . .. A E 999 250 TRAT. BACK,AVE 78, t54 FBAC.,AVE 2~, 583 TCAN.AVE TCLD AVE ~9~,250 TCFD,AVE 999~250 TSC~a. AVE GRCH,AVE :990,250 SIGM.AVE 30,785 TPHI.AVE 54.168 SBHF.AVE S,IGC'AVE 0 7~2 SIBM.AVE 92.71~ TRAT AVE BACK.AVE 52[303 FBAC..AVE 13.984 TCAN~ AV'E TCND,AVE 141.80.344 TCFD.AVE 345~,!57 TSCM AVE CRCH'AVC 48.938 ' ' SIGM.AVC 43.6i8 TPHI.AVE 72.944 SBHF,AVE SIGC,AVE 0.069 SIBH,AVE I05.744 TRAT,AVE BACK.AVE 100.020 FBAC,AVE~ 20.586 ~ANC AVE TC~[') AVE ~1~94,693 TCFO AVE 2450 299 TSCN" ,..~.,AVE 5~, 813 -999,250 -999.'250 -999,250 -999'250 50.288 1,915 42153,680 1862'991 56.568 1,866 912'969 Tame Verl£ication !,istinc! cblumberqor A].a$~.a Computi,~no Center 09:09 PAGE: 15 DFPT. 61o0.0o0 $ IGi'4. AV~j SnH'~' ~V~ ~l.lg5 SIt~C.AVE SP$I .AV~ 0.~66 BACK,AVE TC~F.AVF 10087.564 TCND,AVE TSCF.AVE 247,6qa GRCH,AVE 43.30g TPHI.AVE 0,612 SIgH.AVE ]11.2B0 FBAC,AVE 118~,596 TCFD,AVE 57,125 66.028 5BHF.AVE ~03,865 TRAT.AVE 24.264 TCAN.AVE 2696.585 TSCN,~VE 56.014 1.761 40631.695 9~9,291 FILw ~qA~-~E : EDiT .004 VF~Si('~N : O0~COI DnTE : 94105/ 5 MIX aEC SIZE : ~0~4 FTLF TY~ : L~8m F.ILE FILF N,A~E : EDIT V~RSIO~ : O01CO1 DnT~ : 9~/05/ M~X R~C SIZE : ~0~4 FTL~ wiPE : LO FILE Rlw CURVES Curves and loo header data for each pass in separate DFPT~ I~CRE~E:aT: 0,5000 F'Ib~ SU~RY VENDOR TOOL CODE START DEPTH STOP DEPTH '~;~'''' .... ' .... ;X~;'[ .... ''''''''''097 n,+ ..... 6 ,0 LO(; i,tEAD~R DATA SOFTWAPE VERSION: TI~E LOG~EP ON wi) O~ILb~R Ti) LOGGE~(FT): TOP [,OS INTERVIB POTTO~ bOG iNTeRVAL files; raw bac~oround pass in last fi 24-MAR-94 38,2 1750 24-~AR-94 655~,0 6442.0 6100,0 6435.0 600,0 iS wade Ver~ffcati, on t, istlno chlumherq~,r ,AlasKa ¢'omiout~[~ Center [~-MAY-I 994 09;o9 ']'f~t']I, STt~I~G (TOP TO ................ ..... ...... '['nTP ~ ~';P ~ ~ ~CAY T~ TDTP TRE~MAb DECAY TDTD THERMAL DKCAY L)~TECTO~ T~TP TOT~ TmT~ $ TOOL NUNBER TNC-P-50 TND-P-78 ~OREHOLE A~D CASING PATA OoE~I HOLE MIT STZF DRILl, EPS C~$IN~ DEPTH LO~GER$ CASIng DEPTH t~{3~ E~OLE CONDITIONS FI, U ID TYPF: FLUID DENSITY (I,B/G) 6OTTOM NO[,E T~NPERAT!]~E (DECF): rLJID S,~LINITY (PPM) FLUID LEVEL (FT): FbUTD RATE ~.T ~ELI,~iMAD W~TFR Ct~TS (POT} GAS/OIL R~'lrIO ~ CHOME (DEC) 3143.0 ~TPlX: ~ATRIX DE~S!TY: CORRECTION (IN): BRINE 11.70 165.0 THERMAL SANDSTONE '2.65 B.btJ~b~i~E COl, IN? RATE i~OR~ALIZATION IM OIL ZONE TOP ~O~M,~LIZT'NG WINDOW BASE NOR~.ALIZING WINDOW (FT)~ ~b~IE~,INE COU~:~T R~TE SCALES SFT BY FIELD ENGINEER MAP CO!.Ii~T R~TE LOW SCALE (CPS): 0 FAR COUHT PATE HIGH SCALE (CPS); 12000 ~4E~R COUNT R .r~, b['.)W SCALE (CPS) 0 ~,;E,~R COUNT R~TE UIGH SCALE (CPs): 1200 TOOL STANDOFF RF~I~RKS: 5PIED iNTO CBT 3!20i94, ~i~ 3 P~SSE. , ~S a 600 ~P~. b!S FOR~A? DA~A PACE: 16 IS wane Verification !,i.$tinO Chltlmk?-ergor AlasKa Comp~Itino Center 8-MAY-19q4 09:09 PAGE: 17 ** ~Aq'A FOR~:A'r SP~?CIFIC.&TTO~~ PE(?ORD ** SET TYPE - 64EB TYPE REPD CODE VALUE l 60 0 2 65 0 3 73 200 4 66 I 5 66 ~ 73 7 65 8 68 0,5 9 65 11 66 3 1~ 68 It ~6 0 14 65 I5 66 68 16 66 O 66 IL) ORDER ~ LOG T..PE CL~SS MOD NUmB SAgP El,EM CODE (HEX) '''O~P' .... ''''' ......F~ ~';;'8 94 ........ O0 ''''''''''''''''''''''''''''''''''''''''''''~'''''''''''00 5 I 1 68 000000000 SIG~ ID1 CU 480604 O0 000 O0 0 5 1 t 4 68 0000000000 TPHI TDI SFND TO~ -$BH~ FTD* T[)~ NTDT AFFD A~Fn TDI AFND A~ND SIGC ID1 Slb~ T~A? B~C~ FgAC TC~~ TCAF 480694 O0 PU 480694 O0 V 480004 O0 CI! 480694 O0 CU 48060~ O0 Ct! 480694 O0 CU 480604 O0 CPS 480694 O0 CPS d80694 O0 CPS 480604 O0 CPS ~80604 O0 CPS 480694 O0 CPS 4,80694 O0 CU 4, a06~4 O0 CU 480694 O0 480604 O0 480694 O0 CU 480694 O0 CPS 480694 00 CPS 4806o4 O0 480694 O0 d~0694 O0 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 I ! 4 6~ 0000000000 000 O0 0 5 1 1 4 68 0000000000 000 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 ! 4 68 0000000000 000 O0 0 5 I i 4 68 0000000000 OOO O0 0 5 1 1 4 6~ 0000000000 000 O0 0 5 1 t 4 68 0000000000 000 O0 0 5 1 1 4 6? 0000000000 000 O0 0 5 I 1 4 68 0000000000 000 O0 0 5 i 1 4 68 0000000000 000 O0 0 5 i 1 4 68 000000000o 900 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 I I 4 6~ 0000000000 oeo O0 0 5 I I 4 68 0000000000 000 O0 0 5 1 t 4 68 0000000000 OOV O0 0 5 1 1 4 6~ 0000000000 000 nO 0 5 1 1 4 68 0000000000 000 O0 0 5 1 i 4 6~ 0000000000 000 O0 0 5 1 I 4 68 0000000000 000 O0 0 5 1 1 4 68 0000000000 Wane Vorification T, ist~,no CblUmheraer AlasKa ComFuti. nq Center R-MAY-~.~94 09:09 PAGEt 18 TCN~ _ 0004 TCF~ TD! CPS 4S0~94 O0 TSC~ TO~ CPS a~0694 OO TSCF ~[)! CPS 480~4 O0 I~'F'B TD1 CPS 480694 RWl TDI C~S 4~0694 O0 R~2 TDI CPS 480604 OO RM4 TD~ CPS 480604 O0 ~15 TD1 CPS 4~0694 O0 Ru7 ?D~ CPS 480694 O0 R~8 mD! CPS 480604 R~9 T[)~ CDS 480694 O0 RWl0 TDI CPS 480604 O0 R~I1 TD! C¢S 4Bo694 o0 R~i~ ~DI CPS 480694 00 R~i~ ~O~. CPS 4806~4 00 R~I~, ~O! CP~ a80694 O0 R~lS TO! CPS 480694 00 RUl6 TO! CPS 480694 O0 RPI TD~ CPS 4B0694 00 RP2 TD!. CPS 480694 00 RP3 TD! CPS 480694 O0 RF4 TD~ CPS 4~0694 00 R~5 ~D1. CPS ~80~04 00 RF6 TD~ CPS 480694 O0 R¢7 mD~ CPS 4806~4 O0 RD8 T[>~ CPS 480694 O0 R~9 TD1 CPS ~80694 O0 RFiO TDJ CPS 4~0694 O0 RWlI. W[)~ CD8 480694 O0 R~i~ TD1 CPS 4806~4 O0 RP13 TDI CPS 480604 00 R~14 TD~. CPS .~806~4 00 R~15 TD! CPS 480694 00 R~16 :rD! C~$ 480604 O0 GP TD~ GAPI 480694 00 TENS TO!, b~ 480694 O0 CCh TD! V 4~0694 00 mmmmmmm Mmmm#mmmm mmmmmmmmmmmmm mmmm ;;~ ........ ; .............. l ............ ' .......... 3; .... o~ _ s i 4 o~ oooooo oo ooo oo o s 1 1 ~ ~, oooooooooo GO0 O0 0 ' 1 1 4 68 000000000a CO0 O0 0 ~ 1 1 4 68 0000000000 ooo oo o s 1 ~ 4 ~ oooooooooo 000 OO 0 5 I 1 4 6" 0000000000 coo oo o s ~ ~ ~ ~ oooooooooo ooo oo o ~ ~ , 4 ~ oooooooooo ooo oo o s 1 1 4 ~ oooooooooo ooo oo o s ~ 1 4 ~ oooooooooo o,o oo o s ~ ~ 4 ~, oooooooooo 000 O0 0 5 ! I 4 68 0000000000 ooo oo o s ~ 1 4 ~ oooooooooo ooo oo o s ~ I 4 ~ oooooooooo ooo oo o s i ! 4 ~ oooooooooo OOO O0 0 5 1 I 4 68 0000000000 ooo oo o s , 1 4 o~ oooooooooo ©00 00 0 5 1 1 4 08 0000000000 ooo oo o s i , 4 6~ oooooooooo ooo oo o s ~ 1 4 6~ oooooooooo oo~ oo o s ~ 1 4 6~ oooooooooo 000 00 0 5 1 ~ 4 68 0000000000 ooo oo o s ~ ~ 4 6~ oooooooooo ooo oo o s ~ i 4 ~8 oooooooooo 000 O0 0 5 1 ! 4 68 O00OO00000 ooo oo o ~ ~ 1 ~ 6. oooooooooo ooo oo o s 1 i 4 ~ oooooooooo ooo oo o ~ 1 ! 4 ~ oooooooooo 000 O0 0 5 I i 4 68 0000000000 ooo oo o s ~ ~ 4 6~ oooooooooo oo~ oo o s ~ ~ 4 6~ oooooooooo 00© O0 e 5 1 i 4 68 0000000000 coo oo o s ~ ~ 4 6~ oooooooooo ooo oo o s ~ ~ ~ ~ oooooooooo ooo oo o s ~ 1 4 6~ oooooooooo 000 O0 0 5 I 1 4 6~ 0000000000 ooo oo o s ~ ~ 4 ~ oooooooooo 000 00 0 5 1 ! 4 69 0000000000 000 00 0 5 I ~ 4 68 0000000000 ooo oo o $ i i 4 ~ oooooooooo ooo oo o s ~ ~ 4 ~ oooooooooo DEPT. ISHH. 6449,500 172,371 2,700 237.8~2 . ~ .., ~0 ~ ~'~D SFPO TDI 34.. SB'"ND ! .i 36,703 SBHP'TD~. CTDT.TDi 0.000 MTDT.TD1 0.000 AFFD. TOi. A. FN[). Th ]. 60,572 ABED,TDI 1.t80 $IGC,TD~. ..... - 046 TRnT.TDI 0,000 SDSI TD!. ~MOF, TT) i O, ...... ,. 436 000 IS Tame VerificatJom l. istinq chlumberger Alaska Computing Center BAC~.T!)I 14.707 FBAC.TD1 18. TCNO.Tbl -197.307 TCFD.TD1 -~13. I~'~ TD1 -0.500 !~rD.IDI -0, PN~:TDI 128],:i. 44 RN4. 'I~D 1 163~, ~N7,TD! 67~,j48 R~8.T~t 77~. R~II,T[)! 1671,401 ~N12.T~I 1420, ~F~,Ti)~ 250,9q7 RF4,TD1 364, ~F7.TD1 1~4.b59 RFB,TQ1 293. RFll.TD! 445.076 ~F12,TDI 321, RWlS,~D~ ~0o4Q2 RF~6.TD1 7!. CCL.TO! DFPT, 6400,009 SIG~.TDI 30. I5H~I.'rD1 40.344 SFFD,TD! 31, $~H~.TD1 57.101 FTDT.TD1 4. A~F~,~D! QI,37~ ~FND,TDI 5IB~,TD! 92,096 MHOF,TDi O, B~CW,'¥D1 52,574 FB~C,TDI 13, TCND ~"1 , , .'~t~. 14413 922 TCFO TDI 3520, I~NQ.TD! ~.5~9,430 INFD,T~i 372, ~H3.TD1 1171,0~6 R~4,TDI 151~, ?Dt 703 91.4 ~NS,TDI 770, R~11 .Ti)! I766.098 Rbit2,TDi 1583. R~15 ~i·)l 34,0 909 RNI, 6 ~D · . .... , .~.1 19~ ~F3.TD!, 245.76~ RF4.TD! 315~ PFT.TD! 174.i54 RFS.TD~ 309. RFll.~D! 4~9.453 ~F12.TD1 419. RFIS.TDt 105,794 RF16,TDi 65, CCL,?OI ©,000 D.~PT. 6200.000 ISHU'TD1 1.0.4!.4 SFFD.TD1 SBH~,TD1 62,550 FTDT,TDt ABFn,TD~. 77,331 ~FND,TD1 STB~.~. TD1 107,~66 MMOF.TDi BAC~. Ti:)!. 98,969 ~B~C.TDI TCND.T[)!~ I~.571.918 TCFD.TD1 INND.'rD~ 1.643. ~,15 INF!)'TD~ PN~ 'l?!)~ ~117.271 RN4.TDI Ra'15 TD1 357 S63 RNI, 6 ~F7,!,D1 i t 8,815 RFll,TD! 345,052 RF12,TD1 RF1S.T[)I. 79,753 RF16.TD1 CCL, ~D 1 0, 09:09 049 TCAN.TD1 873 TSCN,TD1 614 RN1.TOi 257 RNb,TD1 7~0 RN9,T~I 454 RNI3,TDI 21~ RF!,?D1 583 RFS,TD1 5~1 RFg,TDI 970 RF!3.TDI 023 GR.'rD! 772 STDT.TD1 537 SFND,TO1 044 NTDT,'rD1 O96 ABND,TD1 972 TRAT,TD1 593 TCAN.TD1 407 T$CN,TDI 283 RN!,TD1 30~ RNS,TD1 202 RN9.TD1 01~ ~N!3.TD! ~64 RFi.TD! 755 RFS.TD1 245 RF9.TDI 922 RF1.3,TDI 104 GR,TOl 43, 43, 382, 2O 2543, 345, 1443. !724 386 ~96 281. 655 STDT,TD! 782 SFND,TD1 303 NTDT,TDI 349 aBND,TD1 q74 TR,.~ 586 TC~N,TDi 337 TSCN,TD! 852 RN1,TD1 212 RN5'TDI 81~ RN9.TD1 798 RN!3,TD1 425 RFi'TDi ~24 RF5'TDI 0~6 RFg,TD! 576 RF!3,TD1 987 GR.,TD1 43,552 385.$0~ 1,026 23,591 8TDT,TD1 8FND,TDI NTDT,TD! ABND,TDI TRAT,TDI TCa~,TDI 0.000 0.000 ~04 356 1~67:803 1425.189 321.970 326 705 378:788 ~69.886 52.68~ 66.000 33.14o 13.815 417.886 42477,070 1894,195 921 7i7 1448.864 1~7~.096 317.~83 380.859 34].424 50.~8~ 66,000 43 5 84 37~.310 35736,961 924 930 ~0 1384 408 1370968 793:011 29!,34! 270.182 3~0 872 ~98,568 65,625 66 000 45 182 8 412 369 976 ~,,685 38247.03i TCAF.TD1 TSCF,TD1 RN2.TD~ RN6.TD1 RNIO.TD1 R~14,TD! RF~ RF6~TD1 RF10.TDI RF14.TD~, TEN$.TD1 TPMI.TDt AFFD,TD~ SIGC,TD~ SD$I,TD~. TCAF,TD! TSCP.TD! RN2,TD~ RN6,TD1 R~IO TD1 RN14:TDl RF2.TD1 RF6,TDI RFIO,TD~, RF14.TD! TENS.TD1 TPHI,TDI SBHF.TD1 AFFD,TD~ $IGC,TD1 SO$I,TD! TCAF,TD1 TSCF,TD! RN2,TD! RM6,TD~ RM!O,TD1 RNI4,TD1 RF2,TD! RF6 ~.. RF14 TD1 TPHI,TD! 8BHF,TD~. A~FD,TD1 SIGC'TD~ SDSI,TD~. TCAF,TDI PAGE: 0,000 0,000 5 O0 288 134~ 432 57 917 15 480 312~500 340,909 213.068 !290,000 54,250 48 835 0.652 0,430 12308. 07 582.~06 52,~32 ~384'.54 1382,576 743.371 10.~0 310,872 343,424 221'354 1595,000 72,245 57,498 68'650 0,000 0633 8655330 239:048 98 04O 1218078 1263441 488· 24,080 237 630 26204a 97,656 !585,000 61.5'34 56,869 67,826 0,731 0'614 9748,389 IS ?aoe Verification 1. istlnq chlumhero.~r AlasKa Camputln~ Cent:er R-~AY-t994 09:09 PAGE: 20 TCr~ D.,.'D 1 1!253,744 TCFO.TD1 IMND.,'D1 166 S. 7 R. 6 INFU. TD1 PN7 .TO! 5rtl. 30~ RR~11.TLT~ 1490.z~5 ~2 R~IS.TD! 3n8.1~5 P~ 6.TD1 PF3. TD! 240. 255 RF4. ~FT. TD~ 129. 368 RFS. ~lt .TD! 34! .062 RF12.TD1 R~IS.TD1 78.965 PFlb.TD! CC~.WD~ O.OOo 2639.!50 TSCN.tD! 364.80a RN1.TDI 14i4.650 RN5.TD1 RO9.~l~ RM9.TDI 1~9.~94 RN13.TD1 ~73.790 ~FloTD1 294.019 RFS.TD1 299.059 RFg. TD1 ~8~.q78 RF13.TD1 S0.6~5 GR,TDI ~46.t64 TSCF.TDI 947.581 RN2.TD~ 1337.~65 1339.o4~ ~o.~ 7~?.ao~ ~4.~ ~90.659 RF2.TD~ 314 ]80 RF6 TD! 7o.ooo ~S.T[~ 238,747 11.4,552 1189,516 1256,720 460,349 18.9~0 248 656 325~941 107,527 1495,000 **** FII, E TRAI[oER **** FTL? NAMg : EDTT ,005 DATM : Q4/05/ 5 M~X RFC $~ZF : ~024 FILF TYPE : ~,0 FILM ~AME ! EDIm 006 SFRVlCE VFRSIO~ : O01C01 DATF : 94/05/ 5 M~X RFC SIZ~ : 1074 F~bF TYPE L~$T FI[,,E : RA.W CURvEs Curves an~ lo~ D ~PTh I C FTLF: VENDOR TO~I~ Cf]DP] , ~ ~ LOG .,,.LADE~R ~AT.A ',' ,-,, .. ,3 'F . .... header data 2 for each START DgPTH pass in, seParate STOP 09 24 ' N A R - 94 38,2 files; raw background pass in last: IS Tame Veri[tcation List. in(~ CblUmberqer AlasKa Co,~putJ. n~ Cent:er ~D bOGG~P(FT): · ~P LOG TNTERVAL (ET): BOT~O~ bOG trio!, $~RI~G ~{~PO~ TOtaL C~D~ TOOL TyP~ ThTP THERi~AL D~CAY CART. TnTP TgEPM~L DFCAY DETECTOR TDTp TDTP TDTP TDTD S ~750 6553.0 6442.0 6100.0 6435.0 600.0 24-~AR-94 TNC-P-50 TND-P-78 TMEP~iAL DECAY GENER,{TOR TNG-P-21 TNER~;Ab DECAY TIM~ ATC-CB-1199 COL~,AP LOCATOR CAI..,-U 8 AUX. mBLE~ETRY ~ODULE AT~-~A-374 ~O~EgOLE AND CASING DATA 9m~:M MOLE BlT SIZE (IN): ~RILLER$ C~$!NC DEPT~ LOGGERS CASING DEPTH P, ORE,~OLE CO~iD1 Tir3NS FLUTD TYPF: SURFACE TEaPERATU~E (DEGF): bOTTOU HOLE T~bPE~ATURE (DEGF): FLUID SALINITY (PPN): FBI.lID I.~EVf;[.,, {F'T): FbUID R.~.T~.~ ~T ~¢ELLMEAD [~A',!J~R CUTS (PCT): GAS/OIL RATIOI CHOKE (DE~): N Et{!iTP()N TOOb TOOL TYPE (EPiTF~ERNAL OR ~,'!A'I'RIX DENSITY; !'{~l.~ CORRECTION (la): 3143.0 gRINE ~1,70 '9 0 1. 65 ~ .0 THERMAL SANDSTONE 2.65 BI,UEL!NE COUNT RATE NOR~ALIZATtON ig OIL Z~ME TOP NORM,~L!ZINf.,' WINDOW (FT): PASE NOR~ALIZIMG ~%~!DOW (ET): BbUEI, INE COU~T RaTE $CABE$ SET BY FIELD ENGINEER FAP CO!!NT PATE !~a~ SCALE (CPS): 0 FAP CO!iNT PATE HIGN $CIL~ (CPS): i2000 ~!E~R COUNT RATE l,OW SCALE (CPS): 0 ~,~E~R COUwT R~TE ~,~ICH SCALE (CPS): 1~00 WOOb 8TA~',.~DI~F? (IN): PAGE: 21 I$ Tame Verification Listing chlumherqer ~.laska Computir:q Center RWt,~aRK$: 'rTgD !,~'rO CBT ~t~?,~ 3 PaS~gg ~ 60O L78 ~OR~,-~AT DATA g-~AY-1994 09:09 PAGE: 22 ** r'ATA FnR~,AT SPECIFICATIOn; PECOPD ** ** SET mYPE - 64Eg ** TYPE RFPR CODE VALUE 1 66 0 2 66 0 3 73 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT i! 66 3 I3 66 0 14 65 PT 15 66 68 16 66 1 0 66 ** SET TYPg - CHAM ** NAM~ SFRV OMIT SERVICE APl API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDEP # LOG TYPE CLASS MOD NUmB SAMP ELaM CODE (HEX) ..... ...... . ..... ..... .-.-,...,......................,........,,....,.. ~r 480 0 0 O0 I ! 4 ,~, 000 DEPT '~' . , O0 ~ 0000 SIGM TD2 STDT TD2 TPHT TD~ SF~P TD2 SBH~ $~H~ TD? FTDT NTDT AFF~ TD2 ARFD TD2 AFND TD~ ABN~ TD2 SIGC TDP CU 480694 O0 000 O0 0 6 1 I 4 68 480604 O0 0()0 O0 0 6 1 i 4 69 PU 480604 O0 000 O0 0 6 1 1 4 68 V a80694 O0 000 O0 0 6 1 1 4 68 CU 480694 O0 000 O0 0 6 ! ! 4 68 CU 480604 O0 000 O0 0 6 1 1 4 68 CU ~80694 O0 000 00 0 6 I I 4 68 CU 480604 O0 000 O0 0 6 I i 4 68 CPS 480694 O0 000 O0 0 6 1 I 4 68 CPS 48069~ O0 (.}00 O0 0 6 1 1 4 68 CPS 480694 O0 OOO O0 O 6 1 i 4 68 CPS 480694 O0 Of)() O0 0 6 I 1 4 68 CPS 480694 O0 000 O0 0 6 1 I 4 68 CPS 480604 O0 000 O0 0 6 I t 4 68 CU 480694 00 O0O O0 0 6 i i 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS ~a~e Verification L£stin,..! ch].umberger AlasKa Comp~ti~ Ce..nteT a-~hY-1994 ~9:09 PAGE~ 23 TD S~BN mD2 CU 480694 SQST TD2 CU 4~Obg4 BICK ~'~2 CPS 4~0b94 F~AC TD? CPS TCA~l TD2 4806g4 TCA~ Tg? 480694 TCN~ TD? CPS a80694 TCF~ TO2 CPS 1~06Q4 TSC~ 7'D~ CPS INND TD? CPS 4~0694 lWF~ TD~ CPS 4806~4 RN1 TD? CPS 4806~4 R~2 ~D2 C~5 a806~4 RN3 TD2 CPS 480694 R~4 TD2 CPS 480694 R~!5 TD2 CPS 4806q4 RN6 "'D~ CPS 4~0694 R~8 TO? CPS 480694 RN9 TD? CPS 480694 RMIO ~D2 CPS 48o604 RNlt TD2 CPS ~80694 R~i~ TI)2 CPS a8o~94 RNI~ TD2 CPS 4806~ RNI5 TD2 CPS 480694 RFI TD2 RF2 TI)2 CD5 RF3 TD2 CPS 480604 RF4 TD2 CPS 4806~4 R~5 TO2 CPS 480694 RF6 ~[)~ CPS 480694 RF7 mD2 CPS RF8 Tt)~ CPS 45069R R~9 ~D~ CPS 4806g~ RFiO ~D~ CP~ ~8069~ R~i~ TD2 CPS 4806~4 RF12 TD2 C~S 4~()bg4 RFI3 TD2 C~$ 4~0694 R~!4 WD2 CPS 4~0694 R~i~ TD2 CPS ~80694 RFI6 TD2 CPS 48069~ G~ TD? GAP! 480604 TFN~ TD2 hg ~80694 CCh Ti)~ V 480~94 LOG TYPE CLASS 00 O00 00 oO 000 O0 O0 000 00 O0 COO o0 0 000 00 O0 O00 00 O0 gO0 O0 o0 000 O0 O0 ',3,00 o0 O0 000 00 oo 000 00 O0 CO0 00 O0 000 O0 O0 000 O0 O0 000 O0 00 O00 O0 00 000 00 O0 000 O0 0 () 0 (.) 00 O0 000 O0 O0 000 O0 O0 000 O0 0 000 00 O0 000 O0 00 000 O0 O0 000 O0 O0 900 O0 O0 000 O0 O0 OOO O0 o0 000 O0 O0 000 OO 00 000 O0 O0 O00 00 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 00 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 O0 O0 000 00 O0 000 O0 oO 000 O0 00 000 O0 O0 000 O0 00 O o () 00 0 6 I 1 0 6 I 1 0 6 1 1 0 6 1 0 6 1 1 0 6 1 0 6 1 0 6 1 0 6 1 1 n 6 1 0 6 1 1 0 6 ! 0 6 1 1 0 6 I 0 6 1 1 0 6 1 1 0 6 1 1 0 6 1 I 0 6 1 1 0 6 1 0 6 1 0 6 1 1 0 6 1 0 6 i 1 0 6 I I 0 6 1 0 6 I i 0 6 1. 1 0 6 I 1 0 6 1 F'II,E . NUIV!B SI E RF,.PR PR C SS NUMB SAI'~P EbKb! CODE (HFX) 0 6 I ! 0 6 1 0 6 1 ! 0 6 1 1 0 6 I 1 0 6 I 1 0 6 1 0 6 I 1 0 6 I 1 0 6 I 1 0 6 i 1 0 6 I l 0 6 1 0 6 1 0 6 1 0 6 1 0 6 1 0 6 1 1 0 6 i 1 4 68 0000000000 4 68 O00OO00000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 O00OO00000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 OOO0000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4. 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 4 68 0000000000 IS Tame Verification t.i$'ti, nq chlum~eraer AlasKa Comput!ns Center DF.pm. 644o.5,~0 S iGi~i. %~D2 ISHU.Tb? 1~.219 SFFO,TP2 SB H ~' Th2 63.8~5 FTDT.TD2 A~Fn:TDP ~2.g36 ~FhD.TD2 sTBU.wD2 i~ 1.7BO ~.~OF.TD2 B~C~.T02 ].~1,919 FSAC.TD2 TCND.TD2 11253.744 TCFD,TD2 IN~n WDP 1668.78b !i~Fg. TD2 PN3:TD2 ~207.3~ RN4.TD2 ~47.TD~ 696,U23 R~8.TD2 R,Ol ! 'TD~ ~ 73'1.689 PN12.TD2 R~,~ 1. 5 TD~ b06,061 R~!6.TD2 D~'3 ~ TI)? 269. 886 R~4.TD2 RF7. TD2 269.8 ~ RFS. TD2 RWll .TI)? 459.290 ~F12,TD2 RWI~.TD2 41. b.b67 RF16.T02 CCt.. TD2 0. gO0 DFPT. 6400.000 $IGM.TD2 I $ H U ' · !) 2 ? 4.. '1 g U S F F D. T 92 S~}!~.' i T[)~ 57,875 FTDT.TD2 A~,Fn TDP 87.277 ~F~D.TD2 SI~W,TD2 Q4,336 ~.~MOF, TD2 BACK,mD~ IP4.78~', FY~AC.TD2 TCND TD2 1.4503.6~0 TCFD, TD2 IMN~'TD2 1.5~0.063 INF~,TD2 ~, 3 ~ TD2 1 122.159 RM4, TD2 ~N7, T92 842.803 R~8, TD 2 TOP 19~9,102 ~N]2 TDP ~IS,TD~ 623.422 ~ N ~ 6.,i'~2 F3.~D2 242.034 RF4 TD2 ~F7,TD~- 212,929 RFS]'r~2 NFl,. D? i47,059 PF16. ....... CCL.TD~ O.OO0 DEPT, 6200,0~0 I $ H -'J, T l.J 2 20, g 28 $ F F i), T D 2 SIB~,TD2 102.0~9 BAC~.' o~ 145 700 F~3~C T92 .TD2 10952'871 TCFD[ 7~'D2 IC~.~t) TD? t682 552 I?~Fb TP2 . ..... , . TO 2 PN3 TD9 968 137 'i'g 2 ~N7, T[)P 603.554 RN8 R~I 1 .TD~ ! 469.0K6 RN~ 2.TD2 PFc. TD~ 217. 262 RF4, TD2 PFT. mi)2 i ~ 4.5g 3 R. F8. TD2 RFll ',.L),. 334 821 ~FI2.TD2 RFI5 TIJ2 96 720 CCL~bP 0.000 S-~AY-1994 09:09 42.857 STDT.TD2 66.000 43.552 SF~D.TD2 45.182 2.289 MTDT.TD2 8.412 385.601 AB~D.TD2 369.976 !.026 TRAT.ID2 1.685 23.591 TCA~.i, D2 38247.031 263g.150 TSCN.TD2 846.164 304.009 RMI.TD2 932 765 1520.356 RNS,TD2 1396~780 819.!29 R~9.TD2 1505.68~ 1406.25~ ~N13.TD2 1136.364 667 614 RF1,TD2 298.295 331~439 RFS.TD2 345.644 250'947 RFg'TD2 37~.788 416.667 RF13,TD2 416.667 459.280 GR.TD2 588.500 30.170 STDT.TD2 30.451 SFND'TD2 4,200 ~TDT.TD2 384.402 ~[~ND,TD2 0 965 TRAT,.TD2 28~93 TCAN,TD2 3586.255 TSCN.TD2 362.840 RNi,TD2 790.. 0 ~9,, D' TD2 1773,990 R~!13,'~....2 546.086 RF1,TD2 300.~45 RFS.TD2 287,990 RFg,f 2 424.326 RF!.3,TD2 111,~26 GR,Tb2 44,162 STDT.!TD2 44,676 SF~4D.T02 2 ~89 NTDT , ...,TO2 351.63~ ~BND,TD2 I,I08 TRAT,TO2 30,817 TCAN.YD2 2369.333 TSCN.TD2 33~.279 RNI,TD2 1309,742 RNS.~D2 g21,07~ R'N9,TO2 1162,684 RN13,TD2 598.g58 RFi.TD2 267,857 RF5,T~2 284,226' RF9,~D2 267,g57 RF~3.TQ2 ~05,655 GR,TP2 66.000 32.823 14 198 !.888 45367.~05 1965.981 935'922 1470'959 153~51~ 1469~381 304.841 326.287 402.880 389,093 112,750 66~000 44 373 8,796 343.845 1,886 40143,711 900,894 880.821 1289 828 833.333 25! ~39 583 ~73 810 184 524 92.063 TPHI.TO2 SBHF.TD2 AFFD.TDP $IGC.TD~ 5DSI.TD2 TCAF.TD~ TSCF.TD~ RN2.TDP RN6.TD2 RMIO.TD~ RNI4.TD2 ~F2.TD2 RF6.TD2 RVIO.TD2 RF14.TD~ TENS.TD~ TPHI.TD2 5BHF.TD2 AFFD.TD2 S!GC.TD2 SD$I,TD2 TCAF.TD2 TSCF.TD2 RN2.TD2 RN6,TD2 RN10.TD2 RNI4,TD2 RF2,TD2 RFG.TD2 RFIO.TD2 RFi4 ..'D2 T~NS,TD2 TPHI.TD2 SBHF,TD2 AFFD.TD2 SIGC.TD2 SDSI,TD2 TCAF,TD2 TSCF.TD2 RN2,TD2 R~6.TD2 R~IO,TD2 RN14,TD~ RF~.~D2 RFG.TD2 RFIO.TD2 RF14.TD2 TENS.TD2 PAGE: 24 61.534 56'869 67.826 0.731 0.614 9748,389 238.747 180,600 1240,530 1354.167 738.636 118.680 369 318 383.523 12!5,000 52,061 50,189 67,898 0.720 0,416 13371,664 626,804 131.,580 1395,202 1459 911 ,ooo ~9 323 223 379 902 249 694 1595:000 74'553 57:127 64 612 0 069 0 669 9641100 225.760 154,800 !.153'492 1211'703 560.662 30 960 23 :119 27~ 21 120 1560 000 IS Tape veri£ication Listtnq cblumher~]er AlasKa Computlno, Center ~-mAY-t904 00:09 PAGE: 25 DMPT. 609o.©00 $iG!4.TD2 ISHt~ TL)2 22.547 SFFi). T~2 SBH~:TD? 63.792 FTDT,TD2 ADFP,T[;2 ~! ,204 ~F~'JD, TU2 5I BP, TI..)~ 1!1,462 B~.CW.~D? 149.561 ~3~C.T02 TC~m.TD2 116~9.0o6 TCFD.TD2 I~[.in, TD? 1710,705 ~Nw[).TD2 ~N3.TD2 ! 136.642 RN4.TD2 ~NT. ~D~ ~21.936_ R 5~ 8. ~. ~ z R~ll _b2 !,557.90~ ~N12 7D2 R~'IS,T!)2 548.407 ~N1,6.TD2 ~F3 wi')2 232.008 RF4.TD2 ~ 7 [Ti)2 1~.3,624 RFS,T~2 RPll ,TD2 389.836 RF!.2,TD2 PlS.~b2 102.5.8 ~F!,6.Th2 RCCt,, T~ 2 0.00 a 45.079 STDT.TD2 66.000 TPHI.TD2 67.505 45.602 SFND.TD2 45.525 SBHF.TD2 57.635 ~.391 MTDT.TD2 8.829 AFFD.TD~ 77.5~3 397.777 ABND.T~2 377.642 SIGC.TD~ 0.143 1.075 TPAT.TD2 1.742 SD$I.TO~ 0.711 32 576 TCA~.J.TD2 43356.477 TCAF.TD2 11041,963 2694~230 TSCN.TD2 ~ 881.414 T$CF.TD2 237 949 367.872 RN1.TD2 891 544 RN~.TDP 164:088 1446,o7~ RN5.TD2 1372[549 ~N6.TD~ 1210. 171 830 ~70 R~g,T92 1398.591 RNI0 TD~ 1279,105 1233~'!49 ~N13,TO2 795.037 R~!14:~TD~ 55~.002 621'936 RFI.TD2 301.452 RF2 T02 26.316 306 187 RF5 1'.~2 288 826 RF6~TO~ 254 i04 303.030 RF9oT02 347.222 RF10.TD? 306~187 ~95'~39 RF~3,TD2 ~05.~77 RFI4.TD~ 121; 127.84l GR.TO2 99.313 TENS.TD2 !570,000 ** E~'q.D OF DATA ** **** FTLE ,~RAiLER **** FTLF t'-~A?-~g :MDIT .006 S~RV!CE : FL!C V~RSION ..'. o0!C01 D~T~:: : 04105/ 5 FIbM TYPE : LO **** FTLE NEADEA FILF MA~E : EDIT .00~7 SFRVlCE : FLYC VFRSIO~,~ : O0~.COI D~T~ : g4/05/ 5 M~X REC SIZE : ~.024 F'ILF TYPE : LO L~S~ F~' . .T.:,E ' FTbF NEADF,:R FTLF ~i L!~r'~ $ E R R.~ CURVES Curves and log DEPTi.i I NCRE]t~E~T: F!bF Si, j~NARY 7 header .data 3 0,5O00 for each Pass in separate files; raw baCkgrot~Dd pass In last STOP DEPTM IS Tane Veri£1cat!on [,ist.ino chlumherger h,~asK, a Cor~putl, no Center ~-~AY-!9q4 09:09 PAGE: 26 ~4-~A~-94 38.2 1750 24-~AR-94 T,OC(iTNG SP~gD DEPT~ CONTROL I!SED (YES/NO): TOOL STRING (TOP TO BOTTOm) V~t~DO~ TOOL CODE TOOL TYPE TOTP TDTP T~T~ S~OPE~OLE ANO C~SlNG DATA OmEn,! HOI,E BIT SIZE D~ILI.,E¢S C~SIN~ DEPTH (FT)I [:OGGERS CASI~G DEPTH (FT): ~OPE~OLE CONDiTIOi~$ ffLU%D TYPF: FLUID DENSIT~ (LB/G): SURFACE TEmPERATUrE (DEGF) BOTT[)~ ~DLE TEi;~PERATUPE (DEGF') F'I,IJID SALINITY (PPM) VL!!ID LEVEL (FT): FLUID RATE ~T WELL}..i~AD (bP~): W~TER CUTS CHOKE (DEG): 6553.0 6442.0 6100.0 6435.0 600.0 TOOL NUMBER THEP~!AL DECAY CART. THC-P-50 THERMAL DECAY DETECTOR THO-P-78 THE~H~b DECAY GENERAT~R TNG-P-¢I THED~AL DECAY TIME ATC-CB-I199 CObI,~R LOCATOR CAL-!!B AUX. TELEMETRY NODULE ~T~-AA-374 3143.0 165,0 ~JEUTRON TOOL TOOL TYPE aATRiX: BI,UE[.,INE COI. INT RATE NOR~.~A!~IZA. TION iN OIL ZONE TOP N[iRYi. lb!ZING WINDOW (FT): ~ASE NOH:~,~ALIZIK~G ~INDOW (FT): THERMAL SANDSTONE 2.65 IS Tane Yeti fi. cation l,isti, no chlumber~.~-r AlasKa comp,]tigo Center ~'AP C[.]~]b~T UA~'E LOw SCALE (CPS): ~"AP CO~[';T ~AmE HIGH SC.SbE (CPS): HE~R COu~.~'I' ~3'E LOW SCALF (CPS): ~Ea? C~13"~'f RATE HIGti SCALE (CFS)~ TOOL S~A~DOFF (tM): RFB~5: TTE~ Ii,~T(] CBT 3t20/q4, $ # LIS FOR?AT DATA 0 200O I~00 PAGE: 2¸7 ** DATA FORMAT SPMCTFtCATION REC'~"[). D ** ** SET T~PE - 64E~, ** ';~;~''''''''''';'~~P~ C D , ..... '''~['V~L_ i. 6b 0 2 66 0 3 73 260 4 66 5 66 6 73 7 65 8 68 0,5 9 65 PT 1~ 66 3 I? 68 13 66 0 !4 65 15 66 68 16 66 0 66 ** SET TYPE - C{~AM ** N~ ~ Sv~v tin S~:~VICE ........... APl FI lC NUMB MB SI R PR P~OCE ID COROE'P ~ bOG TYPE CL~$S MOD ~UMB SAMP ~bEM CODE (HEX) .,,,,.-..--.-,,----.--...-,,-.--.-.-,,..-- .... ........................,...........,.... . 480~94 . 000 0 7 ! i ~ 6 0000000,00 Sl(;~ TD3 CU 480694 O0 000 O0 0 7 i i 4 68 0000000000 STD~ TD3 ~80094 O0 000 00 0 7 1 1 4 68 0000000000 TPHI TO3 plJ 480694 O0 000 00 0 7 I i 4 68 0000000000 ISB{I TD3 V 480694 O0 000 O0 O 7 I I 4 68 0000000000 SFFD ~,93 CU aSO604 O0 000 O0 0 7 I 1 4 68 0000000000 SVN~ Tf)3 C{) 480604 00 000 00 0 7 I I 4 68 0000000000 SBHv TV3 CIl d80694 O0 O00 O0 0 7 1 I 4 6~ 0000000000 SBH~ TD3 CU ~O604 O0 O()O 00 0 7 1 1 4 6~ 0000000O00 IS Tane Verification l,istino cblumberqer ~].asKa Computi. n~ Center g-MAY-Iq94 09:09 PAGE~ 28 ID ORDER , bog TYP~ CbASS MUD ~UMB SAng ~bg~ CODE (H~X) '~;~;';~i. .... ~;~''~';~ .................. 694 00 00(, 00 '''~ ............................. 7 1 t 4 68 ' ........ 000000;000 ' N?D? ~D3 C~& 4g0004 O0 000 O0 0 7 A~FD TD3 CPS 480604 O0 0o0 O0 AFND TD3 CPS ~80694 00 000 0O n 7 1 1 4 68 ABN9 TDB CPS a~06o4 00 On0 STGC TD3 CU 4806~4 00 000 O0 0 7 ! i 4 68 $IB~ TD~ CU ~80694 00 000 00 0 7 1 1 4 6~ M"O~ TD3 .4~0694 00 000 00 0 7 1 1 4 68 T~A? ~D3 480694 00 000 O0 0 7 1 i 4 68 SDSI TD~ CI.! 480694 00 000 0O O 7 1 1 4 68 BAC~ TD3 CPS ~80604 O0 000 O0 n 7 1 I 4 68 FBAC WD3 CPS 480694 00 000 TCAN TD3 48~694 00 000 00 0 7 1 TCAw ?D3 480694 00 0OO 00 O 7 TCND TD3 CPS a80694 O0 000 O0 0 7 1 1 4 68 TCF~ TD3 CPS 48o604 00 000 O0 0 7 1 ! 4 6~ TSCN wD3 CPS 480694 O0 000 O0 0 7 1 l 4 68 TSCW TD3 CPS 480694 INND TDB CD8 4~O694 00 OOO 00 0 7 INFD WD3 CPS 480694 00 000 00 0 7 l I 4 68 RNI TD3 CPS 48o6~4 O0 000 00 0 7 1 I. 4 68 R~2 TD3 CPS ~806~4 00 000 O0 0 7 1 R~3 TD3 CPS 480694 O0 O00 O0 0 7 I i 4 68 RN4 TD3 CPS 480604 O0 O00 00 0 7 !, I 4 68 R~5 TD3 CPS ~80694 o0 000 O0 0 7 1 1 4 68 RN6 TD3 CPS 48o604 00 O00 00 0 7 I 1 4 68 R~7 TO3 CPS A~06q4 O0 CO0 O0 0 7 RN8 TD3 CPS 480604 O0 000 O0 O 7 1 I 4 68 RN9 TD3 CPS 480694 O0 0o0 00 0 7 I 1 4 68 R~10 TD3 CPS 4806°4 00 000 00 0 7 1 I 4 68 RNI1 TD3 CPS 480694 O0 000 O0 0 7 RNI~ mD3 CPS 480694 00 000 00 0 7 1 I 4 68 RNI3 TD3 CPS 480604 0O 000 Rg~14~l TD3 CPS 480694 O0 000 00 0 7 R .... 5 ~1)3 CmS 480~94 00 000 00 0 7 I I 4 68 R~16 TD3 CPS 480694 00 000 00 0 7 ! 1 4 68 R~I TD3 CPS 480694 00 O00 00 0 7 1 1 4 68 RV2 TD3 CPS 480694 00 O00 00 0 7 RF3 TD3 CPS 480694 O0 OOO O0 0 7 ! t 4 68 RF4 TD3 CPS 48~6o,4 o0 000 00 0 7 I i 4 68 RF5 TD3 CPS 4.80694 00 000 O0 0 7 RF6 TD3 CPS 480 Q ,. o. 4 R P 7 · D 3 C P S a 80604 00 RF8 TD3 CPS 480604 00 000 00 0 7 1 I 4 68 RF9 TD3 CPS 480694 00 000 00 0 7 RPI0 TD3 CPS .480694 00 000 00 0 7 1 I 4 68 RF1... ! TD 3 ~P" .. c..,a ,a80604 O0 000 00 0 7 1 1 4 6~ R~I? ~[)3 CPS 480604 O0 000 00 0 7 I 1 4 68 R~I3 TD3 CPS 4806~4 OO 000 00 0 7 I I 4 68 RFi~ !rD:3 CPS 480694 O0 000 00 0 7 1 I 4 68 O000UO0000 OO00000000 000~000000 0000000000 0000000000 0000000000 0000000000 O00000000O 0000000000 0000000000 0000000000 0000000000 000O000000 0000000000 0000000000 0000000000 OOOO00000O 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000OO000 0000000000 0000000000 0000000000 0000000000 OOUO000000 0000000000 0000000000 0000000000 IS Tape Veriftcatlon I:istin~. CblUmberg.~r Alaska ComDutlnC Center g-~AY-19g4 09:09 PAGE: 29 NA. K SKRV SERVICE A i APl APl A FILE N B NUM REPR HO..ES6' C TD ORDER ~ bOG TYPE CLASS ~OD NUmB Sh~P ELEN CODE (HEX) '[;:'';5 .I)3 ...... [;~''~.. ....... 80~a4 ;0 000 O0 0 7 : ...... 1' .... ~ ........... 68 ;~''~;;~;''00 RF16 TD3 CPS 480694 gO 000 O0 0 7 1 1 4 68 0000000000 G~ TD3 GAPT aSO694 O0 000 O0 0 7 1 ~ 4 68 0000000000 T~N$ TD~ LB 4806~4 O0 000 00 O 7 1 1 4 68 O00OO00000 CCL ~D~ ~ ~80694 nO 000 00 0 7 1 I 4 68 0000000000 DEPT 6449.000 SIG~ TD3 45 079 STDT TD3 66 000 ISHt,[TD3 27.766 SFFD~TD3 451662 SFND~TD3 451525 SRH~~ TD3 63.792 FTDT.TD3 2.391 s~TDT,TD3 8 829 ABFD~TDi~ ~1,294 AFND.TD3 397,777 ABND.TD3 377~642 SIBW TD3 1~.1.462 ~MOF,TD3 !,075 TRAT,TD3 I 742 B~CW~TD3 1~9.561 FBAC.TD3 3~.576 TCAN,TD3 43356~477 TCND,TD3 11639.096 TCF[),T~3 2694,230 TSCN,TD3 881.414 I~ND,TD3 ~7!0,705 INFD,TD3 367 ~2 R~I.TD3 928.030 ~N3 TD] ~.145,833 RN4.T~3 1477:z,2 R~5.TD3 1339 962 ~NT[TD] 8P8.598 R~8'TD3 a04.924 RNg'T~3 1444[~29 RNll TD3 1728.2~9 RN~2.~3 i482,007 RNI3.T93 1~35.795 ~IS'TD] 762,3~! ~N16 TD3 790.720 RF1.TD3 303.030 RRF~'TD3 2t7.803 RF4~TD3 307,765 RFS,TD3 350.379 ~Fg~T~3 175,~89 RFS,TD3 ~60,417 RFg,TD3 364'583 arl~ TO~ a~l 401 afl2.1.3 421. 401 ~F~3.TD3 326.705 F15 TD] 208,333 ~FI6.TQ3 217.803 GR.TD3 19S.125 RCC[.[TD~ 0.000 I 3 30.535 ,_TD!,.TD3 66.000 SBHW'TD~ 56 1~3 FTDT.TD3 4,146 NTDT.TD3 1.4.e13 A~Fn~T[)3 85[65:0 AFND.T~3 356,33~ ABNb. TD3 390.36~ S!B~.TD3 ~9.293 ~,~MOF, ~. D3 1.045 TRAT,TD3 ~.991 BAC~'. TD 3 154,223 FBAC,TD3 35 409 TCAN,TD3 44199.898 ~'CND,TD3 14344.598 TCFD TD3 3505 6~1 TSCN ~-3 2023.975 INND.TD3 1641 993 INFD,TD3 350 853 RM1,TD3 923,~95 ~NB.TD3 ~073 232 R~'4.TD3 1477 27~ RNS,TD3 ~46~.490 PN7.TD3 8~4 394 RMS.TD3 831.755 RMg. TD3 1450.44~ RNll.TO3 ta75.000 R~I2.TD3 1649.305 RNI3.TD3 1343.118 5 RS'IS,TO3 6a0 2 ,0 r~N16 TD3 658&:i44 RF1,TD3 281,] 76 F3,TD3 240 8~5 RF4 TO3 288 086 RF5,~.3 323.893 479 RFg.TD3 372.721 F7,TD3 !~7.~74 RFS.TD3 299'.. ~9 ~F13 TP3 123,~13 RFI1,TD3 496.654 RF1.2.TD3 a2~.5~ .T~3 387.~ 70 RF1$.~D~ 169 271 RF16 7 3 126 95~ Ga,_ .,CL Tf)'.~ 0 000 DKPT 6200 ()(~O SIG'{~: TD3 43.995 ,.TD: ~..3 66 000 iS~!','Tt)3. 29.9~8 SFFt).TD3 44.1il SF~D.TD3 .... 44~55:3 SBH~ m!:723 61.448 FTDT.Tr)3 2,~.51 "O , . . ~ ~,~.T.-. T TD3 a. 807 ABFD,TD3 69.873 aF~D,TD3 364,390 hB~D,TD3 342,597 STB~'.T['~,3 10~1.077 ~Ii'qOF.TD3 I.~.6I TR ~ T93 !.929 TPHI.TD] SBHF.TD3 AFFD.TD3 $IGC.TD3 SDSI.TD3 TCAF.TD3 TSCF,TD3 RN2,TD3 RN6 TD3 R~10 TD3 RN14 TD3 RF2 TD3 RF6 TQ3 RF10 TD3 RFi4,TD~ TENS.TD3 TPMI.TD3 S~HF.TD3 AFFD,TD3 SIGC.TD3 $D$1 TD3 TCAF TD3 TSCF TD3 RN6 TO3 RMIO TD3 R'MI4iTD3 ~F2 TD3 RF6.TD3 RFI0.TD3 RFI4.TD3 TKN$.TD3 TPM!.TD3 SBMF'TD3 AFFD,TD3 $!GC.TD3 SDSI.TD3 67 505 57!635 77 513 0.½43 O. 1! 11041.963 1.240 ~306'8~8 866,477 56 760 321 970 317 235 1175 0 916 647 12520'014 6031620 148.,608 1399,937 1,458.333 893'~08 ~9'.40 305.~990 348,307 255,534 1490'000 77'260 54~9i5 63,1 6 0.1 9 0,680 I$ Tame Ver~fI. cation tist~n~ chlumberger AlasKa Computino Cemter BACK.Tm] 165.3R8 FBAC.TD3 TCI.~D. Tm3 !O944.6,~4 TCFD.T!'~3 INN~.TD3 16~9,390 INF[),TD3 ~N 3,Tm3 999. 349 R~'.~4.TD3 ~N7.TD3 603,8~1 ~.~g. ID3 RNI~.TD3 1494,~0 RNI2.TD3 RS~lS.~D3 572.9~7 ~N~ 6.Tm3 ~F3,TF3~ 199,933 RF4.T~)3 ~F7, TD3 196.00~ RFS,TD3 Rwli .Tm3 399.30i RF12.TD3 RF15.Ti33 124.3~8 ~FIO,Tn3 CCT,. TD] O. 000 DEPT, 6050.000 $IGM.TI)3 iSRTt.TD~ 41,219 SFFD.TD3 SBH~,'rD3 62,272 ~'TDT.TD3 ARFD,TD3 84,464 AFNt).TD3 SIBW.TJ)~ 107,061 ~MOF,TD3 B~CK,TD~ 169,957 F~)AC.T93 TCND,T!)3 1~935,26~ TCFD't~3 iKtND.TD~ ~698,4q4 TNFO.T~3 N3,T[33 ~ 202,957 RN4, RMN7, TD3 655. 242 RNS. TP3 1~ .TD3 1606,1~3 ~F3 TD3 253.906 ~FT~TD3 138,346 RFS.'i'D3 RFI! ,TD3 3~2,4~7 RFI2.TD3 RF15 '~[)~ 1~3,932 ** E~',!D OF DATA ~-~A¥-19q4 og:0g 33.~i3 TCAN,TD3 36897.742 236~,1%0 TSCi~,TD3 898.414 330.87? ~N!,TD3 833.333 1287.552 RMS.T~3 1279.297 8i8,685 R~!9,T~3 134~,146 1173.502 ~N13.TD3 846,354 6~4 06~ RF1.TD3 ~38.575 246:g7g R75,TD3 957,056 270,497 RF9,TD3 310,~20 265.457 RF13,TD3 ~8~,459 ~24.328 GR.T~)3 117.813 43.3~0 STDT,TD3 43.7i3 SFND.T03 2,676 398,789 ABND.Ti)3 1,057 TR~.T,TD3 2~.6~4 TCAN,TD3 28i6.633 T$CN,TD3 385.548 1463,374 RNS,TD3 a!4.85~ RMg,T93 1273,521 RN13,TD3 730,847 RFt.TD3 325.521 RFS,TD3 330,404 RF9,TD3 t26,953 GR.TD3 66,000 44 759 g:104 386,638 1 650 40457!445 924 477 937 500 1416,331 873,656 294,596 302,734 349.935 ~09.961 ~.813 TCAF.TQ3 TSCF.TD3 ~N2.TD3 RN6.TD3 R~!IO.TD3 RN14.TD3 ~F2 TD3 ~F6~TD3 RFi0.TD3 RFI4,TD3 TENS,Tm3 TPHI.TD3 SB~F.TD3 AFFD.TD3 S!GC.TO3 SD$I.TD3 TCAF.TD3 TSCF.TD3 RN2.TD3 RN6.TD3 RN10.TD3 RMI4.TD3 ~F2.TD3 RF6,TD3 RFI0,TD3 RF14.TD3 TENS,Tm3 PAGE: 30 8512,564 221,666 177.160 !108.398 !206,055 587,565 25 800 278,898 119,288 1555,000 59,712 58 30O 74:163 0,449 ,678 1065 ,695 278,237 178,880 125~,680 129 '323 594,758 26,316 284 831 296~224 123.698 1500'000 **** FTbM TRAILER **** FTLF NAME : EDIT .007 SERVICE VMRSIO~ : 00!COl DATE : o4/05/ 5 ~X aEC SIZE : i024 FIL~ TYPE LAST FILE SFRVIC~ b!a~,!E : DAT~ : 94/05/ 5 O~!GIN ~ WbIC T~PF MA~E : q4~50 CONTIN(JATIO~? # : 1 PPEVIOUS ~A~E CO~E~T : ~RCO ALASKA 3~ -26 , 50-I IS Wane ¥~rlf.icat~on List~.r~q chlumber~]er Alaska Co~,putJn~ Center PAGE: 31 COMPANY NAME : ARCO A6ASKA, ImC, FIE~D NAM~ : KUPARU~ RIVER BOROUGH~ : NORTH SLOPE STATE : AbASKA AP~ NOM~Eh : 50-10$-20~08 . RECEIVED MAY 0 9 1~!94 cblur~:herqer AlasKa Comk. uKih(~ Center 30-APR-1994 ].5:01 ~$~ REEL HEADE~ SERviCh NAME : EDIT D~TE : OR iG I ~.~ : FLIC COM[,4~NT : ARCO ALASKA INC,, KUPARUK, 3H - 26, 5002920208 SERVICf] NANE : EDII DATE: ORI(;I~ : FL, lC 'IAPE ~,;A~'~E : 94161 CONTINbATION ~ : 1. pReViOUS TAPE : CfJ~'~E[~T : ARCO ALASKA INC., KUPARU~, 3H - 26, 5002920208 TAPE ~EADEH CASED HOLE WiRELi~E LOGS APl NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: OOb hUMBER; LOGGING ENGINEER: OPERATOR WIT~]6S; SURFACE LOCATION SECTION: RAf~GE: F~b: FSI5: FEL: ELEVATIU[~fFT FROM MSL O) KELLY BOSMING: DERRICK FLOOR: (;ROUND bEVEl6: ~g~l, CASING RECUAD ~.ST STRING 2ND STRiP~G PRODUCTION 6TRING 3H - 26 5010320208 ARCO ALASKA, INC SCHLUMBERGER ~[;Lt~ S~RVICES 28-APA-94 9~101 G; dO~N~O~ dC PYRON 281 80, O0 80, O0 39,00 : OPEN HOLE CA~iSG i)RILLER$ CASING BIT SIZE (iN) SIgE (iN) DEPTH (FT) WEIGHT (bB/FT) '1,625 3143,0 29,70 5,500 61~.7,0 1,7.00 6.750 5'000 6640,0 18,00 CURVE SHIFT DAYA - ALL PASSE5 'lO STANI)ARO(NEASURED OEPTH) PAGE: IS Tape Verification l, iSting JO-AFR-1994 cblua~Der~:}er AlasKa Computi~]G Center ~[',WG TOOh CODE; C~T PA~S NUMBER: 1 OATE LUGGED: 2G-MAR-1994 LOGGING C~MPAN~: SCHLtJ~EERGE~ ~Ebb 15:01 .......... E~.UIVAL?:N~i UN~HIFTE[> DEPTH .......... BASELINE DEPTD GRCH C~TG 0378,0 6377.5 ~331.,b 6331,5 6323,5 6323.5 b320,5 6321,0 6308,0 0277.5 6277.5 6209,0 6268,5 6224.5 6224.5 0223.5 6224.0 6219,0 6219,0 6218.0 6218.5 0203.5 6~Og,O ~91.0 6190.5 0168,0 6168,0 o167,0 6167,5 ~146.0 6146.0 6122.0 6122.0 6121,5 6122,0 100.0 100.5 100,0 $ ALL $ $ DEPTH CORRECTION SHOWN ABOVE REFLECT CASED }'lObE GR (]PEN HOLE GR AND CASED a[JbE; ENPH TO OP~;N HObE GR. OT~iER CNTG CURVE6 ~ERE CARRIED Wilt'iq THE ENPH SHIFT8 PAGE: **** FIbE H~ADER Fl:bE NA~ : EDIT ,001 SERVICE : ~'oIC VER$I[]~ : OO1. COI DATE : 94/04/2~ MAX REC SIZE : 1024 FILE TYPf] : bO i~ST FILE Tape Verification L:istihq Chluff~k>erger AlasKa Computil'~q Center PAGE: 3 FILE NU.~qBER: 1 EDITED CbRVE8 Depth s~ifted and clipped curves for each pass in separate flies. P~S8 NOt~BE~: 1 DEPT~ INCREMENT: 0.5000 FILE SUMMARY [,D~G TOOL CODE, START PEP'IH StOP DEPTH mmeeeNmm mmN. ~m. m mmmmmmmmmmm mmmmmmmmmm 6RCH ~40u0 0100.0 CNTG ~423.0 ~1. O0.0 CURVE SHIFT DATA - PAS6 %:0 PASS(MEASURED DEPI'H) BASELINE CURVE ~'0~ SHIFTS LD~G CURVE PASS NUM~ER BASELINE DEPTH $ ......... -EOUIVA!,,ENT UN,SHiFTED DEPTti- ......... RE~ARK$: THIS FILE CONTAIN8 PAS8 ~1 [)~: '1'HE CN'i:G. NU PAS6 TO PASS SHIFTS WERE APPLIED TO TNI~ DATA, bis FORMAT DATA DATA ~OR.~A~ SPECIFICATION R"''' E,C, ORD ** *~ SET TYPE - 64gB ** 1 66 0 2 66 3 73 5 66 ~ 73 7 65 g 68 0,5 i1 66 16 !2 68 13 66 !4 65 FI 15 66 68 lb 66 i 0 66 0 IS 'rave Verification [.,istlnq chlU~,berqer AlasKa Computinq_ CeDter 30-APR-1994 15:01 PAGE: :SET I'NP~ - CNAN ** ''~;''~'i;'~N ........ ERVICE ~''i;i ....... APl ;~;'~i~[''~'';UM .............. NUMB SIZE ORDER ~ bUG 'iYPE CbA~S N~OD NUMB SAMP ELEM . ~m mm mm mm DEPT NPH! CmTG ENPH CPNI CNTG NRAT C~NTG 480455 CRAT CcutG ~V456 ENRa. C~TG ~80456 NCNT CNTG C~6 q80456 p'CNT C~TG CP6 4~0456 CFTC CNTG CP6 CNTC CNTG CPS CFEC CNTG CP~ G~CH C~TG GAPI ~80450 IENS CtuTG ~ ~4~0456 CCL C~TG V 480456 FT q80456 PU-S 4S0456 PU-S 480456 PU-S 480456 CODE O0 OUO OO 0 1 1 ! 4 ~8 O0 uO 000 O0 0 1 1 I 4 b8 OO Oo 000 Og o I 1 1 q b~ OU UO 000 gO 0 1 1 I 4 68 OO O0 ()00 ~0 u i I 1 4 b~ O0 gOO OO u I 1 1 4 b~ O0 O0 OOO O0 U 1 1 1 4 68 O0 000 O0 u i I 1 ~ ~8 O0 O0 000 go 0 1 1 ! ~ 08 O0 O0 000 oO 0 i 1 1 ~ b8 O0 O0 000 O0 0 ! 1 1 ~ b8 O0 Ou 000 O0 O 1 i 1 ~ 68 O0 UO0 O0 U 1 1 ! 4 b8 O0 O0 OOO O0 0 i I 1 ~ ~8 O0 O0 ogO GO O i 1 1 ~ b8 gO gO gOO O0 O 1 i 1 O00OO000 00000000 0uOUO000 OOOuOUO0 OU0U0000 O00UO000 00000000 O00UO000 OUO00OO0 OUOUOO00 OOOUO000 OOOOO000 00000000 O000000U oO00OO00 FCN~',Ci~TG 423.33~ Cb'TC,CNTG C~C.CNTG 3~9~.'t23 URC~,CNTG DEPT. OqOO.0U0 NPHX,CNTG NRAT. C~.~TG "' 3.222 C~AT,C~TG ~'CI~T. C~TG O13,b~O CFTC,Ct~TG CNEC. C~:~'I'G Job2,6OO DE;PT, biog. OOO NPHI, CNTG i~RA'.I;' (,,,t'.l~ j,197 CRA, T:,CNTG [~A'I', CN Tg ~ ' I '! 9 ~AT. CNTG DEFT, o. iOO.l)OO J'/.~O Ei',¢ PH, CNTG 3J.b4b CP~I.CNTG 4J2,15'7 C~:~'I'C. CNT~ l~8~,J2U CFSC.Cm'r~ -~99.X50 1<I. ~.CNTG 2590,000 CCh. Ci~TG ' 0~.25U Tt~NS. CN ~L~ 2540,000 CCI;.~. C~ T~ 29.10b [;6~ F ~'~. Ct~TG 21,$6q CP~i .Cr~TG 'a.OUJ ~;i~g,C,rtT$ '~.380 NCNT,C~TG OU.b~b Tt~m6. cm'rG 2~7~,u0u .... 7 z. o Z b T E ~"~ ~, C t~ T t~ 2 ~ i g, g 0 u ' C C b, C [~ T G 1509,245 ~b77,486 -999.250 29,022 '815,024 2~,468 ...... ? 48,1~2 i3b~,344 ~'5J6.05i 130~,2~4 "506.5b~ l~ TaDe verification C~lU~oerger AlasKa · . V~It{~ : OOlCU1 MAX ~C 6IZN : 1.0~ Flb~ TYP~ : bO - bAS'r FiI,~ : FA~: VERSION : oO1CO1 DAI~ : 9~/0~t2B ~AX Rt.;C SIZ~ : 1024 FILE: ,r~pg : bO-' bAST FIL~ : Depth snltteO and clipped curves ~or each pass in separate PA~$'NUMBER: 2 D~PTH INCRfM~NT: U,50U0 FIbE ~U~MARY bDWO TUOD COD~ 5TART Of PTH S'IOP DEPTH O~C}~ 0409,U ~!00,0 CNTG b423,0 ~lOO,O CURV~ 8H1FT DA1A - Fa~8 TU PA$~[~{~ASUR~D BASEDINE CURV~ FU~ SHIPT8 .......... bDWG CURVE COl)~;: GRCtt PASS NUMmi!jR; 1 ----------EOUtVAb~NT ONSHIf"T~;~ DEPTH---------- BASEblNE DEPTH GRCB 868~8.0 88888,0 b394,0 · 0394,0 635~,0 635b,0 0344,0 6344,5 0323,0 6323,5 6319.5 b295,5 02~$o0 6283.0 Cf~TG b3 i9,0 b263 , b IS TaDe Yerlflcatlon biStinq chlum~erger ~lasKa Computinq Center 6235.0 b235.0 O227,0 b227,U 6223.5 622J.5 6224,b ~221.b 0222.0 o221,0 6221.0 b218.5 b218.5 0191,0 blgl,O b].go,o 619U,5 51O~,0 bI08,0 6167,0 6107,9 6122.0 6110,0 6110o0 0099,0 ~099.5 IOV.O 10~.5 lO0.O THIS FILE CONTAINS PAS6 ~2 UF i'HE CN'iG. THE Df;PTH ADJtIS'rMEi~T~ SHiNto ABUVE MErLe]CT PASS ~2 GRCM TU PAS~ GRC~ a~o PASS ~2 ENPi~ T[I'PA8~; gl ENPn, abb OTHER CNTG CURVE~ w~E CARRIED ~ITH THE ENPH ~HiP'TS, FOk~AT DATA DATA FORMAT SPMCIFICATION R~CORO ** i 66 3 73 5 06 6 73 7 12 68 IA 66 U 14 55 FT lb 66 l- O 6b IS Tape Verification bisting chlumDerger AlaSKa Computing Center NAME 5ERV UNI'C 5~MVICE AP1 AP1 APl APl F lO U~U~ ~ hUG TYPE CbA~ MO~ UEP'I? FT ~U~O Ou UUO OO O ~NPH CNT~ PU-~ qSU~bb OO OOO OO u CPHI CNT~ FU-~ ~U~b uO UUU uo O ~HAT C~T~ ' ~o~O UU oUO UO u C~AT Cfll'G ~u~bO oO OuO OO u FCNT C~T~ CF~ ~SU~ VO UUV UU u C~C CN'r~ CF~ ,~u~b UO UUO UO u ~&~ c~l'~ n~ .... ~va~ vO Ovo VO v C~U~' ~ vTM ~v~O uV VVU uO v 2 ~ I 4 O~ OUOOOOOUO0 2 1 1 ~ O~ OUOOUO0000 Z I i ~ O~ OVUUuOOUO0 Z i ~ 4 ~ ouuouuuuoO 2 i i 4 ~u UUOUUUUUOO 2 i i 4 ~ OOOVUUOUOO Z ~ I ~ O~ VUUUOVOUUO Z ~ ~ ~ O~ UuUUUVVUOO Z 1 I 4 ~a OuvuovOuOu Z i I 4 O~ OuVUOUUVOO Z 1 I ~ Ou uuouovOuOu Z i ! ~ O~ VVUUOVUVOV Z i ~ ~ OU VVOVUOOVVV Z I ! S O~ vvOvuvuvov z i Z ~ O~ UUUUVVUVVV Z Z Z ~ O~ VvUuUuUvOV AU l~aPe verification bkstang cmAu~merger AlaSKa COn~[)utiI%g ~entel 6225.5 ~225,0 0225.5 022~,0 6224.0 P221.0 ~22~.0 ~!90,5 b191,O 61~7,5 0~67,5 6~8,0 6~5~,5 6154,5 6146,0 0146,0 6~21,5 612~,5 6122,0 6109,5 ~00,0 100,5 100,5 S ~E~ARKS: THiS FILE CONTAINS PASS ~3 OF T~E CMY(;, '£WE DEPTH ADOUSTNENTS SHOWN ABOVE REF!,ECT PASS GRC[{ AND PASS ~3 ENPH TO PAS5 #1 ENP~. ALL OTHER CNTG CURVES WERE CARrieD WTTH THE ~NPH $ bis FOR~iAT DATA ** DA~A FORe, AT SPEC...~ICAT.TON RECORD ** ** ~'i~ TYPE- 64EB ** TYPE REPR CODE 1 66 0 2 ~6 3 73 64 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT !2 68 13 66 0 14 65 FT !5 66 68 0 66 0:o- 661. °0 '1;1;~.608 O6 80~ £E8t IL9 6[ 0~ig'666' 6~,9~99 ~96,06~t ~88 068 8E f)iND'DDAD I!L OOE~ 91ND'D,~,qD ~iND'qDD 000 ~L~E ~.ND'D~DD ~I"~98t 9&ND'iHdD 85~:'L~ 9iND'qDD O00'O£~E O0~'§L ~66'E EqO'SL 8L6'E ~,,,, 6 9~ Eq£'L!9 9q["SZ 0~'6£ ~L8 LO9 i9I E 669 [E 0~g'66~- D£NO'D£AD 06~'0~£ DiND'IHdN ~0'00t9 DI, NO'HO~D O~L'~O[ DZND'I~dN O00'OOg9 U&~D'MDMD 88I"L99£ D,~ND' D£AD 09~ ~'[q 9&ND'iNDJ £. t)iND'&~HD l[O,E D£ND'IHdN O0 OOP9 ~ ' ' 30 · 0 .)J,N_.HD~D L~L 8~[ 9&NO 03a3 DIND'i~SD 988'E D&ND'mVaN D£ND'IHdN O00'fgP9 'mdMO Ot 000000 000 89 I I: [ 0000000000 89 ~ I [ E 0000000000 89 9 I I E 0000000000 89 9 I ~ [ 000o000000 89 ~ l I E 00000000o0 89 P I ; E 0000000000 89 ~ I I E 0000000000 89 9 I [ E 0000000000 89 ~ I I E 000o000000 89 ~ I ( E 000o000000 89 9 I [ E 0000000000 89 9 t I E 000000o000 89 ~ I ; E 000000o000 89 ~ I i E 0000000000 89 ~ I ; E 000000000o 89 ~ I I E ;mmm/mmm~im#mmmmmmlm/mlm;mmmlmmImmmmm~mmImm O0 000 O0 9~P08 A 9~ND 0 O0 000 O0 9~08~ 8q 9&NO O O0 000 O0 99908~ Id~D DiED 0 O0 000 00 9~908v 9dD 9iND 0 O0 OOO O0 9~08k 9dD D~ND 0 O0 000 O0 9§~08~ 9dD 9£ND O~ND 0 O0 000 O0 99908~ 9dO D&ND 0 O0 000 O0 9~P08~ ~dD ~£ND 0 O0 000 O0 q~08~ 9dD D£ND &NON 0 O0 0o0 O0 9~908~ DiED 0 O0 000 O0 q~bo8~ DiED 0 O0 000 O0 9~P08~ DiND &VaN 0 O0 000 O0 9~POSV 9-lid DiED 0 O0 000 O0 9S~08~ ~-fid D£ND 0 Oo 000 O0 9~08t' S-tld DiED 0 O0 000 O0 9~908~ i~ XMH) ~OOD N~q3 di~S :3DVd lO:SI 't)66'[-ad IS Tame Verification Listino chlumberqer AlasKa Co.~putin~ Center **** FILE THAII,ER FILE NA~E : EOIT ,003 SFRVICE : t~LIC VERSiqN : ,)O!CO1 DAT.F ~X R~C SIZ~ : ~024 F!L~ TYPE LAST FILE : 30-APR-! 994 15:01 PAGE: 11 **** FILE HEADEi~{ **** FILE r, IA~E : EDIT .004 SERVICE ! ~bIC VFRSIn~.~ ~ 00~ COl. DaT~ ~ 04/04/28 M~X. R;~C S~ZE ~ i024 FIBw TYPE I LO LaST FiLE ~ FILM HESDER AVE~.~ICEU CURVES ,,. ., t 1 · Compensated t,e,]tron: Arithmetic everage oi edit, e8 Passes ~or afl curves Pulsed Neutron: Unaveraged edited Pass i Gamma Rav and Dackround counts; a. rit, nmetic average of esited stat.ic ~aseline passes for ail Other curves, D~PTH iNCREmENT 0.5000 P~,S,S~]$ INCLUDED I~ AVERAGE LOWG TOOL CODE PASS NU~BE~S PE~A~KS: THIS FILE CO{~TAINS THE h[,:IT~MET!C AVEF~AGg OF THE THREE C~.ITG PASSES, AL~, DEPTH COPRECTION ~E~<E ~%PPLIED BEFORE THE AVERAGE ~AS COMPUTED, LIS FORMAT DATA ** DATA F'OR~AT SPECIFICATION RECORD ** ** SET TYPE - 64E~ ** ~YPE YALUE I 66 .~ 2 66 0 3 73 60 ~ 66 ~ Tame Yerlfl. catt. on Listfno chlumberqer AlasKa Computlt~q Center 30-AP~-1994 i5:01 PAGE: 12 ** SET ~YPE - C~AN ** .......... [ .... ....... ............ ....... .. ........... ..... ........ N MF ~FRV NIT SERV'TC~ APl hpI h.. API FII,E MUMB NU SIZE REP pROCE TD ORDER ~ bOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) . 48045 . 000 O0 0 4 ! ~ 6S 000000 ND[~T CNAV PU-$ 480456 O0 000 O0 NDA~ CNfiV 480456 O0 000 O0 CP~I CNAV PU-S 480456 O0 000 O0 C~AT CNAV PU 480456 O0 000 O0 EN'P~ CNAV PU-S 480456 O0 000 O0 E~R~ CN~V CPS 480456 O0 000 O0 NCN? CNAV CPS ~80456 O0 000 O0 FCN~' CNAV CPS 480456 O0 gOO O0 CFTC CNI'V CPS 480456 O0 O00 O0 CNTC CN~V CPS 480456 O0 000 O0 CFEC CNAV CPS 480456 O0 000 O0 CN~C CNAV G~PI 480456 O0 000 O0 G~CE CNAV LB 480456 O0 000 O0 TFN$ CNAV V 480456 O0 000 O0 0 4 ! 1 4 68 0000000000 0 4 I 1 4 68 0000000000 0 4 I I 4 68 0000000000 0 4 I 1 4 68 0000000000 0 4 1 I 4 68 0000000000 0 4 1 ! 4 68 0000000000 0 4 I ! 4 68 0000000000 0 4 i I 4 68 0000000000 0 4 !. 1 4 68 0000000000 0 4 ! 1 4 68 0000000000 0 4 t I 4 68 0000000000 0 4 1 ! 4 68 0000000000 0 4 1 I 4 68 0000000000 0 4 I 1 4 68 0000000000 ** DATA ** C~AT.CNAV FCNT.CNAV CNEC.CNAV 6413'000 3,675 428'067 4?8.067 6400.000 27,555 611,465 72.0~7 NP I.CNAV ENPH.CN'AV CFTC.CNAV GRCH,CNAV NPHi.CNAV. ENPH,CNAV CF~C,CNAV GRC!,{,CNAV 41.052 NR,~T, CNAV "N 5.029 ENRA,C ,AV 1532,606 CNTC,CNAV 2498.083 TEN$,CNAV 3.694 CPHI.CNAV 1567'875 NCNT°CNAV C' CNA V 668.762 2498.08 ~! 3.:9.25 CPHi,CNAV I887.341 NCNT,CNAV 830.030 CFEC.CNAV 0,090 3.654 4~9,]89 3.363, !7 3,12! 36'55.01.7 0'9609 ~&dMO 0'0S~9 O00S'O lOOrO0 : Ol~ ~ ;oa~oo : ~00' j~oa : S~VN aqla ET 05~'[88[ 6~6 E T~T~zLOE £~ Tg Lgo'~ ~;OL'T91~E £6 g :3DVd t90'O AVNO'ANON 8Eg'90ET AVND'IHdD A.V{~D'&NDN 8LE~L~ET A~ND'IHdD S~T ~ gEg'O AVND'D3MD g~)'S6L AVNO'~NDN 8~'~S8T AVNO'IHdD 6TT'£ AViqD'gNM£ L60'89Eg '6 gO9,9 AYND'~N:~ 9£g'S9~g AVND'Va~M AVND"gNa~ 8LE'89~ To:sT AYND'HOHD OEP'EL AVNO'O:~ND AVND'IHO~ 000'00~9 &dAO AYND'~IdN~ E90'T~ AVND'IHdN 000'~0~9 AVND'HdN3 ~80~Lg A~NO'm~D ^VND'IHdN 000 OOE9 '~dMO bg'[lST, rj UO'[!~O[J'~1ah a~i~& IS Wa~e Verif~catlon ListJnQ chlumberqer AlasKa ComputJr~ Center 3O-APP-199~ 15:01 PAGE: 14 ~D D~ILL~R TOP [,OG TDTERVAb ~OT'fO~ bQG I~TERVAI, DEPT~ CONT~OT, TtSED (YES/NO): TOO[, STDI~G (~OP TO V~NDO~ TOOL, CODE TOOI, '~YDE CC!., ~LLA~ [~OCATO~ TCC TEbEMETPY CARTRIDG~ G~ GAM~A RAY' C~TG CO~DENSATFD NEUTR[~N ?S ~O~E~OLE A~D CA, SING DATA OPEN H~LE BlT SIZE DRILI..,EPS C~GTNG DEPT!~ LOGGERS CASING DEPTH ~OREH!3LE CONDitiONS FLUID TYP~: FLUID DENSITY (LB/G): SURFACE TEMPEPATURE (I~EGF): ~OTTO~ Mf]I,E TEMPERATURE (DEGF); FLUID SALINITY FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RAT!01 CHOKE NEUTRON TOOL TOOL TYPE (EPITHERM~L OR THERMAL): M~TRIX: MATRIX DENSITY: }{OLE CORRECTION (IN): O%'APR-94 38,2 ~u15 ~424.0 ~00.0 'r~;Ob C~T,-YA- TCC-B-42~ SGC.,SA-598 31.43.0 05-APR-g4 BRINE ~.i,70 17 0 , 0 EPITHERMAL SANDSTONE 2.65 Br,UELINE COUNT RATE NORmALiZATION i.N OiL ZONE TOP NO~MAL!ZIiNG WINOOW (FT): BASE NO~ALI, ZING BbIIE!.,INE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RkTE LO~ SCALE (CPS): ~h~ COgeNT IS Tare Vert. fication Listlnq chlumberqer Alaska Comput. Inc.~ Center 30-AP~-lg9q 15:01 PAGE: 15 RFaaRR$: TTED INTO CET DATFD 3/201q4 ~AD~ 3 PASSRS AT ~00 FP~ $ LIS W[!R~AT DATA ** DATA ~'OR~AT SPECIFICATION RECORD ** ** SET TYmE - ~4E~ ** 1 66 0 2 66 0 3 73 76 4 66 5 66 7 65 8 68 0,5 9 65 FT !1 66 13 tP 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 ** SET v]PE - CHaN ** NAMF SERV UNIT SERVICE API ~PI APl ~PT FILE ~[J~B NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELMM CODE (HEX) DEPT FT 480456 O0 000 O0 0 5 I ! 4 68 ENP~ PS~. PU 480456 O0 000 O0 0 5 ! I 4 68 E~R~ P$1 480456 O0 000 O0 0 5 1 ! 4 68 CFEC PSi CPS 480456 O0 000 O0 0 5 I ! 4 68 C~EC PS~. CPS 480456 O0 000 O0 0 5 1 I 4 68 REEF PS1 CPS .480456 O0 000 O0 0 5 1 I 4 68 RCE~ PSI CPS 480456 O0 000 O0 0 5 1 1 4 68 NPHT PS! PU 480456 O0 000 O0 0 5 1 .i 4 68 TMP~ PSi PU 480456 O0 000 O0 0 5 1 i 4 68 T~RA PS1 480456 O0 000 O0 0 5 1 i 4 68 RTND PSi. ~80456 O0 000 O0 0 5 I 1 4 68 NP[)~ PSi PU 480456 O0 000 O0 0 5 i 1 4 68 RCN? PS! CPfi 480456 O0 000 O0 0 5 1 1 4 68 REFT PS1 CPS 480~56 O0 000 O0 0 5 1 1 4 68 C~TC P$1 CPS 480456 O0 000 O0 C 5 1 I 4 68 CFTC PS1 CPS 480456 O0 000 O0 0 5 I I 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 IS Ta~.e Ver~f.icatio~ ListJn~ chlumber.';~r Alaska Computlno Center 30-APP-1994 15:01 PAGE: 16 U lit SERVICE 1 ApT AP ~PI FI!.E ~ NUmB I~E REPR P~O ESS GP 1 G P 80456 0 _0 O0 5 1 ! 65 0000 00000 TFNS PS1 bP ~80456 O0 000 O0 C 5 ! I 4 08 O00OO00000 ECL PSi V 480456 O0 OOO O0 C 5 I 1 4 6~ O000OO0000 D~pw. 6~50.000 ENPh. P$1 34.934 E~'.R~.PSI 5.151. CFEC.PS1 C~!EC,P$! 3421.833 ~CKF'P$1 673.956 ~CEN,PS! 3280.123 aPHI.PS1 T~P~.PS~ 35.0~7 TN~.PSI 3 4~4 RTN~.PS1 3.52~ NPfi!~.P61 RC!~T,PS~ 1509,245 RCFT.PS1 423~334 C~iT£?.PSi 1470,608 cFTC.P6~ G~,PSI ~0.3~3 TENS'PS1 la20.O00 CC~..PS! 0,003 DFPT 6400.000 ENPFi,PS! 2~,395 E~Ri~.PSI 4.494 CFEC.PS1 C~EC:PS~ 3662'660 PElF.PSi 855.072 RCF;!.PSi 3526.368 NPHT.PS~ TNP~.DS'I ~9.0~2 TNPA,PS1 3.127 RTN~.PS1 3.~22 NPOR.P$! RCi~T.PS1 ~916,335 PCFT,PS1 613,580 C~]~TC.PS1 185~.383 CFiC.PS1 GP.PSI 65.688 TENS.PSI 2540,000 ECL,PS! 0.014 DFpT 6300 000 ENDS PS1 27.384 Ei~iP~ PSi 4 386 CFE CNEC~D$1 3459,!38 ~C~F,PS1 799,748 ~CEN,PS~ 3336.975 NPHI,PS! TNP~J.P8~ 28,468 TN~A,PSi 3,003 RTN~,PSi 3.197 NPOR.P$~ RENT,PS! 1~60,759 ~CFT,PSi 603.48] CNTC.PS! 1787,189 CFTC,PS~ G~.DS!. 68,6~5 TENS,PSi 2475.000 ECL,PS1 0,208 DVPT. 6200,000 E.NP~{.PS~ 4,~ .662 EI~RA.PSl 5 764 CFEC.PSI C~EC. PS 1 3091 .I. O0 PelF'PS1 549.797 PeEN,PS1 2958:580 NPHI.P81 T~P~.PS1. 49.300 TNRA,PSI 4,194 RTNR,PS1 ~ ~57 NPDR,PSI NT.PS1 1360.149 RCFT,PS~ ~98.~77 CNTC,PSI 1315~035 CFTC,Psi REG,,PS1 75.375 TENS,PS! 2420.000 CCI~,PS1 -0' 08~ DS~PT. 6i00.000 ENPM,PSI 40.782 ENRA.PS! 5 687 CFEC.PS1 C~EC.P81 ~869.641 ~CEF.PS1 489,849 RCEN,PS1 2761~469 NPMI,PSI TNp~,D51 44 036 .FARA,PSi 3.853 RTNR,P$1 3,986 NP~.PSl RCNT.DS~ 1307~214 RCFT,PS1 327.429 CNTC,PS1 1331,B76 CFT~,PS1 G~,PS1 74,6~8 TEN~.PS1 ~3i0'000 ECL,PS! -0,021 DEPT 6096 000 ENPH,PSI 3~ ~07 E~..~RA,PS1 5,480 CFEC.PS1 C~:'f'iDS1 30~5~173 ~CEF~PSI 5~7:u05 PC~N,PSI 2869! 388 NP~il,Ps1 .... i P~'"l 39,802 Trina PSI 3 636 ~?'h~ PSI 3 634 NPOR PSl ~CN?,PS1 1463.0~4 ~:CFT,P81 364,~98 CNTC,PS1 1369 9!9 CFTC.rS1 G~,P$! 95,675 TENS'PSi 2360.000 CEE,PSI 0.082 66z~.312 37,946 35;027 432.195 5 024 28,707 613,172 788,679 29,166 27,945 599,120 536.,:27,2 50,8~0 48,883 310.682 504,564 44 663 46 276 337. 572 51,992 540,707 38,005 370,764 END OF DATA 0~006 o 0O[9 0'~9 0°~9 ~O~V3O~l 8~'1q03 q33 ~dX~ qOOI 3~OD qOOi ~O~N~A ~(~2) q~A~NI 90~I 0 ' [60q O' Og~9 O00S'O :~a~3~D~I H£d3O o~e~eaas UT sseu qoea zo~ e~ep aopeou ~OT pue S3A~iiD Oq : ~dl~ ~qlJ ~OD¢O0 : Diq~ : 900' %1(]~ : 3~VN Aqi,~ TODIOO ; ~OISH3A DIq~ : ~DIA~S §00' ,i/Q3 : 3~VN L'[ :2DVd TO:BI ~661-ad~-O~ IS Tane Verification Listino chlumberger Alaska Computino Center 30-APR-19g4 15:ol 8!3R[iuOLE AHD CA$It~C DATA ODE~ MOLE BIT ~%!ZE {I~)'. ~RIL!.,ERS C~SING DEPT~q fFT): LOGGERS CA$I~G DFPTH FLUID TYPF: FLUID DENSITY (LB/G): SURFACE TF~DE~ATURE FLUID SAbTNITY FL~ID [,EVE[., (FT)~ FLUID RATE AT ~ELbHEAD ~aTER CUTS (PCT): G~S/OIL TOOL ~YDE (EPITHERMAb DR T~iER~AL)I ~aTRIX: [~ATRIX OE~S!7~Y: HOLE CORRECTION [TN): !1.70 !70.0 ~PITHE~NAL SANOSTON~ 2.65 Bt, UELINE COUNT RATE NORMA[,IZATION i~! OIL ZONE TOP ~O~MALIZING wI~DOW (FT): ~ASE NORMALIZING ~INDOW (FT): PL~ELIME COUNT RATE SCAL~$ SET BY FIEb[~ ENGINEE~ FA~ COgeNT RATE LOW S. CALE (CPS): 0 WAR CO!!NT ~A. TE ~IGH SCALE (CPS): 40 ~E~R CU~T R~TE LOW SCALE [CPS): 0 NEAR COU~ RATE NIGM SCALE (CPS): 20 TOOL STANDOFF REMARKS: TJEO INTO CET OATED 3/20/94 ~ADF 3 PASSES AT gO0 FPg $ LIS FORMAT DATA PAGE: 18 ** C~ATA F'OR~AT SPECIFICAT!05,I REC'ORD ** ** SET TYPE - 64EB ** TYP. R R CODE] 1 66 0 2 66 0 3 73 76 4, 66 1 IS Tape ¥ertftcation I,istJ,l.c~ 1.5:01 PAGE: 1.9 b 73 7 65 ~ 68 0.5 9 65 ~T ~! 66 13 ~ 68 18 65 FT 15 66 6~ ~6 66 1 0 6~ 1 ** SEw ?YP~ - CNAN ** NglqE s~Rv U~:~IT SE~VIC APl A I Pl ~PI FiB NUMB ' IZE E PRUCESS ID ORDER ~ bOG TYPE CLASS ~OD t, IU~B S~.MP ELEM CODE (HEX) D~P? Fm 480456 O0 000 O0 0 6 I I 4 68 ENP~ PS9 pU ~80456 oO 000 O0 0 6 1 I 4 68 E~!R~ PS2 480456 O0 000 O0 0 6 ! I 4 68 CFEC P82 CPS 4.80456 O0 000 O0 0 6 I I 4 68 CNEC P$~ CPS ~80456 O0 000 O0 0 $ I 1 4 68 RCEW PS2 CPS 480456 O0 000 o0 0 6 1 ! 4 68 RCE~ PS2 CPS 4~0456 O0 000 O0 0 6 1 i 4 68 NPHT PS2 PU ~80456 O0 000 O0 0 6 ! I 4 68 TMp~ PS2 PU 480456 O0 000 O0 0 6 1 1 4 68 TNR~ P$2 480456 O0 000 O0 0 6 1 I 4 68 R~N~ PS~ ~80456 O0 000 O0 0 6 i 1. 4 68 NPOP PS~ Pll 480456 00 000 O0 0 6 1 1 4 68 RCNT PS2 CPS 480456 O0 gO0 O0 0 6 I I 4 68 RCFT PS2 CPS 480456 O0 000 O0 0 6 1 I 4 68 CNTC PS2 CPS 480456 O0 000 O0 0 6 1 I 4 68 CFTC PS2 CPS 480456 00 000 00 0 6 i I 4 68 G~ ~82 (;~P? ~80456 O0 000 O0 0 6 1 I 4 68 T~NS PS2 ~B 480456 00 000 O0 0 6 1 I 4 68 CCL PS~ ~ ~80456 O0 000 O0 0 6 1, I 4 68 0000000000 0000000000 0000000000 0000000000 000o000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O0000000oO 0000()00000 00000000(~0 0000000000 000000000~ 0000000000 DE[>T 6450.000 ENPH PS2 CNE'~C ~ p$2 344,4..560 RCEF[P$2 Tt!PH PS2 37.47.4 TNRA.PS2 RCNT~ P82 16~3 .~8~ t~CFT' PS2 GP,PS2 67.1~8 TENS.PS2 37 064 65:2 3.635 430 756 1, ,,390 000 ENRA,.PS2 RCEN.P82 RTNR,P$2 CNTC,P$2 CCh,PS2 5 352 CFEC,PS2 3301. 908 NPHI.PS~ 3 674 NPOR.PS2 1562 8..29 CFTC'PS2 -0 041 643 640 40 700 37 474 439 77! ~[6:8[ 6~8 6£ 691 9~ L96'6~ L~L'6g~ 0~6'E6~ 80'8g ~ '8~ ~9~'~8L 8L8 O[ LO~'qE8 gSd 80dN gCSd'IHdN ~Sd'O~4~3 ggd'IHdN ggd'O£MD gSd'UOdM 90I'0 9PS'E gL9:Ot6g EOE ~ 960'0 LSO'~ 688'069g I09'S Eo9 gSg'~ 9LL'~ ~6['0 60E'98LI 6£0'~Lg£ 660'0 8~[ ~ gSd*qOo g~d'VH~M g08'6~ [~a'qoo ooo'o9~ g~d'~N~ 66L't~ gSd'qO3 O00'O£~g gEd'D~NO L~9'909 E~a'N~D~ 6£~'L08 gSd'qOD 000' g~d~D£~JO 60E' gMd HN~a 960' E~d'V~!qM 9gO' gO9 8g/~0i~6 l Dlq~ : ~DtAHM~ g~d'HdNi~ 000'[609 &da(] g~d'}~dNa 000'00t9 gWd'AMD~ I'P6'6~0[ ~Sd g~d'lidNM O00'OOg9 ~Sd'A~Da ~,~L'§L~ go.-. .,d ~NDH g~d'~a~,l£ ggL"9~ gSa'ad~£ g S d ' i~ d ~i S 0 O O ' 0 u ~ 9 IS Tare Verification bistina cblumherger AlasKa Comput!.na Center 30-APR-~994 15:0I PAGE: 21 r wE~DER FTL~ ~!{.i~,BER 7 CURVES Curves and loq header data for each pass in separate pass NU~BFR: 3 D~PTH I NCRE~E~'T: 0.5000 vi~'".'POR~:. . TOUI. CODE START. DFDTH,. .................~>~TG, ;;~;:[. .... LnG ~iFADE~ DATA STOP DEPTH 6094.0 sOFTWAPE VERSION: TD DRILLER CFI): ~P LOGGER(FT): ~OP LOG INTErVaL (FT): PDTTn~ LOG INiERVAL (FT): [.,OCGIN~ SPEED (FPHR): Dg:PT~! CO~TRO!! !ISED (YES/~O): TnOl~ STPlNG (TOP TO BOTTOm) ....... . ....... . CCh CObLAPLOCA. O~ TCC TELEMETRY CARTRIDGE GR GAN~A RAY C~TG CUMPENS~TED NEUTRO~ $ ~[)PE~OLE AMD CASING DATA OP:E~ WOI.,E BIT SIZF (IN): DRILLERS CA$IN~ I~OGGER$ CASING D~PTH FOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): S[IRF~CE TE~{PEP~TURE (DEGF); BOTTO~ ~OLE TEMPERATUPE CDEGF]: f'LUID SALINITY (PP~): FL!lID LEVEL FLUID RATE ~T WELLHEAD W~TER CUTS GAS/OIL RATIO: CHOKE (DEC): ~!EUTRON TOOl,, TOOL TYPE (EPITHERM&b OR THERMAL}: ~hTRIX DENSITY: HOLE CORRECTION (IN): files; raw baCK,round pass in last fi 05-APR-94 38,2 10~5 6553.0 6442.0 6100 0 6424~0 900.0 05-~PR-94 TOOL NUMBER TCC-B-421 SGC-Sa-598 CNC-GA-I~5 3143.0 BRINE 11,70 ~70.0 EPITHERMAL SANDSTONE 2.65 IS Tar~e VerffIcatJ, on !,ist:in~ chlumberger AlasKa Compute. ha Center 30-APR-l. 994 15:01 PAGE: 22 nL~SI~INE CP, ONT RATE SCAbES SET BY FIKLD ENGINEER FAR COt~NT PATE LO~ SCALE (CPS): 0 WAD CO[~NT RATE HIGH SCALE (CPS): 40 ~E.~R COUNT R~T~ LOW SCAbE (CPS): 0 ~3EAR COIJ~'I RA~'~ HIGH SCA~E (CPS): TOOL, STANDOFF TIED INTO C~T D~TED 3/20/94 ~ADE ~ PASSF.,c A'r ~60 FPP $ LTS FO~{r,'~AT DATA ** D~TA F~R~AT SPECIFICATION PKCO~D ** ** SET TYPE - 64EB ** TYPE RMPD CODE VALUE ~ 66 0 2 66 0 3 73 76 4 66 1 5 66 ~ 73 7 65 8 68 0,5 9 65 FT 1! 66 13 1~ 68 11~ 66 0 14 65 FT ~5 66 6~ 16 66 1 ~ 66 I ** SET TYPE - CHAN ** '''~;''~''~NA ....... ]'T SERV~ .................. API APT AP1 ~'';''''''~'~'''~''~;'~'''''''''~'~'~'''It,E N N Z REPR E ID ORDER ~ BOG ~YPE CbASS ~OD NUMB SA~P ELEM CODE (HEX) DEP~ ~8045~ O0 000 0 7 1 4 000000 0 ENP~ PS3 P,~ 480456 DO 000 ~0 0 7 I I 4 68 O000000000 ENR~ PS3 480456 ~0 000 DO 0 7 t I 4 68 OOO0000000 ,IS ,~are Verlficatlon I,istlno chlUmtterqor AlasKa Comput. ino Cent, er 30-A. PR-.!.. 994 15:01 PAGE: 23 ~.5 M F' SRRV .T. CF AP ~.pT_ API AF CPF'.C , $ CPS 8 4 O0 0.0 O0 C~EC P$3 CPS 480456 00 000 OO 0 RCE~ P$3 CPS 480456 O0 000 O0 O RCE~ P$3 CPS 480456 O0 000 O0 0 ~}-11 mS3 pl! 480456 00 0~0 O0 0 TNpH PS] PU 450456 O0 OOO O0 0 T~Ra PS3 480450 O0 OCO O0 0 RT!:~P P83 480456 O0 000 O0 0 NPO~ PS! PI! a80456 00 000 00 0 R¢~T PS3 CPS ~80456 O0 0o0 O0 0 RCF? 083 CPS ~80456 O0 000 O0 0 CNTC PS3 CPS 480456 00 000 o0 0 CFTC PS3 CPS 480456 O0 000 00 0 GP ~53 GAPI 480456 O0 000 O0 0 TE~ ~$3 LB 480456 O0 OOO O0 0 CCL PS~ V 480456 O0 000 O0 0 II, E IJ~ NtJ~B $I E EPR PRO ..E gLEN COUE (HEX) 1 4 _, 00000000 7 I I 4 68 0000000000 7 I 1 4 68 0000000000 7 1 1 4 b8 0000000000 7 1 i 4 6~ 0000000000 7 1 ! 4 68 0000000000 7 I ! 4 68 0000000000 7 ! 1 4 68 0000000000 7 ! 1 4 ~ 0000000000 7 1 1 4 6~ 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 0000000000 7 1 1 4 6~ 0000000000 7 1 1 4 68 0000000000 7 1 1 4 68 000000O000 7 1 1 4 68 0000000000 D~PT. 6449,500 ENPa.PS3 31 T~p~' ....PS .PS~ 40,881 TNPA, 3 RCN~.P$3 1590.961 PCFT.PS3 403 GP,P$3 75,563 TENS,PS3 14!5 D~PT. 6400,000 ~N~H,P$3 27 C~EC.PS3 3667,1.88 RCEF,PS3 853 T~P~,P$3 29.672 TN~A'P83 3 ReNT PS~ I833 208 9eFT.PS3 611 G~PS'3 77~b88 TENS.PS3 2420 DEP?. 6300.000 ENPH.PS3 26 CNEC.PS3 3473.116 RCEF.PS3 800 T~PH. P$3 ~7,048 TNRA'PS3 ~ ,T P$3 ~7~a,750 ~cF'r,P83 608 DEPT. 6200.000 ENPH.PS3 41 C~EC.PS3 3056,976 RCEF,PS3 529 't~pu P83 a. 3,130 T~!~A'PS3 3 'PS ~ ~3i'1.302 RCFT.PS3 319 DEPT,, 6100.000 ENPH.P$3 39 CNEC.P$3 2869.6~[! ~CEF.P$3 494 TNPH,PS3 43'064 TNRA.PS3 3 PS3 1362 5a8 ~C~T' PS3 308 RCNT, ~ ~ , ........ GP P~ ,~ 2 7~0 T~NS PS3 2360 ,772 ENRA,PS3 .405 RCEN,PS3 ~845 RTNR,PS3 904 CNTC.P83 .000 CCL,PS3 .~48 ENRA.PS3 .647 RCEN,PS3 ,!41. ~TNR'PS3 ,360 CNTC.PS3 ,000 CCh,PS3 .975 EN~A,PS~ .19~ RCEN'PS3 ,938 RTNR'P$3 ,223 CNTC.PS~ .000 CCh,PS3 542 EN~A,~o3 827 RCEN.PS3 944 RTNR,PS3 7!1 CNTC,P83 000 CCL,PS3 ,650 ENRA,.P~ o 3 .7~5 RCEN,PS3 9 9 RTNR.P83 90g CNTC,PS3 000 CC5,P83 4 84! CFEC.PS3 3075i758 NPHI,P$3 3 886 NPOR,P$3 !550 ~32 CFTC,PS3 0~!57 4. 71 cF c.ps 3571. 003 NPH!.PS3 3:33! NPOR,P83 1861,.145 CFTC.PS3 o. 1,57 4 342 3328 534 3 000 1780 596 -0 044 754 299 ,' I 13 3,861 - ~, 5 587 2751i671 3 9'12 1324 314 0.126 CFEC.P$3 NPBI.PS3 NPOR,PS3 CFTC,PS3 CFEC.PS3 NPHI,P$3 NPOR,PS3 CFTC,P&3 CFEC,P$3 NPHI,P$3 NPO~.PS3 CFTC,PS3 662.782 44,523 40;881 412.358 838,908 31.699 31,238 607,874 79 882 85O 61 31.294 546.3~6 43,968 333.935 513.622 46'968 43 337.:: i2 IS Ta~.e Verification I,istin~ cblumberger AlasKa Cowputtnq Center 30-APR-1994 1.5:0i PAGE: 24 DFPT. 6094.O00 ENPH,PS3 CNEC.PS3 30!9.075 ~CEF.PS3 T~P~,DE3 40,196 T~RA.PS3 RCNT,PS3 ~40b,O~l ~CFT.PS3 GP,PS3 ~.0~3 TENS.PS3 39.095 ENRa. PS3 55g.gS$ RCEN,PS3 3.~44 ~T~R.PS{ 304.525 CNTC.PS3 251n,0~0 CCh. PS3 5.537 CFEC.P$3 2940.604 NPMI.P53 3.819 NPOR.PS3 1407.561 CFTC.PS3 0,133 545.2~5 44.506 41.456 378.5~6 DATA F?LF ~'A~'2~ : EDIT .007 $~RVIC_ E : ~LTC VWR S 1 f~,',~ : 001C01 DATE : q4/04/28 ~1~X R?C STZ~ : !0~4 SFRVICE f:~HW : EDIT D~TF : O~IC1N : FLIC T~PF ~E : 94161 CONTI~3U~I'ION ~ : l PPEVlUUS TAPE : ~{CL~ ALASK~ INC,, KUPA~UK, 3N ~6, 5002920208 D~TF ~ 94104128 RFEL ~A~,~E : 94161 CONwI~U!TION ~ : PREIi.IOUS REEL ~ COFI~/:~,~T : tRCO ALASK~ I~C., KUPARUK, 3H - 26, 5002920208