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198-109
1. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Convert GL to Jet Pump Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 7432'feet None feet true vertical 4026'feet None feet Effective Depth measured 7087'feet 6539', 6721', 6806'feet true vertical 3776'feet 3405', 3523', 3580'feet Perforation depth Measured depth True Vertical depth Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 6384' MD 3310' TVD Packers and SSSV (type, measured and true vertical depth) 6539' MD 6721' MD 6806' MD N/A 3405' TVD 3523' TVD 3580' TVD N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: N/A 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work: West Sak Oil Pool 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title: Contact Phone: 6517' 3391' Burst Collapse 4014' 141' 209' Casing Conductor 3598' 2-7/8" 6832' 6700' 3509' 6480' 7416'Production 1 Production 2 B Sand Straddle 16" 7-5/8" 5-1/2" 79' 7375' measured TVD 4-1/2" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 198-109 50-029-22890-00-00 P.O. Box 100360 Anchorage, AK 99510 3. Address: ConocoPhillips Alaska, Inc. N/A 5. Permit to Drill Number:2. Operator Name N 4. Well Class Before Work: ADL0025650 Kuparuk River Field/ West Sak Oil Pool KRU 1D-127 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 450 Gas-Mcf MD 121' 750 Size 121' 200 2475225 100 19050 150 N/A Sr Pet Eng: Sr Pet Geo: Sr Res Eng: WINJ WAG 75 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A Packer: Baker Premier Packer Packer: Baker Premier Prod Packer Packer: Baker Premier Prod Packer SSV: None Will Parker will.parker@conocophillips.com (907) 265-6239Senior Production Engineer 6662-6698, 6744-6770, 6876-6882, 6918-6932, 6962-7002' 3484-3508, 3539-3556, 3628-3632, 3657-3667, 3688-3716' D Sand Selective Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Kayla Junke at 1:11 pm, Sep 22, 2023 DTTMSTART JOBTYP SUMMARYOPS 8/25/2023 REPAIR WELL DRIFT TBG TO 7087' MD (ESTIMATED 85' OF RATHOLE BELOW PERFS) FILL IN BAILER, SET SLIP STOP CATCHER @ 6230' MD, PULL OV FROM 6207' RKB AND REPLACE WITH DMY VALVE, ATTEMPT TO PULL OV FROM 4543' RKB SHUCK DOGS. IN PROGRESS 8/26/2023 REPAIR WELL SWAP OV IN STA #1 @ 4543' WITH DMY VALVE, OPEN SLIDING SLEEVE @ 6267' RKB, FLUID PACK IA, SHUT SLIDING SLEEVE @ 6267' RKB TO CONDUCT PASSING MITIA, OPEN SLIDING SLEEVE @ 6267' RKB. IN PROGRESS 8/27/2023 REPAIR WELL SET JET PUMP @ 6267' RKB, SET SLIP STOP ON TOP OF JET PUMP @ 6263' SLM 1D-127 Convert to Jet Pump Summary of Operations Last Tag Annotation Depth (ftKB) Wellbore End Date Last Mod By Last Tag: RKB 7,087.0 1D-127 8/27/2023 rogerba Last Rev Reason Annotation Wellbore End Date Last Mod By Rev Reason: Converted to SPJP, set SPJP and Slipstop, opened CMU, DMY off GLM's 1D-127 8/27/2023 rogerba Notes: General & Safety Annotation End Date Last Mod By NOTE: WORKOVER 9/28/2009 osborl Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) Wt/Len (lb/ft) Grade Top Thread CONDUCTOR 16 15.06 42.0 121.0 121.0 62.58 H-40 WELDED PRODUCTION 7 5/8 6.87 41.2 7,415.9 4,014.2 29.70 L-80 ABM-BTC Tubing Strings: string max indicates LONGEST segment of string Top (ftKB) 36.2 Set Depth 6,384.4 Set Depth 3,310.3 String Ma 2 7/8 Tubing Description TUBING Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE8RDMOD ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 36.2 36.2 0.00 HANGER 10.750 VETCO GRAY TUBING HANGER 2.440 495.7 492.3 16.07 NIPPLE 3.625 CAMCO 2.313" DS LANDING NIPPLE 2.312 4,543.5 2,495.5 64.51 GAS LIFT 4.750 CAMCO KBMG- M 2.347 6,207.3 3,216.0 61.85 GAS LIFT 4.750 CAMCO KBMG- M 2.347 6,266.5 3,245.2 59.05 WIRE GUIDE 4.750 TEC WIRE GUIDE 2.500 6,267.6 3,245.8 58.99 SLEEVE-O 3.875 BAKER CMU SLIDING SLEEVE w/ 2.25" D PROFILE (OPEN 8/26/2023) 2.250 6,271.6 3,247.8 58.81 WIRE GUIDE 4.750 TEC WIRE GUIDE 2.500 6,320.6 3,274.0 56.65 GAUGE 2.875 GUARDIAN SIDEMOUNT GAUGE CARRIER 2.500 6,374.6 3,304.6 54.39 SEAL ASSY 3.980 BAKER 80-40 GBH-22 SEAL ASSEMBLY 3.000 Top (ftKB) 37.7 Set Depth 6,517.4 Set Depth 3,391.1 String Ma 5 1/2 Tubing Description INNER CASING Wt (lb/ft) 15.50 Grade L-80 Top Connection BTC-M ID (in) 4.95 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 37.7 37.7 0.00 HANGER 10.750 VETCO GRAY CASING HANGER 4.950 6,370.7 3,302.3 54.56 SBR 5.040 BAKER 80-40 SEAL BORE EXTENSION 4.000 6,389.9 3,313.6 53.87 XO Reducing 5.560 CROSSOVER 5.5 x 3.5 3.000 6,394.8 3,316.4 53.76 XO Reducing 4.500 CROSSOVER 3.5 x 2.875 2.441 6,437.6 3,342.0 52.86 CIRC MANDREL 4.750 CAMCO KBMG- M 2.347 6,496.6 3,378.1 51.73 LOCATOR 4.180 SPECIAL CLEARANCE LOCATOR SUB 2.441 6,498.8 3,379.5 51.70 SEAL ASSY 3.970 BAKER SEAL ASSEMBLY w/ 7 FT SPACE OUT 2.990 Top (ftKB) 6,491.0 Set Depth 6,700.2 Set Depth 3,509.3 String Ma 2 7/8 Tubing Description D Sand Selective Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE 8rd -M ID (in) 2.44 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,491.0 3,374.7 51.82 SLEEVE 7.000 BAKER HR LINER SETTING SLEEVE 5.750 6,503.7 3,382.5 51.62 NIPPLE 5.500 BAKER RS NIPPLE 4.870 6,508.4 3,385.5 51.55 SBE 5.040 BAKER 80-40 SEAL BORE EXTENSION 4.000 6,539.0 3,404.6 51.08 PACKER 6.560 BAKER PREMIER PACKER 3.870 6,556.7 3,415.8 50.80 XO Reducing 4.500 CROSSOVER 4.5 x 2.875 2.420 6,574.4 3,427.0 50.51 GAS LIFT 4.750 CAMCO KBMG- M 2.347 6,629.6 3,462.6 49.26 SLEEVE-C 3.875 BAKER CMU SLEEVE w/ 2.25" PROFILE (CLOSED 11/26/2016) 2.250 6,677.6 3,494.2 48.30 XO Enlarging 2.480 CROSSOVER 2.875 x 5.5 5.500 6,690.6 3,502.8 48.19 SEAL ASSY 5.750 BAKER SEAL ASSEMBLY 4.810 Top (ftKB) 6,691.1 Set Depth 6,832.0 Set Depth 3,598.2 String Ma 4 1/2 Tubing Description B-Sand Straddle Pack Wt (lb/ft) 12.60 Grade L-80 Top Connection IBT ID (in) 3.96 Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des OD Nominal (in)Com Make Model Nominal ID (in) 6,691.1 3,503.2 48.19 SLEEVE 6.390 HR LINER SETTING SLEEVE Baker HR 5.750 6,703.8 3,511.7 48.07 NIPPLE 6.070 RS PACK OFF SEAL NIPPLE Baker RS 4.875 6,721.0 3,523.2 47.92 PACKER 6.570 BAKER PREMIER PRODUCTION PACKER Baker Premier 3.875 6,806.0 3,580.5 47.18 PACKER 6.570 BAKER PREMIER PRODUCTION PACKER Baker Premier 3.875 6,830.7 3,597.4 46.97 WLEG 4.950 WIRELINE ENTRY GUIDE 3.880 1D-127, 9/20/2023 4:04:06 PM Vertical schematic (actual) PRODUCTION; 41.1-7,415.9 IPERF; 6,962.0-7,002.0 IPERF; 6,918.0-6,932.0 IPERF; 6,876.0-6,882.0 PACKER; 6,806.0 IPERF; 6,744.0-6,770.0 PACKER; 6,721.0 IPERF; 6,662.0-6,698.0 GAS LIFT; 6,574.4 PACKER; 6,539.0 CIRC MANDREL; 6,437.6 GAUGE; 6,320.6 JET PUMP; 6,267.0 SLIP STOP; 6,265.5 GAS LIFT; 6,207.3 GAS LIFT; 4,543.5 NIPPLE; 495.7 CONDUCTOR; 42.0-121.0 KUP PROD KB-Grd (ft) 47.50 RR Date 7/8/1998 Other Elev 1D-127 ... TD Act Btm (ftKB) 7,432.0 Well Attributes Field Name WEST SAK Wellbore API/UWI 500292289000 Wellbore Status PROD Max Angle & MD Incl (°) 65.64 MD (ftKB) 5,056.89 WELLNAME WELLBORE1D-127 Annotation Last WO: End Date 9/1/2011 H2S (ppm) 10 Date 12/29/2015 Comment SSSV: NONE Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB)Top Incl (°)Des Com Make Model SN Run Date ID (in) 6,265.5 3,244.7 59.09 SLIP STOP Set 2 7/8" Slipstop on top of Jet Pump 8/27/2023 6,267.0 3,245.5 59.02 JET PUMP 2" RC JET PUMP (S/N: CP- 0005, 7B RATIO, 36" packing to packing), w/ Rock Screen and gauges (OAL = 116") on 2.25" C-Lock CP - 0005 8/27/2023 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl (°) St ati on No /S Serv Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Size (in) 4,543.5 2,495.5 64.51 1 GAS LIFT DMY BK 1 0.0 8/25/2023 0.000 6,207.3 3,216.0 61.85 2 GAS LIFT DMY BK 1 0.0 8/26/2023 0.000 6,437.6 3,342.0 52.86 3 GAS LIFT DMY BK-5 1 0.0 11/4/2011 0.000 6,574.4 3,427.0 50.51 4 GAS LIFT DMY BK-5 1 0.0 8/28/2011 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft)Type Com 6,662.0 6,698.0 3,483.8 3,507.8 WS D, 1D-127 9/24/1998 4.0 IPERF 0 de,g.phase down 6,744.0 6,770.0 3,538.6 3,556.1 WS B, 1D-127 9/22/1998 4.0 IPERF 0 deg phase, down 6,876.0 6,882.0 3,628.4 3,632.5 WS A3, 1D-127 9/17/1998 4.0 IPERF 0 deg phased down 6,918.0 6,932.0 3,657.4 3,667.1 WS A3, 1D-127 9/17/1998 4.0 IPERF 0 deg phase, down 6,962.0 7,002.0 3,687.9 3,715.9 WS A2, 1D-127 8/23/1998 4.0 IPERF 0 Deg phased, down 1D-127, 9/20/2023 4:04:06 PM Vertical schematic (actual) PRODUCTION; 41.1-7,415.9 IPERF; 6,962.0-7,002.0 IPERF; 6,918.0-6,932.0 IPERF; 6,876.0-6,882.0 PACKER; 6,806.0 IPERF; 6,744.0-6,770.0 PACKER; 6,721.0 IPERF; 6,662.0-6,698.0 GAS LIFT; 6,574.4 PACKER; 6,539.0 CIRC MANDREL; 6,437.6 GAUGE; 6,320.6 JET PUMP; 6,267.0 SLIP STOP; 6,265.5 GAS LIFT; 6,207.3 GAS LIFT; 4,543.5 NIPPLE; 495.7 CONDUCTOR; 42.0-121.0 KUP PROD 1D-127 ... WELLNAME WELLBORE1D-127 ~ . Pages NOT Scanned in this Well History File XHVZE 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. I 'Ii - /6/ File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: Grayscale, halftones, picturesýQraphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NolType OVERSIZED o Logs of various kinds o Other COMMENTS: (Ð3T~ Scanned by~ Beverly Mildred Daretheowen Date: -;:¿¡~( Isl ¡{J o TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Dareth80wen Date: 3/ 21 Is! ~ STATE OF ALASKA y ALASKA 11111AND GAS CONSERVATION COMMISSO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon f Repair w ell r Plug Perforations '-'" Stimulate r Other l� ESP to Jet Pump Alter Casing j Pull Tubing Perforate New Pool r Waiver f Time Extension fl Change Approved Program r Operat. Shutdow n r Perforate f `" Re -enter Suspended Well 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development pi Exploratory r 198 -109 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service - • 50-029-22890-000- 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 0 1D 9. Field /Pool(s): Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 7432 feet Plugs (measured) None true vertical 4026 feet Junk (measured) None Effective Depth measured 7286 feet Packer (measured) 6539, 6721, 6806 true vertical 3919 feet (true vertucal) 3405, 3523, 3581 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 PRODUCTION 7375 7.625 7416 4014 ,-kn.. � i ;� ` g M RECEIVED SEP 2 2011 Perforation depth: Measured depth: 6662'- 6698', 6744' - 6770', 6876'- 6882', 6918'- 6932', 6962' -7002' Alaska OiI & Gas Cons. Commission True Vertical Depth: 3484'- 3509', 3539'- 3557', 3630'- 3634', 3658'- 3668', 3688' -3716' Anchorage Tubing (size, grade, MD, and TVD) 2.875, L - 80, 6384 MD, 3310 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER PREMIER PACKER @ 6539 MD and 3405 TVD PACKER - BAKER PREMIER PRODUCTION PACKER @ 6721 MD and 3523 TVD PACKER - BAKER PREMIER PRODUCTION PACKER @ 6806 MD and 3581 TVD NIPPLE - CAMCO DS LANDING NIPPLE @ 496 MD and 491 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development • Service r Stratigraphic r 15. Well Status after work: Oil `7 Gas fl WDSPL I Daily Report of Well Operations XXX GSTOR r WIND r WAG 1 — GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -244 Contact Brett Packer @ 265 -6845 Printed Name Brett Packer Title Wells Engineer 7/7 Signature ��C -e Phone: 265 -6845 Date , / Form 10 -404 Revised 10/2010 Flees SEP 2 6 201f P- 7' ' it Submit Original Only K • KU P • 1 D -127 ConocoPhimps . . . " Well Attributes Max Angle & MD 1D Wellborn APPUWI Field Name Well Status Inc' ( °) MD (81613) Act Btm (ftKB) 500292289000 ( WEST SAK PROD 65 64 I 5,056 89 1,432 H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date •.. wen c9 r� Sttl,3ema, 9/,10hGt+ tt f�6 SB AM An SSSV: NONE 2 8/2/2002 (Last WO 9/28/2008 1 47.50 7/8/1998 _ ch Actual , 014110 IDepth (111(1 ) Dale Annotation - nnotation Last Mod .. End Date - - - Last Tag; 1_- 6,483.0 4/15/2008 Rev Reason: WORKOVER _�_ ninam 9/10/2011 Casing Strings HANGER, 39 ! dy0.' Casin Description String 0._ String ID... To (ftKB) Set Depth f... Set Depth (TVD) ... String Wt... Siring ... String Top Thrd 9 9 9 P ) P ( P ( 1 9 9 9 w - HANGER 36 - .+ 'CONDUCTOR 16 15.062 42.0 121.0 121 0 62.58 (140 WELDED . C �� Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) . String Wt Stn g ... String Top ThN M . < • PRODUCTION 7 5/8 , 6 750 41 2 7,415.9 4,014.2 _ , 29 70 L ABM - BTC CONDUCTOR R, Tubing Strings ' ,m Tubing Description Str ng 0... String ID _.Top (966) Set Depth (f... Set Depth (ND) Str g Wt... String I String Top Thrd NIPPLE, 496-- - -_ -_- TUBING 'String 2 //8 2 441 I 36.2 I 63844 I 3,3103 I 650 L80 1 EUE8RDMOD Gom_pletion¢ tails Top Depth ■ MID) Top Inc/ Nomi... Top (MB) (ftKB) (`) Item Description Comment ID (in) 36.2 36.2 -1 60 HANGER VETCO GRAY TUBING HANGER 2.441 GAS LIFT 495 491.3 15.94 NIPPLE CAMCO 2.313" DS LANDING NIPPLE 2.312 4,543 T . 6,266.5 3,245.3 58.92 WIRE GUIDE TEC WIRE GUIDE 2.500 6,267.6 3,245.9 58.87 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.25" D PROFILE 2.250 GAS LIFT, __ -- 6,271.6 3,247.9 58.70 WIRE GUIDE TEC WIRE GUIDE 2.500 6,207 6,320.6 3,274.3 56.65 GAUGE GUARDIAN SIDEMOUNT GAUGE CARRIER 2.500 '' 6,374.6 3,304.6 54.39 SEAL ASSY BAKER 80-40 GBH -22 SEAL ASSEMBLY 3 000 NIP 1 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wl... String ... String Top Thrd k 't iv I N Inner Casing String 5 1/2 4.950 37.7 6,517.4 3,391.2 15.50 L -80 BTC -M i s Completion Details il ,,,, I To �D)� Top Intl _ Nomi... ID To ftKB (�B) p �p( ) ( Itm Descrl tion Comment (in) 37.7 37.7 -1.58 HANGER VETCO GRAY CASING HANGER 4.950 6,370.7 3,302.4 54.56 SBR BAKER 8040 SEAL BORE EXTENSION 4.000 6,389.9 3,314.1 53.38 XO Reducing CROSSOVER 5.5 x 3.5 3.000 6,394.8 3,316.9 53.30 XO Reducing CROSSOVER 3.5 x 2.875 2.441 6,496.6 3,378.2 51.73 LOCATOR SPECIAL CLEARANCE LOCATOR SUB 2.441 569, 6,371 • I 6,498 -8 3,379.6 51.70 SEAL ASSY BAKER SEAL ASSEMBLY w/ 7 FT SPACE OUT 2.990 Tubing Description IStringO. (String ID... Top (fIX8) 'Set Depth (1... I Set Depth (ND) ( String 6 W8 50 ...I String... Stdng EUE Top Srd Thrd M __? Sand Selective 2 7/8 I l 2 441 6 491 0 6, 700 2 3,510 7 I l I l L 80 ID CompletttorLDetails Top Depth (1VD) Top Intl Nomi... _Top (f8K6) MO) 11 H mm Item Desmiptlon Comment ID (In) GAS LIFT•______ _ 6,491.0 3,374.7 51.82 SLEEVE BAKER HR LINER SETTING SLEEVE 5.750 s , 4 3e 6,503.7 3,382.6 51.62 NIPPLE BAKER RS NIPPLE 4.870 6,508.5 3,385.6 51.55 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 "7 , 6LEEVE,QTOR491 - 6,539.0 3,404.7 51.08 PACKER BAKER PREMIER PACKER 3.870 LOCA 6,497 6,556.8 3,415.8 50.80 XO Reducing CROSSOVER 4.5 x 2.875 2.420 NIPPLE, 6,504 6,629.6 3,462.5 48.72 SLEEVE-0 BAKER CMU SLEEVE w/ 2.25" PROFILE (IN OPEN POSITION) 2.250 SEAL ASSY, t - 6,677.6 3,496.1 48.33 XO Enlarging CROSSOVER 2.875 x 5.5 2.480 6,499 __ __ SBE, 6,508 - •J - I, SBE, 6,690.6 3,504.5 48.21 SEAL ASSY BAKER SEAL ASSEMBLY 4.810 Tubing Description String 0... String ID... Top HI KB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 BSand Straddle 4 1/2 3.958 6,691.2 6,832.0 3,598.3 12.60 L -80 IBT Packer PACKER, 6,539 - ? Completion Details Top Depth (ND) Top Intl Nomi... Top (ftKCB) (ftKB) (1 Item Description Comment ID (in) GAS LIFT, - . 6,691.2 3,504.8 48.21 SLEEVE HR LINER SETTING SLEEVE 5.750 6,574 6,703.8 3,513.1 48.09 NIPPLE RS PACK OFF SEAL NIPPLE 4.875 • 6,7210 3,524.3 47.94 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 SLEEVE 6,806.0 3,580.7 47.19 PACKER BAKER PREMIER PRODUCTION PACKER 3.875 6,630 s39 ' 6,830.7 3,597.4 46.97 WLEG WIRELINE ENTRY GUIDE 3.880 - Perforations & Slots _..... Shot Top (11/D) Btrn (TVD) Dens 7op(RKB)�f[KB5, (81(8) (ftKB) Zone Date (sh ... Type Comment IPERF, % 6,662 6,698 3,483.8 3,509.3 WS D, 10 -127 9/24/1998 4.0 IPERF 0 de,g.phase down 6,662 - 6,696 - -- - - I 6,744 6,770 3,539.4 3,556.6 WS B, 1D -127 9/22/1998 4.0 IPERF 0 deg phase, down - 6,876 6,882 3,629.5 3,633.5 WS A3, 10- 127 9/17/1898 4.0 IPERF 0 deg phased down SLEEVE,6,69t L- _ - 6,918 6,932 3,658.0 3,667.5 WS A3, 10-127 9/17/1998 4.0 IPERF 0 deg phase, down 1 f 6,962 7,002 3 688 2 3716 0 WS A2, 1D-127 8/23/1998 4 0 IPERF 0 Deg phased, down NIPPLE. 6,704 -,.__, 1 Notes: General Date I ral & Safety Annotation -. _.. 1 0/5/2008 NOTE: View Schematic w7 Alaska Schemat r9 0 PACKER, 6,721 ..: � ..: Mandrel Details IPERF. TO Top Ske 6,740 ( TVD) VD) Intl OD Valve Latch Size TRO Run Stn Top (ftKBL IPERF, 1' (ftKB) ( ") Make Model (in) Sery Type Type (in) (pCont... si) Run Date C 1 4,543.5 2491 7 62.18 CAMCO KBMG - M 1 GAS LIFT SOV BEK 0.000 0.0 8/30/2011 PACKER, 6,806 '�" "" - 2 6,207.3 3,217.9 61.39 CAMCO KBMG -M 1 GAS LIFT DMY BK-5 0.000 0.0 8/30/2011 WLEG, 6,831 - - 7'. 3 6,437.6 3,342.1 52.64 CAMCO KBMG -M 1 GAS LIFT DMY BK -5 0.000 0.0 8/30/2011 IPERF•_, - -_ 4 6,574.4 3,4263 49.21 CAMCO KBMG -M 1 GAS LIFT DMY BK -5 0.000 0.0 8/28/2011 6,876-5,882 -- -- - - PERF,_ 6,918 -5,932 -'` IPERF, 6,962- 7,002 PRODUCTION, 41- 7,416N TO, 7,432 • • CanaeoPhiIIips Time Log & Summary Wenview Web Repotting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/21/2011 3:00:00 AM Rig Release: 9/1/2011 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/21/2011 24 hr Summary Rig Move 1 D -102 to 1 D -127. Spot Rig over well. Accept Rig @ 03:00 hrs. MIRU all support equipment. Pull BPV. Pressure Test hard line, manifold and hoses 250/3500. Circulate well 9.6 ppg brine. Install BPV. ND and Inspect Tree. Set Blanking Plug. NU 11" 5M BOPE. 02:00 05:30 3.50 0 0 MIRU MOVE MOB P Move in Mats and spot equipment behind well 1D -127. Accept Nordic Rig 3 at 03:00 hrs on 8- 21 -11. Hang New Tree in cellar. 05:30 09:00 3.50 0 0 MIRU MOVE RURD P Spot and Level rig over well, Set down Nordic Rig 3 on Double mats. Spot and RU auxiliary equipment. 09:00 09:15 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM on pulling BPV with Lubricator. 09:15 10:00 0.75 0 0 COMPZ WHDBO MPSP P Lubricate out 3" - "H" BPV. Open up well TBG- 370 psi; IA - 380 psi. 10:00 11:00 1.00 0 0 COMPZ WELCTI PRTS P Pressure test hardline to kill tank and kill manifold at 250/3,500 psi - Good test. 11:00 12:00 1.00 0 0 COMPZ WELCTI OTHR P Load 160 ° - 8.6 ppg NaCI brine w/ 3% KCL 12:00 12:15 0.25 0 0 COMPZ WELCTI SFTY P Held PJSM with crew on well kill agenda. 12:15 19:00 6.75 0 0 COMPZ WELCTI CIRC P Reverse Circulate 350 bbls of "Hot" 8.6 IDIOCI NaCI taking returns to kill tank at 5 bpm @ 460 psi. FCP 600 psi. Reverse Circulate back to pit #1 with another 190 bbls of "Hot" 8.6 ppg NaCI at 3 bpm @ 200 psi w/ FCP of 110 psi. Off load rig pit #1 and spot 2nd dirty truck. Begin Reverse circulating with 242 bbls of • 9.6 ppg NaCI "KWF" @ 3 bpm @ 240 psi. FCP 120 psi. Shut down to swap trucks - Well balanced out at 0 psi on IA and 70 psi TBG. Continue Circulating another 100 bbls KWF- 3 bpm @ 240 psi, FCP 240 psi for 343 bbls total pumped. 19:00 19:30 0.50 0 0 COMPZ WELCTI OWFF P Monitor well, well balanced out SITP of 0 psi, SICP of 20 psi. 19:30 21:00 1.50 0 0 COMPZ WELCTI CIRC P Start Reverse Circulate at 3 bpm, ICP 240 psi, FCP 240 psi. Switch over to Circulate Long Way 157 bbls 9.6 ppg KWF taking returns to Kill Tank 3 bpm, ICP 240 psi, FCP 240 psi. 21:00 21:30 0.50 0 0 COMPZ WELCTI OWFF P Monitor well, well static with no flow on Tubing or Casing. Page 1 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:30 22:00 0.50 0 0 COMPZ WELCTL SEQP P Break Down and RD circulating hoses, Dry Rod in and Set 3" - "H" BPV 22:00 22:30 0.50 0 0 COMPZ WELCTL NUND P ND Tree, Hanger Lift Threads in good shape, Set Blanking Plug. 22:30 00:00 1.50 0 0 COMPZ WELLPF NUND P Begin NU 11" 5M BOPE. X8/22/2011 Continue NU 11" 5M BOPE. Test BOPE 250/3500 and Annular 250/3000. Pull Blanking Plug & BPV. Install Side Isolation Sleeve. Pull Hanger. Pull 3.5" ESP Completion. 00:00 00:30 0.50 0 0 COMPZ WELCTL NUND P Continue NU 11" 5M BOPE. 00:30 09:00 8.50 0 0 COMPZ WELCTL BOPE P RU test equipment, Shell test good. Pressure test BOPE 250/3500 and Annular 250 /3000. RD Test �► equipment. • Loaded 83 joints of 3.5" DP while testing BOPE. 09:00 09:30 0.50 0 0 COMPZ WELCTL MPSP P Pull Blanking plug and BPV 09:30 10:00 0.50 0 0 COMPZ RPCOM OTHR P Bring in boxes, RU Centrilift Tools and MU blanking plug retreival tool. 10:00 11:00 1.00 0 6,656 COMPZ RPCOM HOSO P MU Landing jt and BOLDS. Unland hanger at 125k and 95k up wt. Pull hanger 5 -ft above. 11:00 12:30 1.50 6,656 6,656 COMPZ WELCTL CIRC P Circulate 1 1/2 hole volumes at 4 bpm @ 420 psi. Bring inside after clean fluid was seen, Continue to circulate at 3 bpm @ 190 psi ICP and 190 psi FCP. Pumped a total of 317 bbls of 9.6 ppg KWF. 12:30 13:00 0.50 6,656 6,656 COMPZ WELCTI OWFF P Monitor well for flow - Static 13:00 14:15 1.25 6,656 6,568 COMPZ RPCOM PULL P Pull hanger to floor and disconnect Itec wire, Heat Trace and ESP Cable. Pull penetrators. Lay down hanger, pup jt and landing joint. Continue to POOH with 2 jts, removing Cannon clamps and string ESP and Heat trace cables down catwalk. 14:15 15:15 1.00 6,568 6,568 COMPZ RPCOM OTHR P Run ESP and Heat Trace cable over sheaves - found ESP Spooling unit not secured to rig structure. 15:15 16:45 1.50 6,568 6,500 COMPZ RPCOM OTHR T Cut ESP and Heat trace cable above Tool joint. Run back in the with smooth 3 1/2 TBG jt. Install 3 1/2 FOSV and closed Upper 3 1/2 Solid rams at 15:00 hrs. Filled out Hot work permit and installed 2 pad eyes for securing ESP Spooling unit to Rig structure. Closed out permit and re- opened well - Static. POOH and laying cable out into pipe shed, Run cables over ESP and Heat trace sheaves and connect to spooling units. Page 2 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:45 22:00 5.25 6,500 3,655 COMPZ RPCOM PULL P POOH with 3 1/2" ESP completion. Up wt 95k Standing back and strapping 3 1/2" tubing, spooling up ESP Cable / TEC Wire / Heat Trace to 3,655 -ft, End shoe of Heat Trace. Up wt 68k 22:00 00:00 2.00 3,655 1,747 COMPZ RPCOM PULL P Continue POOH w/ 3 1/2" ESP complition from 3,655 -ft to 1,747 -ft. Up wt 58k 08/23/2011 Continue pulling 3.5" ESP Completion. Box & send out ESP components. Load & Tally 2 7/8" DP, 3 1/2" DC & 4 3/4" DC. PU MU & RIH w/ Wellbore Cleanout & Casing Drift BHA and wash down to 7,190 -ft. 00:00 02:30 2.50 1,747 54 COMPZ RPCOM PULL P Continue POOH w/ 3 1/2" ESP completion from 1,747 -ft to Guardian Gauge. 02:30 04:00 1.50 54 0 COMPZ RPCOM PULL P POOH w/ ESP Components to surface. Preform and Record all readings. preform shaft rotation check. take samples, LD ESP components to shed. Clamp Count recovered: 5' mid -joint dual - channel HT clamps= 474 4' mid -joint dual - channel HT clamps= 3 3' mid -joint dual - channel HT clamps= 0 2' mid -joint dual - channel HT clamps= 0 Dual- channel HT end shoe clamp= 1 Dual- channel cross - coupling clamps= 94 Single- channel cross - coupling clamps= 64 Stainless -steel flat bands= 18 04:00 08:00 4.00 0 0 COMPZ WELLPF OTHR P Box and load out ESP components, clamps and equipment. Wrap spools for removal. clean pipe shed and floors. 08:00 09:30 1.50 0 0 COMPZ WELCTI BOPE P RU and Test 3 1/2 Solid upper rams and 3 1/2 EUE 8rd FOSV at 250/3,500 psi - good test. RD test equipment and pull test plug. These are the components used to secure well for welding down thee ESP spooler on the rig floor. 09:30 10:00 0.50 0 0 COMPZ WELLPF OTHR P Set wear ring 10:00 13:30 3.50 0 0 COMPZ WELLPF OTHR P Bring in remainder of 3 1/2" DP, 2 7/8" PAC DP, 4 3/4" DC's. Rack and Tally. Bring Scraper BHA components. 13:30 13:45 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with rig crew and Baker service rep. on making up BHA and RIH. Page 3 of9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:45 15:00 1.25 0 585 COMPZ WELLPF PULD P PU and MU 2 7/8 Mule shoe and RIH on 19 joints of 2 7/8 PAC drill pipe to 585 -ft. 15:00 15:30 0.50 585 630 COMPZ WELLPF PULD P PU, MU and RIH from 585 -ft to 630 -ft with Polish mill and 7 5/8 CSG _ Scraper components along bumper sub and jar. 15:30 16:00 0.50 630 906 COMPZ WELLPF PULD P PU, MU and RIH from 630 -ft to 906 -ft. with 9 -4 3/4" OD DC's. 16:00 22:30 6.50 906 6,929 COMPZ WELLPF PULD P PU, MU and RIH with 3 1/2 DP from 906 -ft to tag at 6930 -ft. 22:30 23:30 1.00 6,929 7,190 COMPZ WELLPF FCO P Wash down from 6,930 -ft to 7,190 -ft. Circulating at 3 -bpm at 410 psi. 23:30 00:00 0.50 7,190 7,190 COMPZ WELLPF FCO P Reverse circulate 189 bbls at 3 bpm at 250 psi ICP; 400 psi FCP. 130k up wt. 65k dn wt. X8/24/2011 Continue to reverse circulate fill out of the hole, RIH w/ Wellbore Cleanout & Casing Drift BHA. POOH & LD BHA #1. PU MU & RIH w/ Surface Casing Testing BHA. Set RBP. Test RBP. to Test Packer & Backside to Surface. Place 10 -ft sand on RBP. POOH & LD Test Packer. 00:00 01:00 1.00 7,190 7,190 COMPZ WELLPF FCO P Continue to Reverse circulate 189 bbls at 3 bpm at 250 psi ICP; 400 psi FCP. 130k up wt. 65k dn wt. 01:00 02:30 1.50 7,190 7,278 COMPZ WELLPF FCO P RIH with last of DP to tag at 7278 -ft RKB. POOH rotate down to 7278 -ft confirm entry to bottom of b -sand straddle. 02:30 04:30 2.00 7,278 7,263 COMPZ WELLPF FCO P PUH 15 ft, pump sweep down backside, reverse circulate @ 3 bpm at 320 psi for 367 bbls. slowly come down on pump, Re tag 7,278 -ft. RKB 04:30 06:30 2.00 7,263 7,263 COMPZ WELLPF OWFF P Monitor well, BDTD, and load pits with 9.6 ppg KWF. - well giving back 8/10 bbl per hour on trip tank. DP was static. 06:30 08:00 1.50 7,263 7,263 COMPZ WELLPF CIRC P CBU (247 bbls) at 3 bpm at 350 psi ICP, 420 psi ICP. 08:00 08:30 0.50 7,263 7,263 COMPZ WELLPF OWFF P Monitor well - Static 08:30 12:30 4.00 7,263 906 COMPZ WELLPF TRIP P POOH with 3 1/2 DP from 7,263 -ft to 906 -ft. 12:30 14:30 2.00 906 0 COMPZ WELLPF PULD P POOH laying down 9 -4 3/4" OD DC's, Baker 7 5/8" CSG scraper and 5.64" OD Polishing mill, and 19 jts of 2 7/8 PAC DP. Calculated displacement for trip was 41.6 bbls and actual was 47.5 bbls. 14:30 15:30 1.00 0 0 COMPZ WELLPF OTHR P Off load DS pipe shed of BHA #1 and Re load DS pipeshed with BHA #2. 15:30 20:00 4.50 0 6,645 COMPZ WELLPF TRIP P PU and MU 7 5/8" Retrievamatic packer and "G" Lockset RBP. RIH on 3 1/2 13.30# DP to 6845- mid element, set RBP, Page 4 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 6,645 6,524 COMPZ WELLPF PRTS P PUH to 6524 mid element, set test packer.Conduct successful pressure test of RBP to 1500 psi. Close pipe rams, Pressure test casing to 1500 psi. Good test. Release test packer, RIH to 6585 -ft, dump 300# of 20/40 sand, chase with 25 bbls down drill pipe at 1 bpm. 08/25/2011 RU HES E -line Unit, RIH w/ Gyro and GR /CCL. Log from 6,645 ❑f back to surface. RIH w/ PDS 40 -arm caliper for 7 . 0 casing and GR /CCL. Log from 6,645 ❑f back to surface. RIH w/ 7 . h Baker Atlas MicroVertilog and GR/CCL. Log from 6,645 0f back to surface. 00:00 04:00 4.00 6,524 0 COMPZ WELLPF TRIP P POOH standing back Drill pipe in preperation for HES E -line. 04:00 04:30 0.50 0 0 COMPZ EVALWE SFTY P Held PJSM with E line and Rig crew on RU. 04:30 05:15 0.75 0 0 COMPZ EVALWE ELOG P Rig up HES E -line. 05:15 11:30 6.25 0 6,645 COMPZ EVALWE ELOG P RIH w/ Gyro logging tools to 6,645 -ft and log back to surface. 11:30 14:00 2.50 0 0 COMPZ EVALWE ELOG P RIH w/ PDS 40 ARM caliper logging tools to 6,645 -ft and log back to surface. 14:00 23:00 9.00 0 0 COMPZ EVALWE ELOG P RIH w/7 5/8" Baker Atlas micro vertilog and GR /CCL. Log from max achievable depth of 4700ft to surface. 23:00 00:00 1.00 0 0 COMPZ WELLPF NUND P Swap out floor equipment, Rig up bha #3. 08/26/2011 MU RBP retrieving assembly on 3 %2 tubing, RIH to - 3,0006 RKB. MU storm packer and set storm packer at -1006 MD w/ tubing hanging below. PT storm packer to 3,500 psi. ND BOP and tubing head. Install new Vetco Gray 5' /s6 casing head and new tubing head. 00:00 05:00 5.00 0 2,929 COMPZ WELLPF MPSP P MU RBP retrieving assembly on 3 %2 6 tubing, RIH to 24626 RKB. MU storm packer and set storm packer at -1006 MD w/ tubing hanging below. Unable to get good PT, Add 5 more stands of 3 1/2 TBG. RIH to 2929 -ft RKB, set storm packer at 100 -ft. 05:00 16:30 11.50 0 94 COMPZ WELLPF PRTS T Attempt to pressure test surface to Storm packer at 100 -ft at 3,500 psi to establish base line - had significant bleed off multiple times attempting to Isolate any leaks. Pull storm packer and replace with retrievamatic packer and set at 95 -ft, pressure up to 3,500 psi - solid test. POOH and change out unloader valve. RIH and set Storm packer at 94 -ft - Release off Storm Packer. Pressure test at 3,500 psi - solid test for baseline to compare NU test to. RD test equipment. 16:30 16:45 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with crew on ND BOPE and Vetco Gray Uni -head. 16:45 20:00 3.25 0 0 COMPZ WHDBO NUND P ND BOPE and Vetco Gray 11" 5M Uni Bowl Uni Head Page5of9 II • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:00 00:00 4.00 0 0 COMPZ WHDBO NUND P Break 11" 5M Casing head from 11" 5M Multi Bowl Uni head - Rotate 90° to the right. NU 11" 5M Casing head to 11" 5M Multi Bowl Uni head. Slip over 7 5/8" 29.7# Casing stub and lock down. NU 11" 5M BOPE stack. 38/27/2011 Pull & lay down storm packer. Continue RIH to the top of sand, circulate out sand down to top of plug. 00:00 02:30 2.50 0 0 COMPZ WHDBO NUND P Break 11" 5M Casing head from 11" 5M Multi Bowl Uni head - Rotate 90° to the right. NU 11" 5M Casing head to 11" 5M Multi Bowl Uni head. Slip over 7 5/8" 29.7# Casing stub and lock down. NU 11" 5M BOPE stack. 02:30 03:30 1.00 0 0 COMPZ WHDBO OTHR P Set wear ring 03:30 10:00 6.50 0 0 COMPZ WHDBO PRTS P Pressure test breaks from 7 5/8 CSG head install to below blind rams to 250/3,500 psi_ test against Storm packer set at 94 -ft. 10:00 10:30 0.50 94 0 COMPZ WHDBO PULL P Release storm packer and pull to surface from 94 -ft. Lay down same. 10:30 12:30 2.00 3,295 6,620 COMPZ WELLPF TRIP P Continue to RIH with 3 1/2 TBG and RBP retrieving head from 3,295 -ft to 6,620 -ft 12:30 15:30 3.00 6,620 6,635 COMPZ WELLPF CIRC P MU top drive and begin washing down to 6,635 -ft and latch into Baker, "G" RBP - attempt to release off plug - had to work multiple times to release off RBP. PU off plug and close Annular. Pump 30 sweep 3 bpm at 180 psi and reverse circulate 283 bbls at 7 bpm at 865 psi. 15:30 hrs Ran out of fluid as sweep reached surface. 15:30 17:00 1.50 6,625 COMPZ WELLPF CIRC T Waiting for Vac truck to load and offload into pits. 17:00 22:00 5.00 6,635 6,635 COMPZ WELLPF CIRC P Wait for fluids to be filtered and loaded in pits, pump 77 bbls at 5 bpm reversing to finish circulating out pill pumped earlier. Offload more fluid in pits. 22:00 00:00 2.00 6,635 6,625 COMPZ WELCTL PULL P RIH, latch RBP at 6636 tbg MD, pu wt is 83, Released RBP, puh 10ft, start to circulate down tubing, 5 bmp, 250 psi, 08/28/2011 Engage fishing neck, release plug and allow elements to relax. Circulate 1.5 hole volumes, monitor well, POOH laying down tubing, lay down RBP. RIH w/ the selective assembly to just above the HR liner setting sleeve at 6,691e, RKB. Set Packer, pressure test to 500 psi. POOH standing back drillpipe, lay down inner string and setting tools. 00:00 01:30 1.50 6,625 6,625 COMPZ WELCTL CIRC P Start to circulate down tubing, 5 bmp, 250 psi, Pump total of 338 bbls. 01:30 02:00 0.50 6,625 6,625 COMPZ WELCTL OWFF Monitor well for 30 min, 1.2 bbl per hour loss. Page 6 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 10:00 8.00 6,625 0 COMPZ WELLPF PULD P POOH from 6,625 -ft with 3 1/2 TBG laying down, lay down RBP. Clean and clear pipe shed. 10:00 10:15 0.25 0 0 COMPZ WELLPF SFTY P Held PJSM with crew on PU and RIH w/ "D" sand selective. 10:15 13:00 2.75 0 214 COMPZ WELLPF PULD P Pick up and RIH w/ "D" sand selective BHA to 214 -ft. 13:00 14:00 1.00 214 2,244 COMPZ WELLPF TRIP P RIH w/ "D" sand selective on 3 1/2 Drill pipe to 2,244 -ft, 14:00 14:15 0.25 2,244 2,244 COMPZ WELLPF SFTY P Held PJSM on Hangiong blocks and Slip and cut of drill line. 14:15 15:30 1.25 2,244 2,244 COMPZ WELLPF SLPC P Slip and cut 84 -ft of 1 -1/8" Drill line. 15:30 22:00 6.50 2,244 6,685 COMPZ WELLPF TRIP P Continue to RIH w/ "D" sand selective on 3 1/2 Drill pipe from 2,244 -ft to 6685 MD. RIH to tag on no go, puh to up wt +1ft, pump ball, set packer. Packer at 6533 MD. Confirm packer was set, Pressure test to 500 psi. PUH, monitor well for 30 min. 22:00 00:00 2.00 6,685 5,000 COMPZ WELLPF TRIP P POOH standing back 30 stands and laying down 120 joints. 08/29/2011 POOH standing back drillpipe, lay down inner string and setting tools. Conduct weekly BOP test. Start running 5 1/2" inner casing string. 00:00 04:00 4.00 5,000 0 COMPZ WELLPF TRIP P POOH standing back 30 stands and laying down joints. ® 04:00 17:00 13.00 0 0 COMPZ WELLPF BOPE P Conduct ct weekly BOP test. < 17:00 18:00 1.00 0 0 COMPZ WELLPF RCST P PJSM, Riq up to run 5.5 inner casing. , 18:00 00:00 6.00 0 5,500 COMPZ WELLPF RCST P Run 5'/i' L -80 BTCM -SCC Inner _ Casing String, 08/30/2011 Finish running 5 1/2" inner casing string, PT the back side to 500 psi. Reverse circulate 115 bbls corrosion inhibited KWF brine to load the 5'/2' x 7 " annulus.Sting back into the SBE and land the 5 %2" PT casing hanger packoffs to 250/5,000 00:00 02:00 2.00 5,500 6,518 COMPZ WELLPF RNCS P Run 51/2' L -80 BTCM -SCC Inner Casing String, No go out at 6517.5 -ft. PT back side to 500 psi for 10 min, good test. PUH 40 -ft to start backside circ, 02:00 03:00 1.00 6,518 6,483 COMPZ WELLPF CIRC P Reverse circulate 115 bbls corrosion inhibited KWF brine down the 5 %" x 7 5/8" annulus. 03:00 05:00 2.00 6,483 6,510 COMPZ WELLPF RNCS P • Sting back into the SBE and land the 5 %2' casing hanger. PT the 5 1 /2' x 7 5/8" annulus to 1500 psi. PT casing hanger packoffs to 250/5,000 psi. 05:00 06:00 1.00 6,510 0 COMPZ WELLPF BOPE P Install 2 7/8 x 5" VBR's in lower pipe rams. 06:00 07:00 1.00 0 0 COMPZ WELLPF PRTS P Set test Plug and Install test joint and test Lower Pipe Rams 250/3500 psi. Pull test plug. 07:00 15:30 8.50 0 0 COMPZ WELLPF PULD P Load,Drift and tally all tubing, pups and completion equipment. Page 7 of 9 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:30 16:00 0.50 0 0 COMPZ WELLPF SFTY P PJSM. Discuss hazard with running completion. 16:00 17:00 1.00 0 100 COMPZ WELLPF PUTB P Perform finial Completion Equipment inspection. Start Running 2 7/8" L -80, 8rd EUE -Mod gas LifUJet Pump Completion. Run TEC Wire and secure with Cannon single - channel cross couplings at every tubing collar connection. 17:00 00:00 7.00 100 5,308 COMPZ RPCOM PUTB P Continue to single in with the 2 7/8" GUJet Pump Completion as designed. Up Weight = 65K. Down Weight = 47K. Perform TEC Wire checks every 1,000 -ft. 38/31/2011 Complete Running the 2 7/8" GUJet Pump Completion as designed. Locate and space -out completion. Circulate Well over to 9.6 lb/gal Brine w /Corr Inhib. MUTbg Hanger. Land Tbg. RILDS. PT Packoff. Drop SV. PT Tbg. PT the 5 1/2" x 2 7/8" Annulus. 00:00 02:00 2.00 5,308 6,370 COMPZ RPCOM PUTB P Continue to single in the 2 7/8" GL/Jet Pump Completion as designed. No -Go on the 5 1/2" Inner Seal Bore Extention at 6,370 -ft. Space out to include 8 -ft "Stick -up. Total SS Bands used = 6 ea. Total Single Channel Cross Coupling Cable Clamps = 200 ea. 02:00 04:00 2.00 6,335 6,335 COMPZ RPCOM THGR P Make up Tubing Hanger and Pick up Landing Joint. Install Dummy ESP Penetrator and TEC Wire Penetrator. Splice TEC Wire and test same. 04:00 05:00 1.00 6,335 6,335 COMPZ RPCOM CIRC P Circulate Well bore with 9.6 lb/gal Brine w /Corrosion Inhibitor at 3.0 bpm460 psi. 05:00 05:15 0.25 6,335 6,374 COMPZ RPCOM PUTB P Sting back into SBE and land Tubing Hanger. RILDS. 05:15 05:30 0.25 6,374 6,374 COMPZ RPCOM PRTS P Pressure Test Hanger to 250/5000 psi for 15 mins 05:30 08:00 2.50 0 0 COMPZ RPCOM PRTS P Rig up Circulating Equipment. Make sure TBG is fluid packed. Drop Standing Valve, wait 20 mins to free fall. Start pumping down tubing to seat standing valve at 3 bpm, 1000 psi. No Luck after two volume pumped. 08:00 10:00 2.00 0 0 COMPZ RPCOM OTHR T Standby for slick -line to Rig down and travel from 2T -pad. 10:00 10:45 0.75 0 0 COMPZ RPCOM SFTY T Slick -line and Crew on Location. Hold PJSM with HES and Nordic. 10:45 13:45 3.00 0 0 COMPZ RPCOM PULD T MIRU Slick -line unit and Load Pressure Control Equipment and Lubricator. Load Slick -line Tools to Rig Floor. 13:45 14:00 0.25 0 0 COMPZ RPCOM SLKL T R/U and RIH with 3" GR, sat down and Latched the 2.25" Cat Standing _. Valve at 24 ft.POOH,and Lay down the same. Page 8 of 9 M • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 14:30 0.50 0 0 COMPZ RPCOM SLKL T MU and RIH with 2.29" gauge ring. Unable to get passed Tubing hanger. POOH and lay down the same. 14:30 15:15 0.75 0 0 COMPZ RPCOM SLKL T MU and RIH with the 2.25" Standing Valve on SLick -line. Unable to work passed tubing hanger. POOH and lay down the same. 15:15 15:45 0.50 0 0 COMPZ RPCOM SLKL T Stand back Slick -line Lubricator and Tools. 15:45 16:15 0.50 0 0 COMPZ RPCOM OTHR T Pull and Inspect Landing Joint. ID of Landing Joint was 2 -1/8" . Drain Stack. 16:15 20:00 3.75 0 0 COMPZ RPCOM SLKL T RU Standing Valve on Slick -line below Landing Joint. RIH with the Standing Valve and set in the "D" profile in the sSliding Sleeve at 6,287 -ft slmd. POOH and rig dow S -Line. 20:00 22:00 2.00 0 0 COMPZ RPCOM PRTS P Pressure test the tubing to 2,500 psi x 15 minutes. Good. Block in Tubing pressure. Pressure up on the 5 1 /fix 7/8" tubing annulus to 3,500 psi x 30 minutes. Good. Bleed the Annulus side down to "0" psi. Bleed the Tubing side down to "0" psi. Preassure back up on the Annulus and shear open the SOV at 2,900 psi. Recorded all test on a chart. Pump both directions at 2 bpm to confirm communications. Rig down test equipment. Lay down Landing Joint. 22:00 00:00 2.00 0 0 COMPZ WHDBO NUND P Drain BOP Stack. Install BPV. Swap out upper Pipe Rams to 3 1/2" solids. Inspect Blind Rams. 09/01/2011 Nipple down BOP Stack. Nipple up Tree and test same. Freeze protect Well with Diesel. Secure Cellar. Release Rig. Move off Well. MIRU at 1D-116 Well Slot. 00:00 03:30 3.50 0 0 COMPZ WHDBO NUND P Replace Blind Ram rubbers. Nipple down BOP Stack and set back on ssump, 03:30 05:30 2.00 0 0 COMPZ WHDBO NUND P Nipple up Production Tree. ._. 05:30 08:15 2.75 0 0 COMPZ WHDBO PRTS P PJSM. R/U Testing Equipment and Pressure Test Tree at 250/5,000 psi. 08:15 08:30 0.25 0 0 COMPZ WHDBO SFTY P PJSM with Little Red and Nordic Crew. 08:30 11:00 2.50 0 0 COMPZ WHDBO FRZP P PJSM. Pull BPV and Set TWCV. Reverse Circulate 110 bbls of Diesel to Freeze Protect TBG x IA. Rig down Little Red and Pumping Equipment. 11:00 12:00 1.00 0 0 COMPZ WHDBO MPSP P Pull TWCV and Install Type "H" BPV. Rig Release. Page 9 of 9 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 26, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • !:' .,, . .v ' _ . ! 4i RE: Multifinger Imaging Tool (MIT): 1D -127 Run Date: 8/14/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1D -127 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 22890 -00 `� � PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: PW 11 Signed: la—C J �. ) 8- 169 • • WELL LOG TRANSMITTAL PROACTIVE DIAGNOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 S 3 I 1) Caliper Report 24- Aug -11 1D-127 1 Report / CD 50- 029 - 22890-00 2) Signed : Date : — 11 Print Name: I� w ear klti�- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAX: (907)245 - 8952 E -MAIL : PDSANCHORAGE(Ca.MEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\DisMbution\ Transmitt alSheets \ConocoPluilips_Transmit.docx 1 • Multi- Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D -127 Log Date: August 24, 2011 Field: Kuparuk (West Sak) Log No.: 6313 State: Alaska Run No.: 3 (2 x MTT, 1 x MIT) API No.: 50- 029 - 22890 -00 Pipet Desc.: 7.625" 29.7 Ib. L-80 ABM -BTC Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 6,635 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection COMMENTS : 1 This log is correlated to the SLB Ultrasonic Imager dated July 7, 1998. This log was run to assess the condition of the surface casing with respect to corrosive and mechanical damage, as well as to identify areas of buckling or ID restriction due to subsidence. The caliper recordings indicate the 7.625" surface casing logged appears to be in good condition, with the exception of a 61% wall penetration recorded in an area of apparent wear in joint 5 (244') and a 22% wall ' penetration recorded at an isolated pit in joint 155 (6,603'). No other significant wall penetrations, areas of cross - sectional wall Toss or I.D. restrictions are recorded throughout the surface casing logged. The caliper recordings indicate slight buckling from —400' to —650'. A 3 -D log plot overlay of the centered and off - center caliper recordings highlighting the areas of slight buckling is included in this report. Although PDS has run a Magnetic Thickness Tool (MTT) twice in this well, this is the first time a PDS caliper has been run. 1 MAXIMUM RECORDED WALL PENETRATIONS: Apparent Wear ( 61%) Jt. 5 @ 244 Ft. (MD) Isolated Pitting ( 22%) Jt. 155 @ 6,603 Ft. (MD) No other significant wall penetrations (> 18 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall loss (> 7 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the surface casing logged. 1 1 Field Engineer: D. Cain Analyst: C. Waldrop Witness: R. Dolcator 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E-mail: PDS amemoryiog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 ict- POI 1 • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (West Sak) Well : 1D-127 Date : August 24, 2011 I Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing. Maximum Diameter Depth 3 -D Log (Off - Center) Image Map (Off- Center) 3 -D Log (Centered) Image Map (Centered) ■ 6 inches Minimum Diameter 8 1ft:800ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° I 6 inches 8 I 6 Nominal I.D. inches 8 ■ 50 _ ■ > 100 e 150 ■ I 200 ,: I • I 1 ■: . A 1 I: 250 i ' III 300 * - 1 : 1 -- 350 t■ all 1 i. - IN , � - 400 __ il MIN Si ■ Y MINI ..,,r Mil II 1 r/■ 450 e: 1 _ T I VIM 500 ' 1 1 I • ■MO11111111111111111111 -- ■■■tti■ 550 �� = I _ ■ ■■F�l■■ 3 •■ ■Fly ■■■E) 600 MINEHIMINIE -- 1 ■ ■■1t■ ■■ s5o -_ ■ ■ii iia■■ _ ■ ■■iti ■■■ -. ....ii __ ■ - 1111111 =- ,. ■ ■ ■.IZI■■ 700 = ■■ ■11111■■ n - ■ ■ MMI7 ■■ ■■ - �■ ■tai •■ ■■ - 1 •It 750 ■■ ■r ... ■■■V1■■ II Normium ■■■FtF■ 800 _ : ■■■1M■ t _ ■ ■ ■rt�■i■■ - - I ■■ ■N MEW 850 I ■■■tIl■ ■ ■■ ■■■FII■■■■ ■■■lit 900 I ■■■W I ■ ■Ef ■ ■ ■■ _ M _ ■■■fli■ ■ SI . ■■■ ' 950 MIIII■.OI I F ■■ ■ill ' ..r" ■■■iIl■■■■ _ =MEI 1I■ ; .' ■ ■ ■ial■■ 1 000 CZ ■■At■■■ ■ 41 IN , V ` ,�. : 1050 - _ _ ii ME■■ ■_ - ■■ Nominal I.D. I 6 inches 8 Minimum Diameter 6 inches 8 I Maximum Diameter Depth 3 -D Log (Off- Center) Image Map (Off - Center) 3 -D Log (Centered) Image Map (Centered) 6 inches 8 lft:800ft ! ° 1 1 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° 1 1 • • Correlation of Recorded Damage to Borehole Profile I ad Pipe 1 7.625 in. (52.2' - 6633.6') Well: 1 D -127 Field: Kuparuk (West Sak) I Company: ConocoPhillips Alaska, Inc Country: USA Survey Date: August24, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 55 1 10 442 I 20 866 30 1289 I 40 1717 50 2143 1 60 2573 14111111 70 3000 E 80 3421 c o Z s • c 90 3842 Q- o °' 0 100 4256 I 110 4664 120 r 5087 1 130 r 5511 140 I 5937 I 150 636 5 f Trr- I 155.2 6634 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 I Bottom of Survey = 155.2 1 • • i 1 C___VPDS Report Overview �--�w. Body Region Analysis I Well: 1D -127 Survey Date: August24, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7.625 in. 29.7 ppf L -80 ABM -BTC Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 7.625 in. 29.7 ppf L -80 ABM -BTC 6.875 in. 7.625 in. 6.0 in. 6.0 in. I Penetration(% wall) Damage Profile (% wall) 200 Penetration body Metal loss body 0 50 100 I 0 150 100 lb 11E- 111 50 0 I 0 to 20 to 40 to over 20% 40% 85% 85% 50 Number of joints analysed (total = 158) 156 1 1 0 I Damage Configuration ( body ) 10 1 100 5 1 0 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole 150. ' Number of joints damaged (total = 10) _ 9 0 0 1 0 Bottom of Survey = 155.2 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf L80 ABM -BTC Well: 1D-127 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. Country: USA Survey Date: August24, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 52 0 0.02 5 1 6.85 Pug 1 55 0 0.04 10 2 6.84 2 98 0 0.03 8 2 6.79 3 141 0 0.04 10 2 6.81 4 184 0 0.04 11 2 6.82 I 5 227 0 0.23 61 6 6.80 Apparent Wear. 6 270 0 0.06 17 2 6.78 Shallow Line of Pits. 7 313 0 0.05 13 4 6.79 Shallow Pitting. 8 356 0 0.04 10 6 6.79 I 9 399 0 0.07 18 3 6.80 Shallow Pitting. Slight Buckling. 10 442 0 0.04 10 5 6.81 Slight Buckling. 11 484 0 0.04 10 4 6.82 Slight Buckling. 12 525 0 0.04 11 7 6.84 Slight Buckling. I 13 568 0 0.03 9 3 6.81 Slight Buckling. 14 611 0 0.03 9 3 6.83 Slight Buckling. 15 653 0 0.04 10 1 6.84 16 695 0 0.04 10 6 6.80 17 739 0 0.03 7 3 6.78 18 780 0 0.03 8 1 6.82 19 823 0 0.04 12 6 6.81 20 866 0 0.03 7 2 6.81 21 908 0 0.02 6 3 6.76 I 22 951 0 0.02 5 1 6.80 23 994 0 0.03 7 2 6.79 24 1034 0 0.02 6 2 6.82 25 1076 0 0.03 8 2 6.84 I 26 1119 0 0.02 6 I 6.83 27 1161 0 0.03 7 1 6.82 28 1204 0 0.02 6 2 6.79 29 1246 0 0.02 6 1 6.79 I 30 1289 0 0.02 6 2 6.81 31 1332 0 0.03 8 2 6.80 32 1375 0 0.03 7 1 6.81 33 1418 0 0.02 5 I 6.77 1 34 1460 0 0.02 6 2 6.79 35 1503 0 0.03 9 1 6.84 36 1546 0 0.03 7 1 6.84 37 1589 0 0.03 8 2 6.79 38 1631 0 0.03 7 2 6.82 I 39 1674 0 0.02 5 2 6.81 40 1717 0 0.03 8 2 6.85 41 1760 C) 0.03 7 2 6.83 42 1803 0 0.02 6 2 6.84 I 43 1846 0 0.03 7 6.83 44 1888 0 0.04 11 1 6.80 45 1930 U 0.04 9 1 6.81 46 1973 0 0.03 8 2 6.83 I ii 47 2016 0 0.03 9 2 6.82 ll 48 2059 C) 0.04 9 2 6.80 49 2100 0 0.02 6 1 6.83 ' Penetration Body Metal Loss Body Page 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf LSO ABM -BTC Well: 1D-127 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA Survey Date: August 24, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 2143 0 0.03 7 2 6.83 51 2187 0 0.03 9 2 6.81 52 2231 0 0.03 7 2 6.77 53 2272 0 0.04 11 2 6.81 I 54 2315 0 0.03 7 2 6.82 55 2359 a 0.03 7 2 6.83 56 2401 0 0.03 7 2 6.80 57 2444 O 0.03 7 2 6.79 58 2487 (1 0.03 7 2 6.78 I 59 2530 0 0.03 7 2 6.83 60 2573 0 0.03 9 2 6.81 61 2616 0 0.03 7 1 6.83 62 2659 (1 0.02 6 2 6.81 I 63 2702 64 2745 0 0.03 7 2 6.83 0 0.04 10 2 6.80 65 2785 0 0.03 7 2 6.83 66 2828 0 0.03 8 2 6.78 I 67 2871 0 0.03 8 2 6.79 68 2911 0 0.03 7 2 6.78 69 2954 0 0.03 8 2 6.82 69.1 2997 0 0 0 0 6.80 Gemoco'754' Stage Cementing Tool 70 3000 0 0.03 8 2 6.78 I 71 3043 0 0.04 11 3 6.79 72 3083 0 0.03 7 2 6.84 73 3126 0 0.02 5 1 6.79 74 3169 0 0.03 7 2 6.79 I 75 3206 0 0.03 9 2 6.79 76 3249 0 0.02 6 2 6.82 77 3292 0 0.03 8 2 6.80 78 3335 0 0.03 9 2 6.83 I 79 3378 0 0.03 7 2 6.81 80 3421 0 0.02 6 2 6.80 81 3463 0 0.03 8 2 6.83 82 3501 O 0.03 8 1 6.81 1 83 3544 0 0.03 8 2 6.78 84 3588 0 0.03 7 1 6.83 85 3631 0 0.03 9 1 6.82 86 3674 0 0.03 8 2 6.79 87 3717 O 0.03 7 2 6.81 I 88 3760 89 3803 0 0.04 10 2 6.81 0 0.03 8 2 6.82 90 3842 0 0.03 9 2 6.82 91 3881 0 0.02 6 2 6.80 I 92 3925 0 0.03 8 1 6.80 93 3967 0 0.03 7 2 6.80 94 4009 0 0.03 7 2 6.82 95 4052 0 0.03 7 2 6.78 I 96 4091 0 0.04 11 2 6.82 • 97 4134 0 0.04 9 2 6.79 98 4177 0 0.03 8 2 6.79 Penetration Body 111 Metal Loss Body Page 2 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf LSO ABM-BTC Well: 1D-127 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA Survey Date: August24, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 99 4220 0 0.03 8 2 6.82 100 4256 0 0.04 10 2 6.83 101 4299 0 0.03 8 1 6.82 102 4342 0 0.04 9 2 6.77 I 103 4383 0 0.03 9 2 6.79 104 4422 0 0.03 9 2 6.83 105 4465 0 0.03 7 2 6.78 106 4501 0.03 7 2 6.78 107 4543 0.03 8 2 6.78 I 108 4587 0.03 9 2 6.79 109 4622 0 0.02 6 1 6.82 110 4664 0 0.03 7 2 6.80 111 4707 0 0.03 7 1 6.79 I 112 4750 0 0.02 6 2 , 6.77 113 4792 0 0.03 7 2 6.78 114 4834 0 0.03 7 2 6.78 115 4875 0 0.03 8 1 6.79 I 116 4918 0 0.02 6 2 6.74 117 4961 0 0.03 8 2 6.79 118 5003 0 0.02 6 2 6.80 119 5045 0 0.03 8 2 6.79 120 5087 0 0.03 7 2 6.79 I 121 5128 0 0.03 7 2 6.80 122 5171 0 0.03 8 2 6.83 123 5215 0 0.03 8 2 , 6.80 124 5258 0 0.03 8 2 6.83 I 125 5301 0 0.03 7 1 6.81 126 5345 0 0.03 7 2 6.81 127 5387 0 0.03 8 2 6.80 128 5426 0 0.03 7 2 6.80 I 129 5468 0 0.03 7 2 6.82 130 5511 0 0.02 6 2 6.83 131 5554 0 0.02 6 2 6.80 132 5593 0 0.02 5 2 6.78 I 133 5636 0 0.03 7 , 1 6.82 134 5680 0 0.03 9 2 6.79 135 5723 0 0.03 9 2 6.79 136 5765 0 0.04 11 2 6.83 137 5808 0 0.02 6 2 6.79 I 138 5851 0 0.03 7 2 6.80 139 5894 0 0.04 12 1 6.82 140 593 7 0 0.03 7 2 6.78 141 5980 0 0.03 7 2 6.79 I , I 142 6023 0 0.03 8 1 6.80 143 6067 0 0.02 6 2 6.80 144 6110 0 0.02 6 2 6.78 145 6153 0 0.04 10 2 6.79 I 146 6195 0 0.03 9 2 6.80 147 6238 0 0.03 7 2 6.82 148 6281 0 0.03 8 2 6.76 I I Penetration M Body etal Loss Body Page 3 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf LSO ABM -BTC Well: 1D-127 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. Country: USA .Survey Date: August 24, 2011 I Joint Jt. Depth Len. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 149 6323 0 0.03 9 2 6.77 150 6365 0 0.03 7 2 6.77 151 6408 0 0.04 12 1 6.82 Shallow Pitting. 152 6448 0 0.03 8 2 6.78 1 I 153 6490 0 0.05 13 2 6.80 Shallow Pitting. 154 6533 O 0.06 15 2 6.80 Shallow Pitting. 155 6575 0 0.08 22 2 6.78 Isolated Pitting. 155.1 6616 0 0.06 16 3 6.83 Marker Pup Joint. Shallow Line of Pits. 155.2 6634 0 0.04 12 2 _ 6.83 Marker Pup Joint. Pup Shallow Line of Pits. I Penetration Body Metal Loss Body I I I I I I I I I I Page 4 1 1 I • • PDS Report Cross Sections ' Well: 1D -127 Survey Date: August 24, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 ' Country: USA No. of Fingers: 40 Tubing: 7.625 in. 29.7 ppf L -80 ABM -BTC Analyst: C. Waldrop 1 Cross Section for Joint 5 at depth 243.710 ft Tool speed = 49 ' Nominal ID = 6.875 Nominal OD = 7.625 I ' Remaining wall area = 94% Tool deviation = 1° / 1 1 1 1 1 Finger = 20 Penetration = 0.229 in. Apparent Wear 0.23 ins = 61% Wall penetration HIGH SIDE = UP 1 1 1 1 • • 1 PDS Report Cross Sections ' Well: 1D-127 Kuparuk (West Sak) Survey Date: August 24, 2011 Field: Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 ' Country: USA No. of Fingers: 40 Tubing: 7.625 in. 29.7 ppf L -80 ABM -BTC Analyst: C. Waldrop 1 1 Cross Section for Joint 155 at depth 6603.090 ft Tool speed = 40 ' Nominal ID = 6.875 Nominal OD = 7.625 Remaining wall area = 98% Tool deviation = 44° 1 1 1 1 Finger = 10 Penetration = 0.083 in. Isolated Pitting 0.08 ins = 22% Wall penetration HIGH SIDE = UP 1 1 1 1 ' KUP 1 - -127 ConOCOPhillips Og Attributes il TD Wellbore API/UWI Field Name Well Status Ind ( °) 186 (ftKB) Ad Btm (8146) lips 500292289000 WEST SAK PROD 65.64 5,056.89 7,4320 Lcnocoeha Comment H2S (ppm) Date Annotation End Date KB-Grd (It) Rig Release Date I Well con6a. -1x127 1/25n010 1.12 35 PM SSSV: NONE 2 8/2/2002 Last WO: 9/28/2008 47.50 7/8/1998 SMemtlic -Actual Annotation Depth (RKB) End Date Amota4on Last Mod ... End Date Last Tag: 6,483.0 4/15/2008 Rev Reason: ESP Assembly lmosbor 1/25/2010 Casing Strings Casing Description String 0... String ID ... Top (NCB) Set Depth (L.. Set Depth (1VD)... String Wt... String... String Top Thrd CONDUCTOR 16 15.062 42.0 1210 121.0 62.58 H WELDED i HANGER, 41 II Casing Description String 0... String ID ... Top (NCB) Sat Depth (f... Set Depth (ND) ... Sting Wt... String ... String Top Thrd SURFAC 7 5/8 6.750 412 7 ,415.9 4,014.2 29.70 L-80 ABM -BTC T u b in g Strings CONDUCTOR, Tithing Description Stung 0... String ID ... Top (NCB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd 42 - 121 TUBING 31/2 2.992 41.2 6,640.3 3,469.5 9.30 L EUEBrdAB - Mod HEAT TRACE, i 41 Completion Details Top Depth (ND) Top Ind Nonni... Top (NCB) OMB) ( °) Item Description Comment ID (In) 41.2 41.2 -1.51 HANGER ABB Vetco Gray Tubing Hanger w/ 3.5" L -80 EUE 8rd Mod. Pup Joint 2.950 6,570.5 3,424.5 50.59 GAUGE Guardian guage 3.500 1 , 6,612.0 3,451.0 48.88 INTAKE ITC Crossover coupling w/ perforated intake 2.992 6,616.6 3,454.0 48.84 ESP SEAL Tandem Seal Section GSB3DB 0.000 6,630.2 3,462.9 48.72 GEAR BOX GRU 525 9:1 0.000 6,631.5 3,463.7 48.71 MOTOR ESP Motor 57 hp KMH 1315V/26A 0.000 ESP 1 3 6,638.3 3,468.2 48.65 CENTRALIZER Motor Centralizer 4.500 i MANDREL, t 4 320 Tubing Description Sting 0... String ID ... Top (NCB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Mid B-Sand Straddle 41/2 3958 6,691.2 6,832.0 3,598.3 12.60 L-80 IBT Packer Completion Details Top Depth i (ND) Top InG Mont.. ESP Top (111(8) ( (°) Rem Description MrwDR 27 6,691.2 3,504.8 48.21 SLEEVE °HR" Liner Setting Sleeve 5.750 6,703.8 3,513.1 48.09 NIPPLE "RS' Pads off Seal Nipple Comment ID (In) 4.875 6,721.0 3,524.3 47.94 PACKER Baker Premier Production Packer 3.875 6,806.0 3,580.7 47.19 PACKER Baker Premier Production Packer 3.875 i GAUGE, 6,570 Gam* 6,830.7 3,597.4 46.97 WLEG Wirerne Guide (WLEG) 3.880 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) INTAKE. 6,612 Top Depth di (ND) Top Ind t Top 6849) MB) B) 1°l Description Comment Run Date ID (In) i 41 41.0 - 1.51 HEAT TRACE 2985' OF DUAL CHANNEL HEAT TRACE 9/29/2008 0.000 ESP SEAL, 6.617 Perforations 8. Slots GEAR BOX, Shot 6.630 Top (TVD) Btm (TVD) Dens i MOTOR, 6,6 ri p Top rytiCB) Btm (NB) (RKB) ( 3 ) zwne Date (5(6.. typ Comment R, I`-''I' 6,6 6,69,3 9/24/199 4. dee own 6,744 62 6,770 8 3348 ,539.4 .8 3,556.6 .3 WS WS B 10. -127 127 9/22/1998 8 4.0 0 IPERF IPERF 0 0 deg ph d CENTRALIZE 6,876 6,882 3,629.5 3,633.5 WS A3, 10-127 9/17/1998 4.0 IPERF O deg phased down 6 6,918 6,932 3,658.0 3,667.5 WS A3, 1D-127 9/17/1998 4.0 IPERF Odeg phase, down 6,962 7,002 3,688.2 3,716.0 WS A2, 1D -127 8/23/1998 4.0 IPERF 0 Deg phased, down i 6,662-6698 SLEEVE, 6,691 Notes: General & Safety End Date Annotation 10/5/2008 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE. 6,704 i lilt i PACKER. 6,721 PFRF 6 . 7 4 4 6 1 7 6 PACKER. 6.806 J i WLEG. 6,831 F IPERF. Mandrel Details I 6,876E,882 . Top Depth Top Pod ill (ND) Ind CO Valve Latch Size 1120 Run Stu Top (NCB) MB) Cl Make Model (in) Sery Type Type (I) IP Run Date Com... IPERF 1 4,320.4 2,401.9 65.50 Cameo KBMG 1 ESP DMY BK -5 0.000 0.0 9/27/2008 6,918 2 6,527.4 3,397.5 51.26 Camco KBMG 1 ESP SOV BK 0000 2,000.0 5/11/2009 1 IPERF. 6.982 -7,002 II i SURFACE. 41 - �* 01 TD. 7432 Brett Packer Page 17 of 26 8/18/2011 1 • • LA \ n , SEAN PARNELL, GOVERNOR L nA ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Wells Engineer ii a ConocoPhillips Alaska, Inc. fg P.O. Box 100360 r 1 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-127 Sundry Number: 311 -244 Dear Mr. Packer: . F +�. s,' ra 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, Daniel T. Seamount, Jr. Chair DATED this /O day of August, 2011. Encl. • • Conoco Phillips Alaska P.O. BOX 100360 t ,.,rs 4",. ; ,,. ANCHORAGE, ALASKA 99510 -0360 August 5, 2011 i t v +fi�i„ i Commissioner its'13P4418 State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover West Sak Well 1D -127 (PTD# 198 -109). Producing well 1D -127 was drilled and completed in November 1998. It was first brought online in December 1998 as a West Sak A/B/D frac- for - sand - control ESP producer. The ESP ran for 3.5 years with minimal problems until May 2002 when the well experienced a matrix bypass event (MBE) with injector 1D -128. The MBE resulted in a significant increase in water and sand production from 1D -127. The watercut went from 10% to 90% and the well struggled to stay online. After numerous pump changeouts, the ESP finally failed in February 2003 due to a downhole short. A workover was done in September 2008 to replace the ESP, cleanout the sand, and install an isolation straddle assembly across the B -sand where the suspected MBE occurred. The isolation straddle worked, as the watercut returned to <10 %. The well produced for 4 months until an ice plug formed in the IA gas recombination line, resulting in pressure building in the IA. While thawing out the line, the pressure in the IA quickly dropped resulting in a rapid drawdown on the formation causing an influx of sand. Many restart attempts were made, each time resulting in a significant amount of sand locking up the pump. Several CTU FCO's and pump changeouts were to no avail. Eventually, a sand bridge formed below the ESP and it appeared there was no formation inflow. The well was shut in May 2009 until a workover could be done. Due to the heavy sand production from this well, and the numerous pump failures, an ESP is no longer the desired artificial lift mechanism we want to pursue for this well. Current plans are to install a surface powered jet pump, similar to what has been done on four of our West Sak 1C single casing wells. This completion will allow CTD access for cleanouts and such. ConocoPhillips has initiated a new two- barrier policy from any energized fluid (i.e. reservoir fluids, power fluid, lift gas), consequently, in order to install a surface powered jet pump, this well requires another string of casing and a packer downhole to provide that 2 barrier. The proposed workover will pull the 3 ' /z" ESPCP completion. install an inner string of 5'G" casing and a selective Waddle. assembly across the D -sand, and complete the well with a 2'/8" jet- pump /gas -lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP is 1662 psi at the mid -perf depth of 3,600' TVD, which equates to an EMW of 8.9 ppg. Current SITP is 100 psi. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265 -6845. Sinc ly, Brett Packer Wells Engineer CPAI Drilling and Wells ‘ cO Au, I, ,, _ _ d., ,,, , , , i - 0.- 1 .,,, STATE OF ALASKA • • ALASK41,_ AND GAS CONSERVATION COMMISSIO ( 0 - I I ;'1 4) :t ; !f •' APPLICATION FOR SUNDRY APPROVALS' n . 20 AAC 25.280 r s . l z .D P ,. ; , #r4P a'. *,,ttitiltcI 1. Type of Request: Abandon f Rug for Redrill r Perforate New Pool r Repair well r Change Approut4d PTiram r" Suspend r Ftug Perforations r Ft'rforate r Pull Tubing P' Time Extension r Operational Shutdow n r® Re -enter Susp. Well r Stimulate r Alter casing 'Other: E 3 P — 33.- P; r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory j'"' 198 -109 ' 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22890 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 1D -127 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25650 • Kuparuk River Field / West Sak 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): 7432 4 4026 • 7286' 3919' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 7375 7.625 7416' 4014' Perforation Depth MD (6662' - 6698', Perforation Depth TVD (ft): 3484'- 3509', Tubing Size: Tubing Grade: Tubing MD (ft): 6744'- 6770', 6876- 6882', 6918'- 6932', 6962' -7002' 3539'- 3557', 3630'- 3634', 3658'- 3668', 3688' -3716' 3.5 L - 80 6640 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PRODUCTION PACKER MD= 6721 TVD= 3523 PACKER - BAKER PREMIER PRODUCTION PACKER MD= 6806 TVD= 3581 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: • Detailed Operations Program r BOP Sketch Exploratory Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/19/2011 Oil I✓ - Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR f SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name Brett Packer Title: Wells Engineer Signature /� / Phone: 265 6845 Date / I Commission Use Only j Sundry Number:3k k • a `�+ (' if Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r 1 3500 Ps ear P i +- Other: £' ' k Z,S� Psi A�., �,. lam- 77;4 Subsequent Form Required: /6 •_ ybt j ' APPROVED BY Approved by: � COMMISSIONER THE COMMISSION Date: 3 /76 / 1 Er Form 10 -403 ReviAS[ AUG 11 201 R IGINAL ,A t ?• Subm' ' uplicate d yl , • • • 1D -127 Rig Workover Install 5 casing, D -sand Selective Straddle 2'/8" Gas Lift/Jet Pump Completion (PTD #: 198 -109) Current Status: West Sak ESP producer was SI May 2009. The ESP cannot be re- started due to a sand bridge below the ESP. Scope of Work: Pull the 3 '/2" ESP completion, cleanout to PBTD, pressure test the casing, run a suite of diagnostic e -line logs in the 7 %" casing, install a 5 ' /2" inner casing string with a D -sand selective straddle assembly, install a 2'/s" Gas Lift/Jet Pump completion. General Well info: Well Type: Producer MPSP: 1,302 psi Reservoir pressure/TVD: 1,662 psi / 3600' TVD (8.9 ppg) Wellhead type /pressure rating: Vetco Gray Horizontal, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA /OA not possible due to single casing packerless ESP completion. Earliest Estimated Start Date: August 19, 2011 Production Engineer: Jenn Gauer Workover Engineer: Brett Packer (265 -6845 / j.brett.packer @conocophillips.com) Pre -Rig Work: 1. RU Slickline: a. Swap out SOV for DV in GLM #2 at 6,527' RKB. b. Obtain SBHP. 2. Pump into tubing to verify communication to the IA and reservoir. V 3. Set BPV. Proposed Procedure: 1. MIRU Nordic 3. Pull BPV. Reverse circulate hot filtered 9.0 ppg brine w/ 3% KCL to clean the ESP & tubing. Conduct a flow check to verify well is dead. If not, obtain SITP & SICP, verify needed KWF, weight up as necessary and repeat circulation using filtered KWF. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE & test. 35) ps. 3. Pull blanking plug & BPV, install side isolation sleeve in hanger, screw in landing joint, BOLDS's and pull to the floor. 4. POOH w/ ESP completion, laying down tbg, spooling up ESP cable & heat trace. Lay down ESP equipment. 5. RIH w/ 3 '/8" milling BHA, 750' of 2 '/8" drillpipe, 7 %" scraper, and 3 'h" drillpipe, cleanout to PBTD. POOH standing back drillpipe, lay down 2' /8" drillpipe. 6. MU 7 5 /8" RBP and test packer, RIH on 3 ' /2" drillpipe to 6,650' MD. Set RBP and release from RBP. Pull up one joint and set the test packer. PT the RBP to 1500 psi. PT back side to 1500 psi. a. If pressure tests OK: Release test packer & RBP, POOH laying standing back drillpipe, and proceed/ with running E -line logs • 7. RU E -line: RIH w/ Microvertilog, 40 -Arm Caliper, and Gyro; log from 6,650' back to surface. 8. Unload old tubing and rack & tally new casing and tubing in pipe shed. 9. PU & RIH w/ D -sand selective straddle assembly on 3 'h" drillpipe down to the "HR" liner setting sleeve of the existing B -sand straddle assy. Load the IA w/ corrosion inhibited fluid. Sting into the liner setting sleeve, set the Premier packer. PT annulus to verify packer is set. Release from straddle assy. and POOH standing back drillpipe, lay down packer setting tools. 10. PU and RIH w/ 5 ' /z ", 15.5 #, L -80 BTCM -SCC casing, SBE, and Seal Assy 11. On TIH, install a storm packer at —100' MD w/ casing hanging below. NDBOP. 12. Remove old wellhead and install new wellhead to accommodate the 5 '/z" casing. 13. NUBOP & test. • 14. Release storm packer and POOH laying down storm packer. • 15. Continue RIH w/ 5 'h" casing down to SBE above the Premier packer. Sting into SBE until fully located, PT annulus to verify seals are engaged. 16. Space out w/ pups —7' off bottom, make up casing hanger, reverse circulate corrosion inhibited KWF in the 51/2" x 7%" annulus, land the 5 '/z" casing hanger, RILDS. Pressure test 5 'h" x 7 %" annulus to 1500 psi. ' 17. PU and RIH w/ 2 ' /2" gas lift/jet pump completion w/ CMU sliding sleeve (and RHC plug installed), - downhole gauge, and seal assy. 18. Sting seals into SBE, mark pipe, pull seals from SBE, circulate well full of CI brine, space out 7' off bottom, make up hanger and splice TEC wire to penetrator, land the hanger. RILDS. 19. Drop a ball & rod to seat in the RHC plug of the CMU. PT tbg to 3000 psi, monitor annulus, bleed tbg to 2750 psi. PT IA to 3500 psi for 30 min. Record casing test on chart recorder. Bleed IA to zero, bleed tbg to zero. Ramp up IA pressure to shear SOV. 20. Pull landing joint, drain stack, remove side -port isolation sleeve, set two -way check, NDBOP. 21. NU and test tree. Pull two -way check, freeze protect through the SOV, set BPV. 22. RDMO Nordic 3. Post - Rig Work: 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Replace SOV w/ DV. b. Pull DV from circulation mandrel. RU LRS, reverse circulate gelled diesel to fill the 5 'h" x 7 %" annulus. Replace DV. c. Open the upper CMU. d. Install Jet Pump. 4. Make necessary S -riser mods. 5. Re -attach flowline. Connect new Guardian gauge. 6. Turn well over to production. • C C e illi s West Sak Well: 1D-127 2011 RWO PROPOSED COMPLETION API: 500292289000 Conductor: PTD: 198 -109 16 ", 62.58#, H -40 to 121' DS Wellhead: Gray Horiz X -mas Tree: 4-1/16", 5K psi ] Surface Casing: Lift Threads: 4.909" MCA / 7.625 ", 29.7 #, L -80 to 7416' BPV: 3" 'H' Proposed 2W' Completion New Inner Casing: • Tubing = 2 % ", 6.5 #, L -80, 8rd EUE. 5.5 ", 15.5 #, L -80 BTCM -SCC • 2.313" DS- nipple at 500' • 2 %" CMU Sliding Sleeve w/ 2.25" D profile. New Tubing: . 2.875 ", 6.5#, L -80, 8rd EUE -Mod • Guardian Pressure Gauge. •XO from 2 % " EUE to TA" EUE. J cm. 1 2.25" CMU Sliding Sleeve at -6270' RKB • 80 -40 GBH -22 LTSA Seal Assy, for 20' SBE. Proposed 5W' Cm String & Straddle • Guardian Sidemount Gauge Carrier • Casing = 5Yz',15.5 #, L -80, BTCM -SCC. • XO to 5 -1/2" BTCM -SCC Casing • XO from 5'/z' BTCM -SCC to 5" BTCM. F— 5" SBE (20' long) • 20' SBE, 5" BTCM. • XO from 5" BTCM to 2 %" EUE. J ♦— 2 -7/8" EUE Tbg w/ 2 -7/8" Circ. Mandrel • 2 %" EUE Tubing w/ Circ. Mandrel. I 1 • "HR" Liner Setting Sleeve @ 6691' RKB • XO from 2 %" EUE to 3'W EUE. ''—'_ • 5" SBE (20' long) 1■ 4.5" x 7.625" Premier Pkr to be set @ 6550' RKB • 80 -40 GBH -22 LTSA Seal Assy. for 20' SBE. Proposed D -Sand Selective Straddle Assv. = 0.. = 2 -7/8" EUE D -Sand Selective Straddle w/ 2.25" CMU Sliding Sleeve • "HR" Liner Setting Sleeve, 5' %" Hydril 521 = _ • RS Nipple, 5%" Hydril 521 x 5 %" BTCM • XO from 5/" BTCM to 5" BTC I� I • "HR" Liner Setting Sleeve @ 6691' RKB •'20' SBE, 5" BTCM. l4 OM 4.5" x 7.625" Premier Pkr @ 6721' RKB • XO from 5" BTCM to 4' /z' IBTM _ = Existing B -Sand Isolation Straddle Assy. • Baker 4%" x 7%" Premier Packer �� • 4.5" x 7.625" Premier Pkr 6806' RKB • XO from 4' %"IBTM to 2%" EUE. @ • 2%" CMU Sliding Sleeve w/ 2.25" D profile. = f WLEG • XO from 2'/a' EUE to 5 %" BTCM. — _ • 5.75" OD locator seal assy. — _ Last Updated: 4 -Aug -11 A h Updated by: JBP , ; rgtig M1 KU P • 1 D -127 Iv - illips ' - y elI.A trs44 ; Max Angle & MD TD Alaska. (r1C ; r': Wellbore API/UWI Field Name W ll Status (ft Inc( () MD KB) Act Btm (ftKB) L'1' _ 500292289000 J WEST SAK PROD 6564 1 5,056.89 7,432.0 Cam B rit w H2S (ppm) Date Annotation - End Data KB (69 Rig Release Date SSSV: NONE 2 8/2/2002 L ast WO: �- 9/28/2008 47.50 7/8/1998 �- f- _ -' - -- _ .__ SdTemadc ArN D - rvt , : � Annotation I epth (ftKB) End Dale Annotation Last Mod .. End Date Last Tag- 1 _ 6,483.0 4/15/2008 Rev Reason: ESP Assembly Imosbor 1/25/2010 [Casing Strings 2 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String String Top Thrd CONDUCTOR 16 15.062 420 1210 121.0 62.58 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER, 41 SURFACE 75/8 6.750 41.2 7,4159 4,014.2 29.70 L -80 ABM -BTC - --M-- Tubing Strings CONDUCTOR, Tubing Description String 0 String ID ... Top (1168) Set Depth (f Set Depth (TVD) . String Wt... String .. String Top Thrd s2 - 121 �. f UBING i 3 1/2 2 992 I 41.2 6,640 3 3A69.5 l 9 30 I L I EUE8rdAB - Mod HEAT TRACE,_ 41 r Completion Details Top Depth (TVD) Top Inc! Nomi... Met KB) (KB) (°) Item Description Comment 10 (in) 41.2 41.2 -1.51 HANGER ABB Vetco Gray Tubing Hanger w/ 3.5" L -80 EUE 8rd Mod. Pup Joint 2.950 6,570.5 3,424.5 50.59 GAUGE Guardian gunge 3.500 6,612.0 3,451.0 48.88 INTAKE TTC Crossover coupling w/ perforated Intake 2.992 6,616.6 3,454.0 48.84 ESP SEAL Tandem Seal Section GSB3DB 0.000 6,630.2 3,462.9 48.72 GEAR BOX GRU 5259:1 0.000 6,631.5 3,463.7 48.71 MOTOR ESP Motor 57 hp KMH 1315V/26A 0 - 000 ESP h :: 6,638.3 3,468.2 48.65 CENTRALIZER Motor Centralizer 4.500 MANDREL, - - -_- ' -- 4,320 -- Tubing Description (String 0... String ID ... Top (ftKB) Set Depth (f... Set Dep (N D) ... String Wt... String ... String Top Thrd I I 13-Sand Straddle 41/2 3 -958 6,691. 6,832.0 3,598.3 12.60 L -80 IBT ,Packer completion Details Ili Top Depth 6,6 188) X4 8 Top Inc[ Nom). ESP Top NKB) [ftKB) ( °) Item Description Comment ID (in) MANDREL, " 4 SLEEVE "HR" Liner Setting Sleeve 5.750 6,703.8 3,513.1 48.09 NIPPLE "RS" Pack off Seal Nipple 4.875 6,721.0 3,524.3 47.94 PACKER Baker Premier Production Packer 3.875 6,806.0 3,580.7 47.19 PACKER Baker Premier Production Packer 3.875 GAUGE, 6s70 - -- - "'I" - ' "' 6,830/ 3,597.4 46.97 WLEG Wireline Guide (WLEG) 3.880 Other In Hol lWireline retrievable plugs, valves, pumps, fish, etc.) Top Depth INTAKE, 6,612 (TVD) Top Inc! Top (ftKB) (ftKB) (°) Description Comment Run Date ID(in) 41 41.0 - 1.51 HEAT TRACE 2985' OF DUAL CHANNEL HEAT TRACE 9 /29,'2008 0.000 + ) N , - __.. 1 . ESP SEAL. _._ I ,,. 6,617 Perforations & Slots 06.68 805, ,,,,. Shot 6,630 Top (TVD) EMI (TVO) Dens 14 To�(flK61 Blni (ftKB) ( B) (NCB) Zone Date (h Type Comment MOTOR,6,632 - - - ' 6,662 6,698 3,483.8 3,509.3 WS D, 1D-127 9/24/1998 4.0 IPERF 0 de,g -phase down 1 6,744 6,770 3,539.4 3,556.6 WS 8, 1D- 127 9/22/1998 4.0 IPERF 0 deg phase, down CENTRALIZER, 6,876 6,882 3,629.5 3,633.5 WS A3, 10- 127 9/17/1998 4.0 IPERF 0 deg phased down 6,638 6,918 6,932 3,658.0 3,667.5 WS A3, 10-127 9/17/1998 4.0 IPERF 0 deg phase, down 6,962 7,002 3,688 2 3,716.0 WS A2, 11J-127 8/23/1998 4 0 WPERE 10 Deg phased, down IPERF, ' 8,662 -6,698 , """" N 0 110 General 8r Safety E d D ate A nnotation SLEEVE, 6,691 _" 10/5/2008 NOTE VIEW SCHEMATIC w /Alaska Schemat c9 0 NIPPLE, 6,704 111 PACKER, 6,721 IPERE, 6,744 -6,770 PACKER, 6,806 -- WLEG, 6,83'1- rs = IPERF, = - - -- Mandrel Details - 6,676 -6,882 ' Top Depth Top I Port A MAO Inc! OD Valve ■ Latch TRO Run Stn To8 (N(B) (") Make Model (in) Sery Type TB (in) (Psi) Run Date Com... I.� ....e■ 1 4,320.4 2,401.9 6S. 50 Camco KBMG 1 ESP DMY BK - 5 0.000 0.0 9/27/2008 IPERF, - ?W. s. 1 6,918 -6,932 WRNS 541.X. 2 6,527.4 3,397.5 51.26 Camco KBMG 1 ESP SOV BK 0.000 2,000.0 5/11/2009 Z4 PERF, iP++ 0,902.7,002 , - SURFACE, 41- 7,416 • ` TD, 7,432 i wF,~L c,o~ r~An~snl~Irr~a~ Ian PROACTIVE DIAGNOSTIC SERVICES, INC. C~ To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Magnetic Thickness Tool 15-Apr-10 10127 1 Report 50-029-22890-00 2) ~~~` t ~,~~~ i~~ ~~ ~~ °~ 1~~-?v~ ~ a~- ~: z MAY1iZ010 Signed : Date Print Name: ®~ - PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245$951 FAX: (907)245-88952 E-MAIL : pdsanchoraaeCa@memorvloa.com WEBSITE : www.memoryloa.com C:\DocumenCs and Settings\Diane Willisms\Desktop\Tcatismit_Conoco.docx • • Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. We11: 1 D-127 Log Date: April 15, 2010 Field: West Sac Log No.: 10622 State: Alaska Run No.: 2 API No.: 50-029-22890-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 214 Ft. (MD) Pipet Desc.: 7.625" 29.7 Ib L-80 ABM-BCT Top Log Intvl.: Surface Pipet Use: Production Casing Bot. Log Intvl.: 214 Ft. (MD) Pipe3 Desc.: 16" 62.58 Ib. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the second time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total metal thickness of the 3.5" tubing, 7.625" production casing, and 16" conductor pipe. Passes at SHz, 8Hz and 10Hz were made at 20 fpm. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison of the current 8Hz pass to the previous 8Hz pass indicates a change in tubing between the current and previous Togs since last MTT was run in this well on June 14, 2006. There appears to be no indications of metal volume loss during the time between logs. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous 8Hz passes is included in this report. The current MTT log actually indicates a fairly consistent (--7%) increase in metal volume over the interval 0' - 44'. The small interval of 7% metal loss indicated between 2' and 4' in the previous log appears to have been an inverted response to a pup joint collar that has been removed during the time between logs. INTERPRETATION OF MTT LOG RESULTS The MTT log results indicate no significant areas of metal loss throughout the interval logged. Changes in metal volume are relative to the calibration points at 57' and 150', where the readings are assumed to represent undamaged pipe. Alt other readings are relative to these reference points, which include influences from the 3.5" tubing, 7.625" casing and 16" conductor pipe. Of the three frequency passes made, the 8Hz pass appears to show the best representation of the well bore condition, having the least noise and data spikes of all of the passes. A log plot of the entire 5Hz pass is also included in this report as a reference. A log plot overlay of the filtered Delta Metal Thickness curves from all three passes is included in this report as well. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or (888} 565-9085 Fax: (281) 565-1369 E-mail: PDS@memoryiog.com Prudhoe Bay Field Office Phone: (907} 659-2307 Fax: (907} 659-2314 l9 ~S-/Cdy OtgM net(SA~c Q,. ,~ ~ Comparison to Previous M~Log Overlay 1 D-127 Pf1O/~CTIVE DIAQNOSTIC SERVICES April 15, 2010 and June 14, 2006 Database File: d:lwarriorldatal1d-127~comparison.db Dataset Pathname: comparison Presentation Format: comps Dataset Creation: Fri Apr 16 10:26:24 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2(110 (8Hz) (%) 50 -50 Delta Metal Thickness 2006 (8Hz) (%) 5D 0 20 40 7 518" Casing (Inverted Delta Metal Thickness 2006 Jt. Trace 60 ' ' ' ' ' ' Delta Metal Thickness 2010 Bottom of the 16" 80 i--,-~t--r--~ 518" Casing Col Quo Fny R~orded Magnetic Thickness ~ Data - SHz Pass 1 D-127 April 15, 2010 PIIOACTIVF DIAyNOSTIC SERVICES Database File: d:\warriortdatalld-127~Shzpass.db Dataset Pathname: 8HzPass Presentation Format : 2.8 scale Dataset Creation: Thu Apr 29 14:56:06 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness {%) 50 ~ 2.8 0 Line Speed (ft/min) 200 -5.6 Tree ~' I--r Line Sp ee ~ i ~ ~ ~ ~Hanger~ ~ ~ ~ ! - P ~ -__ }-} up _.. 3.5" Co llar ~ - -- Delta Metal Thickness 20 Tubing Jt. 1 t, ' 3 5" Co llar . 40 ' 7.62 5" C olla r {In verted Respo nse } ' bi Jt 2 T u ng . 60 3.5" Co llar ~ I ' Bottom o f 16" Conductor vv Tubing Jt. 3 7.625" Co llar MTTP01 (rad) MTTP12 (rad} 12.8 4 5" Collar 100 Tubing Jt. 4 120 3.5" Collar ' 7.625" Collar 140 Tubing Jt. 5 5" Colla Tubing Jt. 6 180 5" 200 Tubing Jt. 7 Delta Metal Thickness Line Spee Delta Metal Thickness (%) 50 2.8 MTTP01 (rad) 12.8 Line Speed (ft/min} 200 -5.6 MTTP12 (rad) 4 o`~~wE"~A~ R~Orded Magnetic Thickness ~ Data - 5Hz Pass ~ n~G a ~ '" 1 D-127 April 15, 2010 PII°I~CTIVE DIAGNOSTIC SERVICES Database File: d:lwarriorldata\1d-12715hzpass.db Dataset Pathname: 5HzPass Presentation Format: mtt_50 Dataset Creation: Thu Apr 29 14:04:00 2010 Charted by: Depth in Feet scaled 1:150 ' -50 Delta Metal Thickness (°lo) 50 1 0 Line Speed (ft/min) -200 -45.2 Tree Line Sp eed Ha~~ - -- Pup ' 3.5" Co llar ~ Delta Metal T hickness _ Tubing Jt. 1 ' 20 ~ '~, ~ 3.5" Co llar ~ 40 7.625" Collar (Inverted Respons e} ' Tubing Jt. 2 ' 60 _ 3 5" -- C -- - . o llar Bott om of 1 6" Conductor ' 80 Tubing Jt. 3 ' 7. 625" Co llar MTTP01 (rad) MTTP12 (rad) 51 4.8 +--=~-;---i 5° .625" Colla 5" 625" 5" Collar. Metal Line 100 Tubing Jt. 4 120 140 Tubing Jt. 5 Tubing Jt. 6 180 200 ing Jt. 7 -50 Delta Metal Thickness (%) 50 1 MTTP01 (rad) 51 0 Line Speed (ft/min) y -200 -45.2 MTTP12 (rad) 4.8 Quo Agcy `~M~E"s SHz, ~z and 10Hz Passes Delta I Thickness Overlay N (Filtered) PIIpACT1VE DlnyNpSTIC SEpYICES 1 D-127 April 15, 2010 Database File: d:lwarriorldatal1d-1271overlay.db Dataset Pathname: comparison Presentation Format: comps Dataset Creation: Fri Apr 16 10:26:24 2010 Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness 2010 (5Hz) (%) 50 -50 Delta Metal Thickness 2010 (8Hz) (%) 50 -50 Delta Metal Thickness 2010 (1 OHz) (%) 50 0 Thickness 2010 20 40 Metal Thickness 2010 Delta Metal Thickness 2010 60 Bottom of 16" 80 I I a I ConacoPhillips Alaska, Inc. ~KRU 1 D-127 1 D-127 API: 500292289000 Well T e: PROD An le TS: de NBING SSSV Type: NONE Orig 7/8/1998 Angle @ TD: 43 deg @ 7432 (o-ss~a, OD:3 500 Com letion: . , iD:z.9sz) Annular Fluid: 3% KCI /8.7 Last W70: 11/24/1998 Rev Reason: Waivered Well cas Litt - - , a „ Reference L Ref Lo Date: Last U date: 2/27/2004 MandrelNalve ~ Last Ta : 2220 TD: 7432 ftK6 ~ (6523-6524 - ~ ~ Last Ta Date: 3/7/1999 Max Hole An le: 66 de 5057 , ~RODUCTION -, - Caslrl Shin -ALL (o-74~s, r Descri lion Size To Bottom ND Wt Grade Thread oD:7.sz5, wt:2s 7o) - CONDUCTOR 16.000 0 121 121 62.58 8-40 WELDED . PRODUCTION 7.625 0 7416 4014 29.70 L-80 ABM-BTC Tubin Strin -TUBING Size To Bottom ND Wt Grade Thread 3.500 0 6614 3453 9.30 L-80 EUE GAUGE Perforations Summar (6567-6568, InterV81 ND Zone Status Ft SPF Date T e Comment oD:a.SOO) 6662 - 6698 3484 - 3508 WS D 36 4 9/24/1998 IPERF 0 de, .hase down PACKOFF 6744 - 6770 3539 - 3557 WS B 26 4 9/22/1998 IPERF 0 de hase down (6570.6579, 6876 - 6882 3629 - 3633 WS A3 6 4 9/17/1998 IPERF 0 de hased down OD:3.500) 6918 - 6932 3658 - 3668 WS A3 14 4 9/17/1998 IPERF 0 de hase, down 6962 - 7002 3688 - 3716 WS A2 40 4 8/23/1998 IPERF 0 D hased, down Gas Lift Me ndrels Nelves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv PUMP Mfr Run Cmnt (6579-6616, OD:2 313) 1 6523 3395 CAMCO KBMM CAMCO OV 1.0 BK 0.188 0 2!2612003 . Other lu s ui .etc. -JEWELRY De th ND T Descri tion ID 6567 3422 GAUGE BAKER SENTRY GAUGE -PUMP INTAKE 3.500 6570 3424 PACKOFF 1.620 6579 3430 PUMP Centrilift Retrievable Pump 180ML2000 KUDU w/packoff & slipstop, set 0.000 4/25/2002 6611 3451 NIP SLOTTED NIPPLE 2.992 6614 3453 XO 2.992 6616 3454 SEAL Tandem seal GSB3 DB IL H6PFS 0.000 '~ , - - 6629 3462 GEAR Gear reduction unit 9:1 525 series 0.000 '~ 6631 3464 MOTOR 57 HP 1315!26 KMH 0.000 NAP General Notes (6611-6616, OD:3.500) Date Note xo 1/30/ 200 WANERED WELL: IA x OA COMMUNICATION ' (6614-6675, OD:3.500) SEAL (6616-6629, OD:5.130) GEAR (6629-6631, OD:5.250) - MOTOR (6631-6638, OD:5.620) Pert (6662-6698) Pert (67446770) Pert (6876-6882) Pert (6918.6932) Pert (6962-7002) Casin OR Tubin OR Driiiin Detail welt: 1 D-127 31/Z°' SP Tubin Gam etion oats: ai27taoas /~,~,~,,~,,,ry~.f WI lVWff ~f~~~ Rig: Nordic 3 naeo, u+a Depth Jttrcanner ;:ur:`•.yZ nt `S:e<':#Y:;y. 1lJ;. `:tiot`i:%,s 4--~ ~~ti~~, ~ Ja~M :Gi2: i;Yr,'~'~.'->:j~~, }' ~ '~~~ Weli Equi~mentDescript3on and Comments Page 1 To of Strin or Ta of Flan e lsng~ {S~r~'~',"5:',,'N~.~-~''?;~~k f~r~y,`::.;y,` ~'~:4 ' Tops .,v.j S;: ,J••-'O s~.zrs::;'{.+`2`)Y ;":~% .. '~~~~~~"~~ "~% Parker 245 ORKB 41.15 ABB Ve#co Gra Tobin Ha er w/ 3.5" L-80 EUE 8rd Mod. Pu Joint 5.62 `~-4a Jts 41 to 72 a2 Jts 3 1!2" 9.3# L-$0 EUE 8rd AB Mod. Tubin w/ heat trace 2985.29 46.77 Jts 27 #0 40 14 Jts 31 /2" 9.3# L$0 EUE 8rd AB Mod. Tubi 1282.21 3032.06 3 1!2" 9.3# L-$0 EUE 8rd AB Mod. Tubi Pu Joint 6.09 4314.27 3.5" x 1" Camca KBMG w/ Dumm , BK-5 Latch 7.05 s 3 1!2" 9.3# L-$0 EUE 8rd AB Mod. Tobin Pu Joint s.io 4327.41 Jts 3 l0 26 24 Jts 3112" 9.3# L-80 EUE 8rd AB Mod. Tubin 2187.77 4333.51 3 1/2" 9.3# L-80 EUE 8rd AB Mod. Tubin Pu Joint 6.10 ~' 3,5" x 1" Camco KBMG wl Dumm BK-5 Latch 7.05 '"~_' 3112" 9.3# L-80 EUE 8rd AB Mod. Tubin Pu Joint 6.07 6534.43 Jts 1 to 2 2 Jts 31/2" 9.3# L-84 EUE 8rd AB Mod. Tubin -Guardian Goa e 6 586' 61.33 3 1/2" 9.3# L-80 EUE 8rd AB Mod. Tubin Pu Joint 10.16 6601.83 TTC Crossover cau ii w! erfarated intake 4.65 Tandem Seai Section GSB3D6 13.58 GRU 525 9:1 1 •~ ESP Motor 57 h KMH 1315V/26A s•80 Motor Centralizer 2.00 8840.32 6640.32 6640.32 6840.32 ssao.3a ssao.32 6640.32 6640.32 6640.32 6640.32 fi640.32 6640.32 8640.32 6640.32 8640.32 8640.32 8640.32 Remarks' Clamps used: Up Wt 90 K 64 - S•mgie channel X cplg, 84 -Dual Xcp),q, 487 - 5' l7uat Channel, 5 - 4' Dual Ghannei, 20 - S5 t3ands and Dn Wf 50K 1 End shoe on heat (race. Block VVt 35 K --- -_ Supervisors: a~ a a y ca er i (- • Caslin OR Tubin OR DrilFin Detail wen. 1D-127 WestSak B-sand Straddle .Packer ass Date: 9/27/2008 L W l 4W"I gI~~PS ~ Rig: Wardic Rig 3 A a i~urinc. Depth .ItNumber .toffs Weli Equipment Description and Comments Page 1 Length Tops ss<:: `:.'~:. ::.`i'~: :F' 4:J: . .. ,. :<:~.. . Ai~+ 'ice: ..:&~~:~ "' % ~, «~~f>„=~~~.r.~ _ ..~ye:.. i':f `: •tx~:.~..~;,y' To of Strin or To of Flan a ~t`y -- :'2 `~ ",:Yat'i~2" 6s~. :.iSk)r...k,,. • :Sfi'._ F.y~n ~:>2.:^~c,'r- ,-.. . ~: '..- 6697.15 "HR" Liner Settin Sleeve 12.68 8891.15 "RS". Pack aff Seal Ni le 2.54 6703.83 CraSS Over SUb 1.08 8708.37 Liner Pu Join# 3.80 6707.46 CfOSS Over u Joint 9.77 6711.26 Baker Premier Production Packer 7.33 6721.03 Cross over Joint 9.30 6726.36 Jts 1 to 2 2 Jts 41/2 12.6# L_80 IBTM R2, SC 4.920" C I Tubin 58.52 6737.66 Cross aver Joint 9.78 6756.18 Baker Premier Production Packer 7.01 68os.96 Cross over Joint 17.72 6812.97 ~/L 9.39 6830.68 6$32.00 6832.00 6832.00 6832.00 6832.00 6832.00 8832.00 6832.00 - 6832.00 6832.00 6832.00 8832.00 6832.00 6832.00 8832.00 6832.00 6832.00 6832.00 6832.00 6832.00 6832.00 683200 Remarks: Carder of Element on i'acker#1 ~ 6,810' and Packer#2 ~ 6,725' Up Wt 100 K WestSak ~B" sand perfs are from 8,744' to 8,770' Dn Wk fi2K Block Wt 35 K ~ Supetvfsors: Kai StarckeRandy tk~lcafe, • ConocoPhillips ~as~ P.o. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 10, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • id JAN ~ 3 2C~~~ ~iasiea Qii ~ Gas ~~ar~s, ~amrnissinr~ ~nciiara~a ~„ Enclosed please find the 10-404 Report of Sundry Operations :for ConocoPhillips Alaska, Inc. well 1D-127 (PTD 198-109 Sundry 306-210). The proactive surface casing excavation and inspection has been postponed. Anew 10-403 Sundry Approval application will be submitted if the work is rescheduled. Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, Love and ConocoPhillips Well Integrity Projects Supervisor Enclosures ~ ~E~EIVED STATE OF ALASKA bJ~(i) ~ 3 Z~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI0~1'~~j ~;i ~ has Cons. Commission ce approv 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ~~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^~ Exploratory ^ 198-109 / 3. Address: Stratigrephic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22890-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 112' ' 1 D-127 ' 8. Property Designation: 10. Field/Pool(s): ADL 25620, i4LK 468 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7432' feet true vertical 4026' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' PRODUCTION 7304' 7-5/8" 7416' 4014' Perforation depth: Measured depth: 6662-98', 6744-70', 6876-82', 6918-32', 6962-7002' true vertical depth: 3484-3508, 3539-3557, 3629-3633, 3658-3668, 3688-3716' Tubing (size, grade, and measured depth) 3-1 /2" , L-80, 6640 MD. Packers &SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: NA Intervals treated (measured) NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation NA Subsequent to operation NA 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ ~ Service ^ Daily Report of Well Operations _X -work canceled 16. Well Status after proposed work: Oil^Q Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. F~cempt: 306-210 Contact Loveland/Klein Printed Name MJ Loveland .Title Well Integrity Supervisor Signature Phone Date ~ JC-~ ~q~ ~ 4 ?ors ~ ~-,3.oy Form 10-40 Revised 04/2004 ~~`~ Submit OrigirtY~=~~ 1 D-127 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/10/2009 Surface casing inspection postponed until further notice. This 10-404 is to close 10-403 306- 210Work not completed. • STATE OF ALASKA ~ ~ "``'"^ =r ~ ._ _ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI~~,~ ~: ~.; , 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimu~ .- Other ~' '' ^ { Alter Casing ^ Pull Tubing ^~ Perforate New Pool ^ Waiver ^ Time Exter1sibm -^ . Change Approved Program ^ Operat. Shutdown^ Perforate ^ {~ ~l F .7jy~~ Re-enter Susp~ird~Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^~ Exploratory ^ 198-109 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22890-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 70' 1 D-127 ' 8. Property Designation: 10. Field/Pool(s): , ~ ADL 25650 Kuparuk River Field / We§t Sak OT'P~a wr 11. Present Well Condition Summary: ~.. "'4 Total Depth measured 7432' feet ~i~ ~ c~ ~/~_,, `' true vertical 4026' ~ feet Plugs (measured) '~; i Effective Depth measured 7286' feet ;, Junk (measured) - ;, -v true vertical 3919' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 7375' 7-5/8" 7416' 4014' Perforation depth: Measured depth: 6662'-6698', 6744'-6770', 6876'-6882', 6918'-6932', 696" ~~ '~~~ ~~~ ~ ~ ~U~ U true vertical depth: 3484'-3509', 3539'-3557', 3630'-3634', 3658'-3668', 3688'-3716' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6640' MD. Packers &SSSV (type & measured depth) Straddle pkr, 2 Baker production pkrs @ 6721', 6806' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia, if C.O. Exempt: none contact Brett Packer @ 265-6845 ~ i~ Printed Name Brett Packer Title Wells Group Engineer ~~ ... .~-, Signature ~"? ~' ~' °'"L Phone: 265-6845 Date f ~' ~ ~ ~ Pre d b h r n Allsu -Drake 263-4612 r ~~, /o.ZZ.v~S - ~ : <d, - Form 10-404 Revised 04/2006 j '~~~ ~ ~- E~ u ~ Z~~bmit Or' inal,Qnly . r~ Cor~o~oP'hilips Time Log & Summary ~~„~~~ ~~~ ~e~o~,~g Report Well Name: 1 D-127 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 9/22/2008 10:30:00 AM Rig Release: 9/30/2008 5:00:00 AM ', Time Logs Date From To Dur S. Depth E Depth Phase Code 5ubcode T Comment 9/22/2008 _ _ 24 hrSummarv Moved from 1J to 1 D pad sans mats until Y south of D. Matted 1 D bypass to Spine Road. Loaded 11" BOP stack in cellar, spotted rig over well 1 D-127, RU hardline and kill tank, loaded pits with kill wt fluid, killed well, started loadin 3 1/2" DP. 04:00 10:30 6.50 MIRU MOVE MOB P Moved rig from 1J to 1D pad sans mats to Y south of D pad. Matted 1 D b ass road to S ine Road. 10:30 11:30 1.00 MIRU MOVE RURD P Accept Nordic Rig 3 @ 1030 hrs on 1 D. PU 11" BOP into cellar on 1 D ad. 11:30 13:30 2.00 MIRU MOVE RURD P Move over well. Spot & level rig. Berm cellar and RU hardline 13:30 14:30 1.00 COMPZ WELCTL OTHR P Pull BPV with lubricator. Tbg gauge showed 700 si. 14:30 16:00 1.50 COMPZ RPCOM RURD P Change out ESP spool, RU circulatin lines and test to 3000 PSI 16:00 22:00 6.00 COMPZ WELCTL KLWL P Load pits w/ KWF. Unable to load pits earlier due to welding repairs, load decompletion equipment, rack and tally 3 1/2" DP while waiting on sodium bromide dry product, KWF was loaded into pits which contained approx 20 bbls fresh water and cut KW back to 10.4ppg, mix dry product an increase fluid weight to 10.5 22:00 00:00 2.00 COMPZ WELCTL KLWL P SITP = 400 psi, IA = 380 psi, break circ down tbg taking returns to kill tank, ICP 260 psi on tbg at 3 bpm, FCP at 390 psi tbg - 100 psi IA at 4 bpm, pumped 300 bbls 10.5 brine, shut in and monitored well. 9/23/2008 NU and tested 11" BOPE, unseat hanger and pump hot seawater down IA to clean tbg, displace with 10.5 brine, POOH f/6,639' t/ 3,780' standin back 3 1/2" tb . 00:00 00:30 0.50 COMPZ WELCTL OWFF P Monitor well while cont rack and tally 3 1/2" DP. SITP = 0, IA = 0. 00:30 02:30 2.00 COMPZ WELCTL NUND P RD circ lines, blow down hard line, set BPV ND tree. Install test dart. 02:30 06:30 4.00 COMPZ WELCTL NUND P NU 11" BOPE w/ 3.5" pipe rams. Grease choke manifold. 06:30 10:30 4.00 COMPZ WELCTL BOPE P Test ROPE at 250/3,000 psi on chart. Witness of BOP test waived by AOGCC Rep Chuck Scheve at 8:00 am, 9-22-08. 10:30 11:30 1.00 COMPZ RPCOM OTHR P Pull Test Dart and Install isolation sleeve. PU and MU Landing jt into TD. BOLDS+_ Pull hanger up 5' com letion free wt was 80k u wt. F~age 1 s~f f~ I Time Logs Date From To Dur S. De th E. De t~h Phase Code Subcgde T Comment 11:30 12:30 1.00 COMPZ RPCOM CIRC P Reverse Circulate 290 BBLS of 127? Sea Water @ 6 bpm @ 740 psi. Veri well is still dead. 12:30 13:30 1.00 COMPZ RPCOM CIRC P Circulate well w/ 10.5# KWF taking Sea Water returns to Tiger Tank @ 7 bpm @ 900 psi ICP and 1,110 psi FCP. 13:30 14:00 0.50 COMPZ RPCOM OWFF P Monitor well for flow -Static, BD Hardline 14:00 16:00 2.00 COMPZ RPCOM PULD P Pull hanger to rig floor remove penetrators, lay down hanger, pup jts and landing jt. Heat trace was parted @ penetrator. Meg ESP Cable -Grounded. Gages and Tec wire checked good. RU heat trace and ESP Sheeves. 16:00 00:00 8.00 6,639 3,780 COMPZ RPCOM TRIP P POOH w/ ESP Completion, 4 bbl „~ ~ +~ ~ 3 hole fill for 1st 5 stands. ~ 9/24/2008 Continue to POOH f/3,780' w/ ESP Completion, Inspect ESP Components. PU, MU and Rih w/ 6.75" Clean out BHA on 3 1/2 DP to 6,620' and to fill. 00:00 06:00 6.00 3,780 27 COMPZ RPCOM TRIP P Continue POOH w/ ESP completion from 3708'. 06:00 08:00 2.00 27 0 COMPZ RPCOM PULD P LD ESP. Cable extruded from center of pothead at surface from pressure trapped in motor. Motor oil OK. Rub or blowout found on MLE splice. Recovered 1689 bands, 443 6' flat guards, 28 4' flat guards, 18 3' flat guards, 3 protectalizers & 62 LaSalle clam s. 08:00 10:30 2.50 COMPZ RPCOM OTHR P Clean up & load out ESP equipment. Found four more bands under rotary bushin . 10:30 11:30 1.00 COMPZ RPCOM OTHR P Attempt to set wear bushing. More bands in BOP. Open upper pipe ram doors and remove one 6' flat guard & 4 bands. Total now 444 6' flat guards & 1697 bands. 11:30 12:30 1.00 COMPZ WELCTI BOPE X Set test plug. Close upper pipe rams on test joint & shell test BOP below 250/3000 si. 12:30 13:00 0.50 COMPZ WELCTI OTHR X Pull test plug, set wear bushing. 13:00 15:00 2.00 COMPZ RPCOM OTHR P Load out boxes containing flat uards, clam s & bands. 15:00 16:00 1.00 0 306 COMPZ RPCOM PULD P Sin le in w/ 6.75" bit, three 4.75" boot baskets & 9 DC's. 16:00 23:30 7.50 306 5,961 COMPZ RPCOM TRIP P 'n w/ clean out BHA f/ 306' to ' (tag 13.5' in on jt# 196). POOH w/ 7 stands standing back in derrick. 23:30 00:00 0.50 5,961 6,607 COMPZ RPCOM TRIP P Single in w/ Clean out BHA f/ 5,961' t/ 6,607'. 9/25/2008 Clean out fill f/ 6,620' to PBTD. POOH and lay down BHA. MU Straddle packer assy. Lay down setting sleeve and runnin tool to return to vendor. ~_ ~_ _ _ -- page 2 of 6 ~. ~~ ~ ~~~ r r~ Time Logs __ _ __ _ Date From To Dur S De th E. De th Ph se Code Subcode T Comment 00:00 04:00 4.00 6,607 6,993 COMPZ RPCOM CIRC P Gather parameters 115k up wt, 58k do wt, 80k Rot wt @ 50 rpms w/ 5,200 ft/Ibs free torque. SPR pump 1 @ 35 spm @ 160 psi, 51 spm @ 330 psi. Pump 2 @ 35 spm @ 150 psi, 51 spm @ 320 psi. Circulate @ 137 spm / 8 bpm @ 1,920 psi. w/ 39% flow return. Clean out from 6 620' to 6 993'. 04:00 04:30 0.50 6,993 6,605 COMPZ RPCOM TRIP T TD Failure -Pooh from 6,993' to 6,605' 04:30 07:00 2.50 6,605 6,605 COMPZ RPCOM OTHR P Trouble shoot Electrical for top drive. and build it volume. 07:00 10:00 3.00 6,605 7,296 COMPZ RPCOM TRIP P RIH f/ 6,605' to 6,993'. Wash down f/ 6 993' to 7,296' and Tag up on PBT_D. Circulating @ 8 bpm @ 1,950 psi. Continue to Circulate hole clean @ same rate. 10:00 12:00 2.00 7,296 COMPZ RPCOM CIRC P Reverse circulate @ 5 bpm @ 200 psi while rotating @ 5 rpm w/ annular closed. Slow PR down to 4 bpm ICP 210 psi, FCP 420 psi. 195 bbl loss to formation. 12:00 12:30 0.50 COMPZ RPCOM OWFF P Monitor well, well breathing. Blow down TD. 12:30 13:00 0.50 7,296 7,205 COMPZ RPCOM TRIP P POOH laying down 10 joints DP f/ 7,296' to 7,205' -Monitor well static. 13:00 17:00 4.00 7,205 306 COMPZ RPCOM TRIP P POOH standing back DP f/ 7,205' to 306'. 17:00 18:30 1.50 306 0 COMPZ RPCOM PULD P Lay down clean out assy and clean boot baskets. 18:30 20:30 2.00 COMPZ RPCOM OTHR P Held PJSM w/ Crane personnel and rig crew for unloading and reloading ESP Cable spool and Heat trace s ool. S of and set a ui ment. 20:30 23:30 3.00 0 136 COMPZ CASING PUTB P RU floor equipment for 4 1/2 Scab inner liner. Held PJSM and egin installing 4 1/2 Scab inner i~ner~2 • Premier packers. MU and install inner string. PU and prep HR setting sleeve. 23:30 00:00 0.50 136 136 COMPZ CASING PUTB T Setting sleeve released from running tool. Lay down failed equipment and prep for return to Baker Production in Dead horse 9/26/2008 Pooh w/inner string and scab inner liner assy. WO on running and setting equipment to arrive. RIH w/ same, MU running assy and RIH. Had problems attempting to set scab liner across desired perfs. POOH w/ Runnin tool and innerstrin and NO Straddle Packer ass . 00:00 03:30 3.50 136 136 COMPZ CASING OTHR T Pooh w/ straddle packer assy -wait on equipment setting sleeve and running tool to be delivered to Prudhoe and returned. Rih w/ Straddle aaker ass in re aration. 03:30 04:00 0.50 136 162 COMPZ CASING PUTB P PU and MU setting sleeve and runnin tool to innerstrin and 04:00 04:30 0.50 162 162 COMPZ CASING OTHR P Change over to DP Equipment ~_..~.__._ ~ Page 3 of 6 1 Time Logs Date From To Dur S. Depth E. Depth Phase __ Code _ Subcode T Comment _ _ __ 04:30 11:00 6.50 162 6,834 COMPZ CASING RUNL P Rih w/ 4 1/2 scab liner on DP f/ 162' to 6834'. Top element at 6725.3, bottom element at 6810.2'. 15 Bbls/Hour losses while tripping in hoe. 11:00 14:00 3.00 6,834 6,834 COMPZ CASING CIRC P Reverse circulate 25 Bbls. inhibited brine (1 % CRW-32). Displace with 220 Bbls. brine. 40 Bbls/Hr. losses while reverse circulatin at 2 BPM. 14:00 18:30 4.50 6,834 6,834 COMPZ CASING RUNL T Drop .90" OD BAII and attempt to set Straddle packers. Pump 3.6 DP volumes @ 3 bpm @ 320 psi. Drop 2nd .90" OD ball and attempt to set Straddle packers. Pump 2.7 DP volumes @ 3 bpm @ 320 psi. Drop 1.75" OD Ball in attempt to set Straddle packers. Pump 2.3 DP volumes 3 b m 290 si. 18:30 19:00 0.50 6,834 6,834 COMPZ CASING OTHR T RD Test equipment and clear floor. 19:00 22:30 3.50 6,834 162 COMPZ CASING RUNL T POOH w/ Straddle packer assy. Found to have lost the Premier Straddle packer assy off of the runnin tool. 22:30 23:30 1.00 162 0 COMPZ CASING OTHR T Lay down inner string components 23:30 00:00 0.50 0 0 COMPZ CASING OTHR T Unload 2 3/8 inner string from pipe shed alon w/ handlin tools. 9/27/2008 WO fishing tools. MU and RIH w/ spear assy and recover Straddle packer assy. Redress running and settin tools. RIH w/ straddle acker ass to 1,706'. 00:00 01:00 1.00 0 COMPZ FISH WOEO T Wait ing for fishing tools to arrive. 01:00 01:30 0.50 COMPZ FISH SFTY T Held PJSM w/ crew 01:30 03:00 1.50 0 316 COMPZ FISH PULD T PU, MUand RIH w/ Spear BHA ass . 03:00 06:00 3.00 316 7,170 COMPZ FISH TRIP T Rih w/Spear assy w/ 3.947" Nominal catch ra le on DP 06:00 07:00 1.00 7,170 6,160 COMPZ FISH TRIP T Latch into fish at 7152', pushed down. to 7.170', PUH with 12000 over pull. Lay down 4 singles. Stand back DP. Losses still 07:00 08:00 1.00 6,160 6,160 COMPZ FISH SFTY P Man Down Drill with KRU emergency services. 08:00 11:00 3.00 6,160 6,160 COMPZ FISH TRIP T Continue POOH 11:00 13:30 2.50 6,160 0 COMPZ FISH PULD T Stand back drill collars, lay down fishing tools and packer assembly. Hot shot packer assembly to BOT for ins ection/redress. 13:30 19:00 5.50 0 0 COMPZ CASING WOEQ T Waiting on return of packer assemblies 19:00 20:00 1.00 0 0 COMPZ CASING OTHR T Load pipe shed w/ Straddle packer ass and handlin tools 20:00 23:00 3.00 0 159 COMPZ CASING PUTB T PU, MU and Rih w/ Straddle packer ass and inner strin I?a~4ofS • Time Logs Date From To D~ r 5- De th E De th Pha9e Code Subcode T Comment 23:00 00:00 1.00 159 1,706 COMPZ CASING __r RUNL T RIH w/ Straddle Packer Assy on DP f/ 159' to 1,706'. 50k up wt., 47k do wt. 9/28/2008 Continue to RIH w/ Straddle packer assy to desired depth. Circ packer fluid. Drop ball and set straddle acker ass .Release off ass and POOH w/ DP PU and MU ESP Com letion and RIH. 00:00 03:00 3.00 1,706 6,834 COMPZ CASING RUNL T Continue to RIH w/ Straddle Packer assy to 6,832.0 100k u wt., 62k do wt. 03:00 04:00 1.00 6,834 6,834 COMPZ CASING CIRC T RU and Circulate 25 bbls of corrosion inhibited brine and follow w/ 51 bbls KWF 2 b m 180 si. 04:00 05:30 1.50 6,834 6,834 COMPZ CASING OTHR T Drop ball and wait for 20 minutes and Begin pumping @ 2 bpm @ 310 psi and seat ball @ 36 bbls pumped. Pressure up to 500 psi. Bleed pressure off IA. Open Annular and Pressure up to 3,000 psi w/ Rig test pump and initially set packers. Pump up @ 500 psi increments and set for 5 minute intervals setting packers. Shear ball seat @ 4,900 psi. Dump pressure and slack off 12k, verify packers set. RD Test um . 05:30 12:30 7.00 6,834 124 COMPZ RPCOM TRIP P POOH laying down 72 jts DP and stand back 45 stands. 12:30 14:00 1.50 124 0 COMPZ RPCOM PULD P Lay down packer setting tools and inner strin . 14:00 15:00 1.00 0 COMPZ RPCOM OTHR P Load out inner string and move DC's in derrick from in front of 3 1/2 Tubin . 15:00 17:00 2.00 COMPZ RIGMNT SVRG P Slip and Cut 84' drill line 17:00 17:30 0.50 COMPZ RPCOM OTHR P Pull wear ring. 17:30 23:00 5.50 0 70 COMPZ RPCOM PULD P Load ESP com letion a ui ment and service the same. Install motor lead and Baker Guardian Gauge. Splice TEC wire. 23:00 00:00 1.00 70 306 COMPZ RPCOM RCST P Rih w/ ESP Completion on 3 1/2, 9.3#, L-80 8rd EUE AB Mod. tubing and jewelry to 306'. 40k up wt, 40k do wt. 9/29/2008 Continue to RIH w/ ESP Completion and land. ND BOPE 00:00 16:00 16.00 306 6,593 COMPZ RPCOM RCST P Continue to RIH f/ 306' to 6,593'. Had twist in round cable @ 55 jts in the hole @ 1,681'. (This will be f/ 4,929' to 4,959' when landed.) Start Heat Trace at -3600' (3000' when landed 16:00 21:00 5.00 6,593 6,593 COMPZ RPCOM PULD P MU hanger and splice ESP and Heat Trace to penetrators. Check integrity on ESP cable, Heat Trace and Guardian ua e. ~ Page ~ caf 6 Time Logs _ _ _____ _ _ D ate From To bur S De tht E. th Phase Code Subcode T Comment _ 21:00 21:30 0.50 6,593 6,640 COMPZ RPCOM HOSO P Land Hanger and RILDS w/tail @; 6,640'. Back out landing jt. 90K up wt, 50 do wt, 35k Block wt. Clamps used: 64 -Single channel X cplg, 84 -Dual Xcplg, 487 - 5' Dual Channel, 5 - 4' Dual Channel, 20 - SS Bands and 1 End shoe on heat trace. 21:30 22:00 0.50 COMPZ RPCOM SFEQ P Test void and Pack off to 5,000 psi. - held 22:00 22:30 0.50 COMPZ WELCTL OTHR P SetTWC 22:30 00:00 1.50 COMPZ RPCOM NUND P Held PJSM and ND ROPE. 9/30/2008 NU Tree, and test to 5,000 psi. Install HBPV. RDMO to 1 D-121 00:00 01:30 1.50 COMPZ RPCOM NUND P Continue to ND BOPE 01:30 02:00 0.50 COMPZ RPCOM DHEO P Test ESP Cable, TEC wire and Heat Trace. -all tests ood 02:00 03:30 1.50 COMPZ RPCOM NUND P NU Tree 03:30 04:00 0.50 COMPZ RPCOM SFEQ P PT tree to 5,000 psi and hold for 10 minutes. 04:00 04:30 0.50 COMPZ RPCOM OTHR P Set BPV and secure well. 04:30 05:00 0.50 COMPZ RPCOM SFEO P Conduct Final Test on ESP Cable, TEC Wire and Heat trace. Release Nordic Ri 3 0500 hrs P~~~ b ct 6 Cortocol'hillips ~.i.,,;n,:, i11:i HANGER. 41 GAS LIFT, 4,320 GAS LIFT, _ fi,527 GAUGE, 6,570-- - INTAKE, fi,612 ESP SEAL, 6,617 GEAR 80%, 6,630 MOTOR 6,632 IPERF. 6,6fi26,fi98 SLEEVE, 6,691 ~-- NIPPLE. 6,706 SACKER. 6,721 IPERF, 6 ]446,770 iCKER, 6,806 W LEG, 6,831 IPERF, fi,B76b,882 IPERF, 6.918£.932 KUP 1 D-127 NONE i 2 7/1/2008 'Last WO' 9/28/2008 I 47.50 I 7/8/1998 ion Depth (ftKB) IIEnd Date 'Annotation End Date ig~ 6483.0 4/15/2008 'Rev Reasorr WORKOVER 1015/2008 lg Strings Descr p[ on Str ng 0... Str ng ID ... Top (ftKB) 'Set Depth (f .. Set Dapfh (TVD) .. 'St g Wt... St g G .. Str ng Top Thi JCTOR 16 15.062 QO 121.0 121.0 62 SS H-00 ~ WELDED Descr pion String 0... Str ng ID ... '.TOp (ft K8) Set Depth (f .. Set Depth (TVD)...St g Wt... St g G ... Str ng Top Th .CE 7 5/8 6.750 0.0 7 416.0 4,014.3 29 70 L 80 ABM-BTC ig_ Strings Description String 0... String ID ...'Top (ftKB) -- - - 'Set Depth (f... Set Depth (lYD) ... - --- (Siring Wt... ~IStdng Gr 'i5trmg Top Th 31/2 2.992 0.0 6,640.3 3,469.5 L-80 ~EUE 8RD 930 ~ I AB-Mod i ~letion De I Top Depth tails I (ND) Top R1I, (ftKB) ~' Incl l°I na,~ nr..rr,~.n~„ Cnmmwnt ID lI 6,570.5 3,424.5 50.59 GAUGE Guardian guage 3.500 6,612.0 3,451.0 48 88 INTAKE TTC Crossover coupling w/ perforated intake 2.992 6,616.6 3,454.0 48.84 ESP SEAL Tandem Seal Section GS83OB 0.000 6.630.2 3,462.9 48.72 GEAR BOX GRU 525 9:1 0.000 6,631.5 3,463.7 48J7 MOTOR ESP Motor 57 hp KMH 1315V/26A 0,000 6,638.3 3,468.2] 48.65 CENTRALIZER I Motor Centralizer 0.000 Tubing Description (String 0... String ID ...' Set Depth (TVD) ... String Wt... String Gr... Top (ftKB) Set Depth (i... _. _ String Top Thrd '~BSand St raddle 41/2 3.958 ( 6,697.2 6,8320 3,598.3 12.60 L-80 IBT IPKR Com le tion Details Top Depth' Top (ftKB) (TVD) (ftKB) Top Incl (°) Item Description Comment _ _ ID (in) 6,691.2 3.504.8 48.21 SLEEVE "HR" Liner Setting Sleeve 5.750 6,703.8 3.513.1 48.09 NIPPLE "RS" Pack off Seal Nipple 4.875 6,721.0 3,524.3 47.94 PACKER Baker Premier Production Packer ~ 3.875 Bim Schematic9.0 1 4.0 IPERF 0 deg phased down 4.0 IPERF 0 deg phase, down 4.0 IPERF 0 Deg phased, down 'ep 'i I Port _- __ ___._ n I OD ~ Valve ~ Latch Size TRO Run. (°) ', Make Model (in) Sarv I TYW TYPe ('^) IPsil Command Run Dale IPERF, _ 6,962-7,002 SURFACE, 0-7,416 TD. 7.632 . ,, Maunder, Thomas E (DOA) From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Monday, October 27, 2008 4:09 PM To: Maunder, Thomas E (DOA) Subject: RE: 1D-127 (198-109) Tom, n Page 1 of 2 When you mentioned the scab liner in your previous email I immediately realized the error on my part for not having filed a 10-403 since we were modifying the casing by running a scab liner across the B-sand. I mentioned it to Howard also, and he too was awestricken that it hadn't even crossed any of our minds. Running the scab liner was a last minute change to the workover procedure that was proposed as a way to mitigate the MBE that had taken place in the B-sand. 1 think we were so caught up in the fact that we had come up with a solution to fix the MBE on the producer side of things and get this welt back online vs. try and attack the MBE from the injector side, that we unintentionally overlooked the required Sundry. t apologize for this oversight, please let me know what course of action I need to take to rectify this situation. ,~ Brett Sacker Drilling BZ `lNelis 'workover Engineer zNork# 265-6845 Cell'# 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 27, 2008 3:51 PM To: Packer, Brett B Subject: ItE: 1D-127 (198-109) Thanks Brett. Did you get my further message, regarding if we had communicated about the scab liner? Tom From: Packer, Brett B [mailto:).Bret#.Packer@conocophilfips.com] Sent: Monday, October 27, 2008 3:49 PM To: Maunder, Thomas E (DOA) Subject: RE: 1D-127 (198-109) Tom, On 9124, we couldn't set the wear bushing because there was additional debris in the BOP stack that had gotten hung up upon pulling the ESP completion. I spoke w/ the Rig Supervisor and he said that the 4 bands and a 6' flat guard were lodged across the blind rams so we couldn't get a plug or anything downhole to mechanically secure the well and still be able to retrieve these items at that time. This is why he had them open the upper pipe ram doors and reach into retrieve these items, so that we still had the ability to close the blind rams if needed. We had 10.5 ppg KWF in the hole at the time. The BOP stack was configured w! 3.5" rams in the lower and upper pipe rams as shown in the attached BOP sketch. Please tet me know of any other questions or concerns. 10/28/2008 . .~ ,. ,y Brea Backer trg ~ 9NelZr 2~orkover Engineer 'Wotf,# 255-6845' Cell # 230-8377 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, October 27, 2008 10:00 AM To; Packer, Brett B Cc: Regg, James B (DOA) Subject: 1D-127 (198-109) LJ Page 2 of 2 Brett, I am reviewing the 404 recently submitted for the workover on this well and have some questions. 1. On 9/24, it proved not possible to set the wear bushing due to banding/guard debris in the BOP and the upper pipe ram doors are opened to remove them. How was the well mechanically secured at that time? Were the blind rams closed? 2. What rams were employed in the stack for this workover? Thanks in advance. I took forward to your reply. Tom Maunder, PE AOGCC 10/28/2008 . . ~ ConocoPhillips Alaska RECEIVED JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 S'~~~ JUL 11 2007 176 ./ \ O~ \0\ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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. Please M.J. Loveland at 907-659-7043, if you have any questions. ConocoPhillips Well Integrity Project Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name pro # cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/912007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 61912007 10-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 619/2007 10-113 198-178 2" na 1 6/9/2007 10-114 198-159 2" na 1 619/2007 10-115 197-232 2" na 1 6/912007 10-116 198-172 2" na 1 6/9/2007 10-117 197-237 2" na 1 619/2007 10-118 197-229 2" na 1 6/9/2007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/912007 1O-125a 200-044 2" na 1 6/912007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 (~ ',""~-¡\ " PRoAc1ive DiAGNOStic SERvicES, INC. e e WELL LOG TRANSMITTAL To: AOGCC. Attn: Ceresa Tolley 333 West 7th Avenue Suite 1 00 Anchorage, Alaska 99501-3539 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Calìper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmìttalletter to : ProActive Diagnositc Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (901) 245 - 8952 1] 1C - 119 MTT Report 16-May-06 2) 1 C - 121 MTT Report 16-May-06 3] 1C-131 MTT Report 14-Jun-06 I 'fß -I \), 4] 10 - 127 MTT Report 14-Jun-06 5) 10 - 121 MTT Report 14-Jun-06 6] 1 0 - 1 09 MTT Report 1 5-Jun-06 7] 1 0 - 120 MTT Report 15-Jun-06 8] 10-111 MTT Report 15-Jun-06 Signed: M-wJ öiJJ Print Name: µ. D \.U IJ.v I/' À~ Ok lll,^¿" Date: 1/ J u t¡ ~ ~ ~ PRoAcTivE DiAGNOSTic SERviŒ', INC., ]}O W. INTERNATioNAl AiRpoRT Rd SuiTE C, ANCltoRAGE, AK 99 ~ ] 8 PltoNE: (907)24~-89~] FAx: (907)24~-89~2 E-MAil: pdSl'.i\J(koRi\GE@¡,¡EMORV!oq.COM WEbsiTE: MEMoRyloG.COM C:\My Documents\ W ork\ DistributionLablesNew\ Transmit_ Original. doc I I I I I I I I I I I I I I I I I I I Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: Pipe3 Desc.: Pipe3 Use: Inspection Type: e e Memory Magnetic Thickness Tool Log Results Summary q ~ v \ 09 ConocoPhillips Alaska, Inc. June 14, 2006 8032 1 3.5" 9.3 Ib EUE Tubing 7.625" 29.71b BTC Production Casing 16" 62.6 lb. Welded Conductor Pipe Well: 1D-127 Field: Kuparuk State: Alaska API No.: 50-029-22890-00 Top Log InM.: Surface Bot. Log Intv!.: 190 Ft. (MD) Top Log InM.: Surface Bot. Log InM.: 190 Ft. (MD) Top Log InM.: Surface Bot. Log Intvl.: 121 Ft. (MD) Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Tubing Hanger @ 0' Depth. This is the first log of this well with the 12 Arm Magnetic Thickness Tool (MTT). The Magnetic Thickness Tool responds to the total metal thickness of the 3.5" tubing, 7.625" production casing, and 16" conductor pipe within the logged interval. Due to the concentric pipe strings in the log interval, the MTT response is qualitative - indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTTwas calibrated down hole (100'), where the readings are assumed to represent undamaged tubing, casing and conductor pipe. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 7.625" casing, and 16" conductor pipe. The total volume of metal encountered by the MTT's qenerated AC maqnetic wave between the surface and the bottom of the 16" conductor pipe in this well exceeded the tool's rated capacity for transmission of a full clean siqnal. However. the data recorded appears to provide a relative indication of total metal surroundinq the tool. with one interval indicatinq minor metal loss. The reported percentaqe metal loss intervals in this report are not considered to be a percentaqe of any particular volume of metal. but merely a relative correlation of indicated metal loss throuqhout the loqqed interval. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval 0' - 190'. A log plot of the entire log interval, plus detailed sections of intervals showing metal loss are included in this report The Delta Metal Loss (%) curve in these plots refers to total metal surrounding the MTT tool and the results show one interval of metal loss. A maximum of (-7%) circumferencial metal loss is recorded in the interval below the hanger and -3.5'. No other significant areas of metal loss are recorded. The percent circumferencial metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 3.5", 7.625" and 16" pipe. If all of the metal loss is specific to the 7.625" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: R. Richey & J. Halvorsen Analyst: M. Tahtouh & J. Burton Witness: T. Sendon I ProActive Diagnostic Services, Inc. I P.O. Bo;< 1369¡ Stafford, TX 77497 Phone: (281) Ot' 565-9085 Fax: (281) 565-1369 E-mail: PDS:çÜmemorylog.com P¡'udhoe Bay Field Office Phone: 659-2307 Fax: 659-2314 I I I I I I I I I I I I I I I I I I I cIas. I"~ lDi"G_Y¡c SE""I",,,,, iNC. nø,~iI Metal Loss - 3. Database File: Dataset Pathname Presentation Format: Dataset Creation: Charted by d: \warrior\data\ 1 d-127\ 1 d-127. db Kuparuk/1D-127/run1 {log8h. 1 22SCAl-Î Frì Jun 16 08:11:19 2006 by Calc Sondex Warrior V7.0 Depth in Feet scaled 1 :60 -50 Delta Metal loss (%) 50 g,,-- If~.'.' UDlng Hang I n 5%, Me~al Loss I I I PupJt. 4*TII 7% Metal loss ,-3 5" Collar . : I Pup Jt. . I I I I I ~7625" Casir.9 Collar ~--3.5" COllar~ I I I -·f~- ), -3.5" Coliar-= 4:: I I 20 ------ 2.2 -6.6 ~ ~ > ¡.-.., "'"-. t Jt. & ~ I I ~~ I I .[ -50 Delta Metal Loss (%) 50 2.2 -6.6 MTTP01 (rad) MTTP12 (rad) 12.2 3.4 " :: < .. I <:, I ¿ '> c :> MTTP01 (rad) MTTP12 (rad) 122 3.4 I I I I I I I I I I I I I I I I I I I ---- -- u_ ~ Magnetic Thickness ".....1 I, ....___'1. \onz r a\:Jci) p~ DiAqNò'iTÌè SElIVicE'i¡. INC. Database File: d:\warrior\data\1d-127\ 1 d-127db Dataset Pathname Kuparuk/1D-127/run1/log8h.1 Presentation Format: 22SCAL -1 Dataset Creation: Fri Jun 16 08:11:19 2006 by Calc Sondex Warrior VTO Charted by Depth in Feet scaled 1 :150 -50 Delta Metal Loss (%) 2.2 MTTP01 (rad) 12.2 -6.6 MTTP12 (rad) . ¡T~ I I I TUbing,Ha 5% Metal Loss Pup Jt: -3.5" Collar 7% Metal LiS ~--- - Pup Jt. - ~ I . -3.5" Co¡lar~ ' .bL~ Casing Collar i m Pup Jt. I '1n -3.5" Colla!"" -- --- -- 3.5" , Jt 1 40 l I 7. 625" Casing Collar ~3.5" Collar I 60 ._-~- --- 3.5" - - ~------- ------ Jt. 2 I I f Bottom of 16" Conductor au - - 3.5" Collar - __ __ , 'irl ~+ - 7.625" Casing Collar r- ---' I -- 3 3.5" - Jt 3 =~ I 100 - , I I I I I I I I I I I I I I I I I I I I I ~ I -==;¡ == ---' - ~ ~-~- ~~ ~ - ~ f--- 3 5" Collar < ~ ~ , 120 ~ - -- f--- - 4 ~ - 3~5" ~ Jt 4 ,-- ~ - , , --^---- --- -- kÁ- -7.625" Casing Collar -~~ , ~ , 140 f~-~~-~- -~-~--- f--- I _ â 3.5" Collar· 1----- -~- ---- -~- ..; '- ~ I"~m ~--- ~ ~ --~ --~ --, ~-~ ~ ,~ ~ 160 F: m 1- - [ J f---' 3.5" I--- I Jt :::> I--- I I f--- I I f= I 'I I I !-- 3.5" Collar- ~.625" Camng Collar - 180 ~ - ~ 3.5" ~ --~ I-~- ~ Jt 6 ~ = - ~ - - ill p¡¡;: I - -- f Delta Metal Loss (%) 50 2.2 MTTP01 (fad) 12.2 -6.6 MTTP12 (rad) 3.4 I I TUBING (0-6614, 00:3,500, 10:2,992) Gas Lift MandrelN a Ive 1 (6523-6524, °ROOUCTlON ~- (0-7416, 00:T525, Wt29.70) I I I GAUGE (5567-6568, OD:4,500) I Pl'.CKOFF (557Q.6579. OD:3,500) I PUMP (6579-5616, 00:2,313) I I I NIP (6611-13616, 00:3,500) XO (5614-5615, 00:3,500) SEAL ------- (6616-6629, 00:5,130) GEAR (6629-6631, 00S250) MOTOR (6631-13638, 00:5,620) I I I Perf (6662-6698 ) I Perf (6744-5770) I Perf (6876-6882) I I Perf (6918-6932) I Perf (6962-7002) I KRU 1 D-127 2,992 2.992 0.000 0.000 0.000 Note WAIVER ED WELClAxüÄ CüMMUNICÄTTo¡\r--~------ -~----l I ~~---~~,~~_.~-- Ll" yvu. '-'UI1U~UJ. 1111Up~ L^~a.Va.L1UJ1 u<,. 1'\.....pUll 11UJ........LJ "--- "- Subject: [Fwd: ConocoPhillips Excavation & Repair Project) " From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 20 Jun 2006 07:00:24 -0800 reo: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding <john _ spaulding@admin.state.ak.us>, John· Crisp <john _ crisp@admin.state.ak. us> ~ Jeff Jones kjef(jones@admin.state.ak.us>, Chuck Scheve <chuck _ scheve@admin.state.ak.us>, Jim Regg ;gim _ regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom \t>-\ð\ \~~~\O\ Subject: Date: From: To: CC: -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <N1878@conocophillips.com> tom maunder@admin.state.ak.us Ñ-SKWefr-"""Integrity-Proj <N1878@conocophillips. com> , aogcc p~udhoe bay@admin.state.ak.us Tom: I donlt remember how much of our plans we have shared with you on excavating and repairing wells at 1C & lD pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to IIpro-activelyll excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «lC and 1D Casing Repair List AOGCC.xls» «SPE-100432-PP SC Corrosion West Region 2006 Final.doc» Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 SCANNED JUN 2 7 2006 __ .. no ._u ._________________ Content- Type: application/vnd.ms-excel IC and ID Casing Repair List AOGCC.xls Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 Final.doc Content-Type: 10f2 6/26/2006 7 :51 AM PRIORITY 1 2 3 4 5 ') 6 \ ~ '6-- \ \) <; --., 7 8 9 10 11 12 13 14 15 16 ) Notes: ---., NAME 1 C-121 1 C-131 1 0-1 09 1 0-111 ConocoPhillips Alaska, Inc. 1C and 1 D Suñace Casing Corrosion Repair Candidates TYPE PTD# LEAK DEPTH (ft) "'''--...,.-- INJ 201-080 4 ---- INJ 201-185 7 - INJ 197 -235 5* INJ 198-166 5* -- INJ 197-221 7 - Gas Lift 197-181 None Gas Lift 198-1 09 None INJ 198-121 5 INJ 200-046 None -. INJ 200-047 None INJ 200-048 8 - - . _.- - INJ 200-049 None -- -.- INJ 201-139 16 Jet Pump 201-220 None ESP 197-184 None Gas Lift 200-112 None COMMENTS I STATUS 10..127 ._~ __..__0_____,...__..._....... 1 0-132 10-136 10-137 .. _ _'.__",_,_.,'__0'__4,_,.__" .0_ 1 0-138 1 0-139 1 C-119 .--..---~-- - "....-.,.....-. ... . -- '·'-·-1 1C-.t3S : I ,_. .......~. J...." .'.. ,.,..,..___... .....,... .___.._.,..~....,..;. .~., ..." ".' . . . . I :.._._....,........,__,...!B~~~,.~~_.,_...,.;.......,...J 1D':;141 ! I Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 1 D-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 ·@.".',...'Ti.'.I...... ...m·.A!!.V'.' rrF... . ...,\' 1 I ! iIJ\ ., I P ® U Ln.J . L!:::J IrrTI' : . rr· · I'i' n UJJ. U· ' · : Þ.J, ,. b\. Î..I ! . ! 'J I \ ' ! ¡J LflJ b (fù n~' ~' ~... ",\, "~' ,J &11, "''''\Ll cW U\ib-u e I / FRANK H. MURKOWSKI, GOVERNOR ! l ,I / / J 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 A ....ASIiA OIL AlVD GAS CONSERVATION COMMISSION l ,j f MJ Loveland WI Project Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 'I\l(¡/\D~ Re: Kuparuk River Field, West Sak Oil Pool, 1D-127 Sundry Number: 306-210 ,r·'· n \ì':~ <h 29 'K"A~~~¡¡:;:~) ..,'''' , J 0'- ~yl~;'<"'" ,r 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisJiday of June, 2006 Encl. IQY-Io'ì e Conoc~illips Alaska e FU~.·CE'VED P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ,\ '\\' "J ') 70!Ì6 JU1' }.:J '- ) ¡Qil& An¡;hmage ..µ',,., June 9, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approval to proactively inspect and repair the production casing if needed for ConocoPhillips Alaska, Inc. wells 1D-121 (PTD # 197-181) and 1D-127 (PTD # 198-109). Neither well indicates any signs ofa production casing leaks, however they are both drilled in an area where near surface production casing leaks have been a problem. Please call me or Jerry Dethlefs at 659-7043 or Marie McConnell or Perry Klein at 659- 7224 if you have any questions. SinCerelY:µ' ~and Well Integrity Project Supervisor -- Attachments '^- 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver It!!Jhorage Other 0 Alter casing 0 Repair well 0 . Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska,lnc. Development 0 Exploratory 0 198-109 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22890-00 It, 7. KB Elevation (ft): 9. Well Name and Number: RKB 112' 10-127 . 8. Property Designation: ~.¡3'L".þ 10. Field/Pool(s): Kuparuk River Unti ¡4þL- 2..Ç'~D Kuparuk River Field / West Sak 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): 7432' , 4026' Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 PRODUCTION 7304' 7-5/8" 7416' 4014 6890 4790 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6662-98',6744-70',6876-82',6918-32',6962-7002' 3484-3508,3539-3557,3629-3633,3658-3668,3688-3716' 3-1/2" L-80 6614' Packers and SSSV Type: Packers and SSSV MD (ft) no packer nô-SSSV , ' 00 SSSV , 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: July 1, 2006 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPl 0 Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dethlefs/loveland Printed Name MJ Lovel~ Title: welllntegritcervisor Signature --"..,~ --.. A .-- Phone 659-7043 Date 9 :r tJItltPó .I /- /' (; .... Commission Use Only , SUnd%"{;:.- ~t() Conditions of approval: Notify Commission so that a representative may witness Plug Integrity D BOP Test 0 Mechanical Integrity Test 0 location Clearance 0 Other: ~ ~\\"'l1: ~ ~c~, \,)., '> ~ ,c>.. "-t'-..2J I ~ 0'=> ~A· \>\'Û\-c ~ (Q -\ ~CbM.)-'§-~ '-(J..'>\ ""> S,b"q'e", Fo"" Req,'''''' ~"t) ~ ~ RBDMS 8Fl JUN 1 5 1006 ~ --1 ~~MMISSIONER APPROVED BY ~-/If-~ Approved by: THE COMMISSION Date: ~l~ .'---" .Að '-rs~ Form 10-403 Revised 7/2005 Submit in lie W~ r;(JJ 6/~t{~+/o. II ~:f"E e STATE OF ALASKA P4 ,-' "40 t", IVED ALASKA OIL AND GAS CONSERVATION COMMISSION II \ ~'JN r 3 2 APPLICATION FOR SUNDRY APPROVAL A .;-f",,,, 006 20 MC 25 280 ¡it",." (,,, & Gas Cons C n AL ~~ e e ConocoPhillips Alaska, Inc. Kuparuk WelllD-127 (PTD 198-109) SUNDRY NOTICE 10-403 APPROVAL REQUEST June 9,2006, This application for Sundry approval for Kuparuk well1D-127 is for the proactive inspection and possible repair of the production casing near surface. This well is a single casing gas lifted producer that has no surface casing. It was completed in 1998 and has been produced by ESP and gas lift. This well is in an area that has a recent rash of production casing leaks to surface. v 1D-127 has shown no signs or indications of a production casing leak however ConocoPhillips requests approval to pro actively excavate ~ 10', cut a window in the conductor and inspect the production casing in this well. If damage is present a patch will be installed. With approval, repair of the production casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well as needed with KWF and load the tubing and IA with appropriate weighted brine and diesel freeze protection cap, 3. Remove the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the conductor (and IA if needed) so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. A window will be cut in approximately the top ten feet of conductor to provide access to the production casing forinspectioIl.Notify AOGCC Inspector for opportunity to inspect. 6. CP AI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. Ifa patch is required, QAlQC will verify the repair for a final integrity check. 8. Install anti-corrosion coating as specified by CP AI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top offwith sealant. 10. Backfill as needed with gravel around the wellhead. . ~,-,c...~'cV\ 11. Remove plugs and return the well to w~. ~q) b'?"\ ~ h '-\ 12. File 10-404 with the AOGCC post repair. NSK Problem Well Supervisor 6/9/2006 e e ConOCoPhiIJipsAfaska)llnc. KRU 1D-127 .. . .... API: 500292289000 Well Type: PROD AiiQIe @TS: deQ (â) TUBING SSSV Type: NONE Orig 7/8/1998 Angle @ TO: 43 deg @ 7432 (!J..6614, Completion: 00:3,500, 10:2.992) Annular Fluid: 3% KCI /8.7 PPQ LastW/O: 11/24/1998 Rev Reason: Waivered Well Gas Lift - Reference LOQ: Ref LOQ Date: Last Update: 2/27/2004 MandrelNalve Last TaQ: 2220 TD: 7432 ftKB 1 Last T ao Date: 3/7/1999 Ie: 66 deQ @5057 (6523-6524, 'ROOUCTION (0-7416, DescriPtion Size Top I Bottom I TVD Wt Grade Thread 00:7.625, CONDUCTOR 16.000 0 I 121 I 121 62.58 H-40 WELDED Wt29,70) 1 PRODUCTION 7.625 0 r 7416 T 4014 29.70 L-80 ABM-BTC Size r Top I Bottom I TVD r Wt T Grade r Thread 3.500 r 0 I 6614 1 3453 1- 9.30 T L-80 I EUE GAUGE Perf9ri:ìtÌóriii $tillirili3rY;···' (6567-6568, Interval TVD Zone Slatus Ft SPF Date ' rVDe Comment 00:4,500) 6662 - 6698 3484 - 3508 WSD 36 4 9/24/1998 IPERF o de,g.phase down PACKOFF 6744 - 6770 3539 - 3557 WSB 26 4 9/22/1998 ¡PERF o dea chase, down (6570-6579, 6876 - 6882 3629 - 3633 WSA3 6 4 9/17/1998 IPERF o deQ chased down 00:3,500) 6918 - 6932 3658 - 3668 WSA3 14 4 9/17/1998 IPERF o deQ chase, down 6962 - 7002 3688 - 3716 WSA2 40 4 8/23/1998 IPERF o DeQ chased, down GaS: Lift Mäl'ldrëlsNal'ieS:'.;..'" St MD I TVD I Man Man Type V Mfr V Type I V OD Latch Port TRO Date Vlv PUMP_ Mfr Run Cmnt (6579-6616, 1 I 65231 33951 CAMCO KBMM CAMCO OV I 1.0 BK 0.188 0 2/26/2003 00:2,313) ·Other: Ü 'ItiliS:;~QU¡D;' 'ate; Depth TVD Type DeSCrïni¡on ID 6567 3422 GAUGE BAKER SENTRY GAUGE - PUMP INTAKE 3.500 6570 3424 PACKOFF 1.620 6579 3430 PUMP Centrilift Retrievable Pump 180ML2000 KUDU w/packoff & slipstop, set 0.000 4/25/2002 6611 3451 NIP SLOTTED NIPPLE 2.992 6614 3453 XO 2.992 6616 3454 SEAL Tandem seal GSB3 DB IL H6PFS 0.000 6629 3462 GEAR Gear reduction unit 9:1 525 series 0.000 6631 3464 MOTOR 57 HP 1315/26 KMH 0.000 NIP_ (6611-6616: ~ Date I Note 00:30500) :',' XO 1/30/200~WAIVERED WELL lAx OA COMMUNICATION (6614-6615, 00:3,500) SEAL_ (6616-6629, .00:5.130) - GEAR ~ (6629-6631, 00:5,250) MOTOR (6631-6638, 00:5,620) - ~ Perf - r-- (6662-6698) - r-- - r-- - r-- - f---- Perf - '--- (6744-6770) - - - - - f- Perf - r-- (6876-6882) - r-- - r-- - f---- Perf - f---- (6918-6932) - r-- - I-- - '--- Perf - - (6962-7002) - - --' f- - I-- L4uarLerly llowiine inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "n1617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1D-102 Insp Log.xIs)(See attached file: 1 D-105 Inspection Log.xIs)(See attached file: 1D-110 Insp Log.xIs)(See attached file: 1D-121 Inspection Log.xIs)(See attached file: 1D-127 Inspection Log.xIs)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xIs) I ~.3H:05.....Quarterlv Inspectios. Lo.q.xls] Type: EXCEL File (application/msexcel) [C.~ h - O'~ ~ '1 tEncoding: base64 ¢]~1D-102 Insp Lo.q.xls Type: EXCEL File (application/msexcel)t Encoding: base64 i J~ Name: 1D-105 Inspection Log.xls I J [~1D-105 Inspection Log.xIs Type: EXCEL File (application/msexcel)iI ~(~) ~,- ~(~c:~ Enc0ding:.....base64 il /~1D-110 Insp Lo.q.xls Type: EXCEL File (application/msexcel)l c~b~ ' (~"~ R / ' Encoding' base64 1D-127 Inspection Lo.q,xls Type: EXCEL File (application/msexcel)il Encoding: base64 .il Name:.. 1~-.1.27. Inspection Log,xls ~1 Type:' EXCEL File (applicat on/msexcel)!l I Encoding: base64 I of 2 10/6/2003 3:17 PM L~uarterly i'lowline inspection reports ~/~ I Name: 1D-129 Inspection Log.xls ~-"~1D-129 Inspection Lo.q.xlsI Type: EXCEL File (application/msexcel) I Encoding: base64 Type: EXCEL File (application/msexcel) 1D-140 Inspection Loq.xlsl Name: 1D-140 Inspection Log.xls I Encoding: base64 !of 2 10/6/2003 3:17 PM 1D-127 Special Inspection Request Log DS1D 1D-127 - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) · # of Worst Date of Comments Inspection Inspection B, I, N Case Wall Damage Locations Loss % Grade 03/06/03 6 B 0% A Base Line Inspection 03/11/03 6 N 0% A 1 - Day Follow-up Inspection 03/18/03 6 N 0% A 1-Week recur inspection 03/25/03 6 N 0% A 1-Week recur inspection 04/01/03 6 N 0% A 1-Week recur inspection 04/08/03 6 N 0% A 1-Week recur inspection 04/30/03 6 N 0% A.,-,. Monthly Inspection Interval 05/31/03 6 N 0% ..... A...--~''~ ,~.,..~ Monthly Inspection Interval 08~30~03 6 N .,...--0%~o-. · .,...-'...,~,,.~ .... Quarterly Inspection Interval · ./-- ,,, ., Qua, rtedy Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "rtl 617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-1 1D-1 1D-1 1D-1 1D-1 1D-1 02: PTD 2000750, Sundry #302-101 05A: PTD 2012020, Sundry #302-294 10A: PTD 2000390, Sundry #302-227 21: PTD 1971810, Sundry #302-304 27: PTD 1981090, Sundry #353-057 29: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1 D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1 D-140 Inspection Log.xls) Name: 3H-05 Quarterly Inspection Log.xls' ~__~3H-05 Quarterly Inspection Lo.q.xls Type: EXCEL File (application/msexcel) Encoding: base64 i¢~1D-102 Insp Log.xls Name: 1D-102 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding~ base64 I ,, Name: 1D-~105 Inspection Log.xls t~1D-105 Inspection Lo,q.xls Type: EXCEL File (application/msexcel)1 ~ Encoding' base64 I~ 1D-110 Insp Lo,q.xls Type: EXCEL File (application/msexcel)1 -- Encoding: base64 r~1D-121 Inspection Log.xls Name: 1D-121 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 1 of 'CAI NED "JUL :[ 6 2:803 7/14/2003 10:39 AM Quarterly Flowline line inspections ,,, r~ 1 D-127 Inspection Loq.xls! Name: 1D-127 Inspection Log.xls Type: EXCEL File (application/msexcel) i Encoding' base64 !¢~ 1D-129 Inspection Loq.xls Name: 1 D-129 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 r~1D-140 Inspection Lo,q.xls Name: 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 2 of 2 7/14/2003 10:39 AM 1D-127 Special Inspection Request Log - Flowback inspection - Weekly inspections for 1 month - Monthly inspections for 2 months then quarterly inspections until further notice B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Comments Inspection Locations Loss % Grade 03/06/03 6 B 0% A Base Line Inspection 03/11/03 6 N 0% A 1 - Day Follow-up Inspection 03/18/03 6 N 0% A 1 -Week recur inspection 03/25/03 6 N 0% A 1-Week recur inspection 04/01/03 6 N 0% A 1 -Week recur inspection 04/08/03 8 N 0% A 1-Week recur inspection 04/30/03 6 N 0% A Monthly Inspection Interval 05/31/03 6 N 0% A Monthly Inspection Interval 08/31/03 Quarterly Inspection Interval ConocOphillips Problem Well Supervisor P.O. Box 100360, NSK 69 Anchorage, AK 99510-0360 Phone 907-659-7224 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 February 23, 2003 Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notice variance requests for ConocoPhillips Alaska, Inc., wells 1D-127 and 3H-05. The variance request for 1D-127 is for approval to temporarily use gaslift to produce the ESP-completed well. The variance request for 3H-05 is for an extension to produce the well with a failed ESP. Attached are discussions and well schematics. Please call MJ Loveland or myself at 907-659-7224 if you have any questions. Sincerely, Jerald C. Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. RECEIVED 7 6 003 Alaska Oil & Gas Cons. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension Stimulate _ Change approved program _ Pull tubing _ Vadance _X ~'/ Perforate _ Other_ 2. Name of Operator 6. Datum elevation (DF or KB feet) ConocoPhillips Alaska, Inc. RKB 112 feet 3. Address P. O. Box 100360 Anchora~le, AK 99510-0360 4. Location of well at surface 315' FNL, 599' FEL, Sec. 23, T11N, R10E, UM At top of productive interval At effective depth At total depth 4265' FNL, 4965' FEL, Sec. 23, T11N, R10E, UM 5. Type of Well: Development __X Exploratory __ Stratigraphic _ Service._ (asp's 560491, 5959349) (asp's 556160, 5955365) 7. Unit or Property name Kuparuk River Unit West Sak Oil Pool j 8. Well number 1D-127 9. Permitnumbeyapprovalnumber 198-109" 10. APInumber 50-029-22890 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' PRODUCTION 7304' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) Size 16" 7-5/8" 7432 4026 feet Plugs (measured) feet feet Junk (measured) feet Cemented 234 sx AS II 1,2 sx AS III 385 sx class G 2.5 sx AS III LW 60 sx AS I Measured Depth 121' 7416' True vertical Depth 121' 4014' 6662-6698,6744-6770,6876-6882,6918-6932,6962-7002 3484-3508,3539-3557,3629-3633,3658-3668,3688-3716 3-1/2",9.3#,L-80Tbg @ 6614'MD. RECEIVED 2003 Alaska Oit & Gas Co~s. Coramissio~ Anchorage Packerless completion w~th no SSSV 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation Immediately on approval 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil _X Gas _ Service Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,/,~,,~('"__ ~ Title: Problem Wells Supervisor thlefs S ignedjer.{y,De FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity __ BOP Test __ Location clearance _ · M echani~call ntegrity , Test . Approved by order of the Commission ~_~-/~-~ //'~-'(~/..,-~ Commissioner Date i..~..~ Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE ConocoPhillips Alaska, Inc. West Sak Well 1D-127 SUNDRY NOTICE 10-403 VARIANCE REQUEST 2/23/03 The purpose of this Sundry Notice is for approval to temporarily gaslifi West Sak producer 1D- 127 that is completed as an ESP (electric submersible pump) well. The ESP has failed and a workover is required to pull and replace the ESP, and is expected to occur during 2004. The well makes approximately 75 bopd via ESP, a majority of which may be possible to produce on gaslift. Due to the configuration of the tubing, production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate will be 500-800 mcfd. Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 800-900 BFPD. The basic gaslifi and production facilities layout for 1D-127 will be identical to the current 1D- 110A and 1D-102 layout. ConocoPhillips has started fabrication and will install a new 3" annulus flowline on 1D-127 to replace the existing 2" flowline prior to production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design has been implemented for 1D-110A and ID- / 102 as a pro-active measure, even though there was no indication of active erosion in the 2" line that was on well 1D-110A.) Velocity calculations have been done with maximum anticipated flow rates of 1000 BLPD and total GLR of 600 scf/stb up the annulus and through the 3" annular flow line. Production pressure is approximately 230 PSIG. The maximum velocity through the NPS 3" sch 160 A333 Gr6 line will be 18 ft/s. There have been five (15) solids shakeouts on well 1 D-127 since April 2002 and they range from 0.01% to 0.24% by volume. ConocoPhillips intends to take production shakeouts both initially and periodically to monitor future performance. On the following page is a table of recent well test information. Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows, as per agreement with the AOGCC: Perform inspections weekly for the first month. Perform inspections monthly for the next two months. Perform inspections quarterly thereafter. Submit inspections on a quarterly basis to the AOGCC. As an extra safety feature, a valve handle to the IA API valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. ConocoPhillips proposes that the AOGCC approve this request for a time period not to exceed 12 months from the approval date. If a workover is not completed within that time period, the AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. ConocoPhillips Alaska, Inc. West Sak Well 1D-127 Well Test Data FORM ESP DS WELL FTP FTT SAND OIL WATER %WC GAS GOR HZ BHFP 1D 127 285 81 AB.D 74 241 76 6 81 59.9 1479 1D 127 282 81 AB.D 84 240 74 3 31 59.9 1452 1D 127 285 81 AB.D 82 241 75 14 169 59.9 1445 1D 127 277 81 AB.D 90 239 73 3 38 59.9 1426 1D 127 273 81 AB.D 103 242 70 3 30 59.9 1402 1D 127 293 81 AB.D 115 235 67 4 38 57 1425 1D 127 209 80 AB.D 3 148 98 0 143 26.8 1517 1D 127 226 82 AB.D 13 91 87 I 73 23.9 1519 1D 127 258 81 AB.D 117 224 66 15 127 51.9 1357 1D 127 250 81 AB.D 132 231 64 15 115 51.9 1348 1D 127 268 82 AB.D 147 231 61 28 192 51.9 1324 1D 127 254 83 AB.D 175 244 58 25 141 51.9 1300 1D 127 256 83 AB.D 164 234 59 21 130 48.9 1314 1D 127 247 85 AB.D 169 227 57 25 147 48.9 1320 1D 127 258 87 AB.D 168 229 58 20 121 48.9 1328 1D 127 259 86 AB.D 156 215 58 18 114 44 1337 1D 127 249 85 AB.D 169 168 50 15 87 37.9 1350 1D 127 AB.D 6 8 1 3 1D 127 237 84 AB.D 192 191 50 37 191 37.9 1313 1D 127 240 83 AB.D 232 185 44 32 139 37.9 1274 1D 127 243 83 AB.D 240 182 43 31 130 37.9 1272 1D 127 235 82 AB.D 280 161 36 36 130 37.9 1204 1D 127 217 79 AB.D 271 144 35 43 159 32.9 1233 1D 127 218 78 AB.D 281 108 28 35 125 30.9 1151 1D 127 223 77 AB.D 263 51 16 27 102 23.9 1194 1D 127 223 77 AB.D 208 107 34 25 122 23.9 1194 1D 127 220 72 AB.D 141 2 2 8 53 14.9 1372 1D 127 AB.D 1D 127 214 75 AB.D 159 67 30 18 114 15.9 1193 1D 127 189 73 AB.D 156 1 1 4 28 14.8 1326 2 KRU 1D-127 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY (0-6614, 0D:3500, ID:2.992) VtandrelNalv~ 1 (6523~524, 0D:5.390) (6570~579, OD.2 992) (6579~o616, 0D:2.313) 1D-t27 APl: 500292289000 SSSV Type: NONE Annular Fluid: 3% KCl/8.7 ppg Reference 3/7/1999 ; AEL CONDUCTOR PRODUCTION TUBING Size Top 3.500 0 Perforations Summary Interval TVD 6662-6698 3484-3508 6744-6770 3539-3557 6876-6882 3629-3633 6918-6932 3658-3668 6962-7002 3688-3716 Gas Lift Mandrels/Valves Well Type:l PROD Orig 17/8/1998 Completion:I Last W/O: 11/24/1998 Ref Lo~l Date. I TD: 7432 ftKB Max Hole An~l e: 66 des (~ 5057 Angle @ TS:I deg @ Angle @ TD:I43 deg @ 7432 I Rev Reason: Reset pump, SOV, ladd ~]auge by ImO Last Update:14/27/2002 Size Top Bottom TVD Wt Grade Thread 16.000 0 121 121 62.58 H-40 WELDED 7.625 0 7416 4014 29.70 L-80 ABM-BTC 6614 3453 EUE Zone Status Ft SPF Date Type Comment WSD 36 4 9/24/1998 IPERF 0de,,(].phasedown WSB I I26 I 4 19/22/199811PERF t0degphase, down WS A3 6 4 9/17/1998 ~ IPERF ~0 deg phased down WSA3 ~ 14 4 8/17/19981 IPERF lO deg phase, down I WSA2 t I 40 I 4 18/23/1998l IPERF 10 Deg phased, down Vlv Cmnt (6611-6616, OD:3.500) ~. 2000#psi JEWELRY Description I D BAKER SENTRY GAUGE - PUMP INTAKE 0.000 1.620 Centrilift Retrievable Pump 180ML2000 KUDU w/packoff & slipstop, set 0.000 4/2512002 SLOTTED NIPPLE 2.992 2.992 Tandem seal GSB3 DB IL H6PFS 0.000 reduction unit 9:1 525 series 0.000 0.000 HP 1315/26 KMH (6814-6615, OD:3.500) (66166629, 0D.5130) ~,ODUCTION -- (0-7416, 0D:7.625, W~29.70) Perf (6862-6898) (6744-6770) Perf (6876-6882) Per[ (6918-6932) Perf (6962-7002) 198-109-0 KUPARUK RIV U WSAK 1D-127 50- 029-22890-00 PHILLIPS ALASKA INC Roll gl: Start: Stop Roll #2: Start Stop MD 07432 TVD 04026 Completion Date: 11/24/98 Completed Status: 1-OIL Current: Name Interval Sent Received T/C/D D 8716 1,2 SPERRY MPT/GR/EWR4 OH 9/16/98 9/16/98 L DGR/EWR4-MD FINAL 121-7432 OH 9/23/98 9/23/98 L DGR/EWR4-TVD FINAL 121-4026 OH 9/23/98 9/23/98 L USIT-REPROSCET FINAL BL(C) 100-7290 CH 5 9/4/98 9/9/98 R SRVY CALC BHI 121-7432 OH 1/12/99 1/13/99 R SRVY RPT SPERRY 0-7432. OH 8/19/98 8/26/98 Tuesday, January 09, 2001 Page 1 of 1 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 8, 1999 Mr. Robert W. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-127 (Permit No. 98-109) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-127. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer AAI Drilling TWM/skad RECEIVED JA~ ~3 1999 A[aoka 0il & Gas Cons. Commission Anchorage - LASKA OIL AND GAS CONSERVATION COMMISSION ..... ..... /ED WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~] GAS E~ SUSPENDED [~ ABANDONED--] SERVICE [] '4!aska Oii& 6'35 2 Name of Operator 7 Permit Number AnCho"-'"/~' ARCO Alaska, Inc 98-109 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22890 4 Location of well at surface 9 Unit or Lease Name / '"' ~ ~i Kuparuk River Unit 316' FNL, 599' FEL, Sec. 23, T11N, R10E, UM .... ':; ':?,, At Top Producing Interval ii 4~~..~' "i~~ ~ 10 Well Number At lotal Depth 11 Field and Pool ._~ 1015' FSL, 319' FWL, Sec. 23, TllN, R10E, UM "- .;-.2. :~J~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease D~signation and Serial No. West Sak Oil Pool RKB 41', Pad 70'I ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 01-Jul-98 04-Jul-98 24-Nov-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7432' MD & 4026' 3-VD 7286' MD & 3919' TVD YES X~ NO U NA feet MD 1518' APPROX 22 Type Electric or Other Logs Run GR/Res, USIT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD ] CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.58# H-40 SURF. 121' 24" 234 sx AS II 7.625" 29.7# L-80 SURF. 7416' 9.875" 1. 225 sx ASIII LW, 385 sx Class G 2.479 sx ASIII LW, 60 sx AS I 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) I PACKER SET (MD) 3.5" 6638' *I N/A 6876'-6882' MD 3629'-3633' 'I-VD *NOTE: bottom of ESP 6962'-7002' MD 3688'-3716' 'I'VD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 6918'-6932' MD 3658'-3668' -I-VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6744'-6770' MD 3539'-3557' 'I'VD 6662'-6698', 6744'-6770', see attachments 6662'-6698' MD 3484'-3508' TVD 6876'-6882', 6918'-6932', 4 spf 6962'-7002' }ate First Production , Method of Operation (Flowing, gas lift, etc.) I 12/11/98 Gas Lift Date of Test Hours Tested PRODUCTION FO~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 12/29/98 6.00 TEST PERIOD 64 24 5 100 416 Flow Tubing Casing Pressure CALCULATED iOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 197 0 24-HOUR RATE: 248 103 21 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. "' _i- 30. "'- ~ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 6652' 3477' Base West Sak Sand 7255' 3897' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Shallow Sands Team Leader DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 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 measurements 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 cement- 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". Form 10-407 Date: 10/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-127 WELL_ID: AK9637 TYPE: AFC: AK9637 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/01/98 START COMP: RIG:RIG # 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NI/MBER: 50-029-22890-00 06/30/98 (D1) TD: 121'( 121 SUPV:DEB 07/01/98 (D2) TD: 1895' 1774 SUPV:DEB 07/02/98 TD: 4549' SUPV:DEB D3) 2654 07/03/98 (D4) TD: 7411'(2862 SUPV:DEB 07/04/98 (D5) TD: 7432'( 21 SUPV:DEB MW: 0.0 VISC: Drilling at 202' 0 PV/YP: 0/ 0 APIWL: 0.0 Move rig from 1D-126 to 1D-127. Accepted rig ~ 2300 hrs. NU diverter. MW: 9.5 VISC: 285 PV/YP: 27/45 Drilling ~ 3125' APIWL: 9.8 Function test diverter system. Had leak at diverter line knife valve. Drain riser. Pull diverter line, clean gravel out of knife valve and re-install diverter line. Fill riser, OK. Spud at 121' and drill to 201' Disc Flo pumps plugged with large gravel. Clean out 10' of fill. Drill to 246' Plugged DiscFlo pumps. Clean gravel out of pumps and lines. Drill to 260' Plugged DiscFlo pumps with gravel. Clean gravel out of pumps; lines and DiscFlo tank. Drill from 260' to 1895' MW: 9.6 VISC: 298 PV/YP: 45/49 Drilling ~ 5499' APIWL: 6.6 Drill from 1895' to 4549' MD and drilling ahead. MW: 9.6 VISC: 210 PV/YP: 43/43 RBIH after shrot trip to -3000' (TD ~ 7432') APIWL: 3.8 Drill from 4549' to 7411' MD, 4010' TVD and drilling ahead to TD ~ 7432' MW: 9.9 VISC: 195 PV/YP: 50/39 APIWL: 3.4 PJSM on running casing (started running casing ~ 0630). Drill from 7411' to 7432' MD, 4026' TVD. Circulate hole clean at 2550' Got a small amount of gravel, then mostly clay and sand. P0H to 470', no tight spots. RIH to 7432', no bridges, no fill on bottom. Date: 10/14/98 07/05/98 (D6) TD: 7432'( SUPV:DEB 0) 07/06/98 (D7) TD: 7432'( SUPV:DEB 0) 07/07/98 (D8) TD: 7432'( SUPV:MCH/MC 0) 07/08/98 (D9) TD: 7432'( SUPV:MCH/MC 0) ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 MW: 10.0 VISC: 78 PV/YP: 28/16 NU BOPE. AP IWL: 5.2 PJSM. Run 7.625" casing. Circulated 1118 bbls, 6.0 BPM to 8.5 BPM, 500 psi to 850 psi. MW: 9.4 VISC: 55 PV/YP: 13/10 POH to check bottom casing scraper APIWL: 8.8 Pump 2nd stage cement job. Wash cement out of diverter. ND diverter system. NU BOP and test to 250/2000 psi. Drill out plug and stage tool at 2993' wash down to 3062'. Clean out cement from 7161' to plug on baffle at 7292' PBTD. MW: 8.3 VISC: 28 PV/YP: 0/ 0 Rig up to circ APIW-L: 0.0 Test casing to 2000#, OK. Displace well to water. Run USIT log. Run 3.5" tubing. MW: 8.5 VISC: 28 PV/YP: 0/ 0 Release rig APIWL: 0.0 Run 3.5" tubing to 7294' Pump hogwash. Freeze protect annulus. N/D BOPE. N/U tree and test. Release rig ~ 1600 hrs. 7/8/98. Date: 12/28/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 REMEDIAL AND COMPLETION OPERATIONS WELL:iD-127 WELL ID: AK9637 TYPE: -- AFC: AK9637 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/01/98 START C0MP:11/18/98 RIG:NORDIC # 2 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22890-00 ii/18/98 TD: 0' PB: 0~ C10 ii/i9/98 TD: 0' PB: 0' ii/20/98 TD: 0' PB: 0' Cll C12 ii/2i/98 TD: 0' PB: 0' C13 11/22/98 (C14 TD: 0' PB: 0' 11/23/98 (C15 TD: 0' PB: 0' 11/24/98 (C16 TD: 0' PB: 0' DISPLACING FLUID IN HOLE MW: 8.7 BRINE SUPV:M.C. HEIM Move rig from 1D-131 to 1D-127. Accept rig @ 2400 hrs. 11/18/98. TAGGED @ 6672' = CLEANING MW: 8.7 SUPV:RICK OVERSTREET N/D tree, NU BOPE and test. POOH w/tubing. BRINE POH W/BHA #1 (MILL). MW: 8.7 BRINE SUPV:RICK OVERSTREET Mill from 6596' to 6691'. Mill and clean out from 9991' to 6816' CIRCULATING W/CLEAN FILTE MW: 8.7 SUPV:RICK OVERSTREET Continue to circ & work pipe clean out carbolite. BRINE RUNNING ESP & 3=1/2'' TUBI SUPV:RICK OVERSTREET POH w/tubing. MW: 8.7 BRINE SPLICING CABLE, LANDING H MW: 8.7 SUPV:RICK OVERSTREET RIH w/ESP completion, cable and heat trace. BRINE MW: 8.7 BRINE SUPV:M.C. HEIM Run 3.5" tubing. N/D BOPE. NU tree and test to 250/5000%, OK. Release rig @ 1800 hrs. 11/24/98. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~' K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 08/24/98 INITIAL A2 SAND PERFS 8305 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 1 NO YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 0 PSI 150 PSI 0 PSI 100 PSII 0 PSI 0 PSI DALLY SUMMARY SWS PERFED THE A2 SANDS IN 1 RUN USING SAFE WITH 2 1/8" ENERJETS, 4 SPF, BH, 0 PHASED, DOWN FROM 6982' TO 7002' W! 200 PSI WHP. MOVED TO 1D-131 TO PERF FOR FRAC.[Perf] TIME LOG ENTRY 07:30 SWS MIRU, HELD TGSM. TEST SAFE FIRE SYSTEM, NOT FIRING. 08:45 TROUBLE SHOOT SAFE SYSTEM, FOUND BAD CCL, READ GOOD BUT COULD NOT FIRE THRU IT. 10:00 ARM SAFE GUN & PT LUB TO 3000#. 10:30 MIH W/20' - 2 1/8" E J, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, 1 11/16" ROLLER, HEAD. CORR TO SWS USI LOG 7-7-98 & PERF FROM 6982' TO 7002' USING 200 PSI WHP. 12:30 POH & LD GUN, ALL SHOTS FIRED. 13:15 ABORT SECOND RUN TO PERF 1D-131 FOR FRAC. RIG DOWN. 13:45 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~4, WELL SERVICE REPORT '~' K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 08/25/98 FINISH PERFORATING A2 SANDS 8305 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-ELMORE JONES FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 100 PSI 120 PSI 100 PSI 120 PSI 0 PSII 0 PSI DALLY SUMMARY ISWS FINISHED PERFORATING A2 SANDS IN 1 RUN W/2 1/8" ENERJET, BH, 4 SPF, 0 PHASED, DOWN FROM 6962' TO 6982' USING 200 PSI WHP.[Perf] TIME LOG ENTRY 07:15 SWS MIRU, HELD TGSM. ARM SAFE GUN & PT LUB TO 3000#. 08:45 MIH W/20' - 2 1/8" E J, BH, 4 SPF, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLER, HEAD. CORR TO SWS USI LOG 7-7-98. PERF FROM 6962' TO 6982' USING 200 PSI WHP. 10:15 POH & LD GUN, ALL SHOTS FIRED. 11:00 RELEASED SWS, DID NOT HAVE TO RIG DOWN FOR THE NEXT JOB ON 1D-126. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '~' K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/10/98 PUMP "A2" FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 YESI YES DS-GALLEGOS SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 115 PSI 300 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY "A2" FRAC. PUMPED TOTAL OF 32,328 LBS OF PROP. SCREENED OUT WITH 4 PPA AT PERFS. WITH TOTAL OF 19,000 LBS PROP OUT PERFS LEAVING 13,328 LBS PROP IN PIPE.REVERSED TUBING CLEAN. AVERAGE TREATING PRESSURE 2700 PSI. MAX TUBING PRESSURE 2733 PSl.[Frac-Refrac] LOG ENTRY TIME 07:30 MIRU DS UNIT (GALLEGOS, LRS, HES, APC) TGSM EVAC PLAN AND JOB OVERVIEW. PT SURFACE LINES TO 8300 PSI. 08:00 REVERSE CIRCULATRE DIESEL UNTIL CLEAN FLUID RETURNS AT TUBING. 09:00 PUMPED SW HPBD 28 BPM 6500 TREATING PRESSURE, SD ISIP 869 PSI. 09:45 PUMPED 50# HEC DATA FRAC. 15 BPM, TREATING PRESURE 2500 PSI. TREE SAVER NOT HOLDING. 10:45 SHUT DOWN AND CHANGED TREE SAVER CUPS. FIRST SET WAS DAMAGED. 11:45 PRESSURE TEST LINES TO 8000 PSI, OK PUMPED MAIN FRAC, SCREENED OUT INTO RAMP STAGE WITH 4.5 PPA AT PERFS. MAX TREATING PRESSURE 2733 PSI. MAX ANNULAS PRESSURE 3000 PSI. 12:30 SHUT DOWN. TOTAL 32,326 LBS PROP PUMPED, 19,000 LBS IN PERFS, LEAVING 12,326 LBS IN PIPE. REVERSED OUT PROP FROM TUBING UNTIL CLEAN. 15:00 REMOVED TREE SAVER. LEAVE WELL SHUT IN FOR CTU CLEAN OUT. RDMO DS EQUIPMENT. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~, K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/13/98 2ND ATTEMPT TO FRAC "A2" SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 4 YESI YES DS-GALLEGOS SCHWENDERMAN FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 600 PSI 500 PSI 600 PSI 1100 PSII 0 PSI 0 PSI DALLY SUMMARY 2ND ATTEMPT TO FRAC "A2" SAND. PUMPED TOTAL OF 115,750 LBS PROP. WITH 114,584 LBS PROP OUT PERFS, FLUSHED LEAVING 11,066 LBS IN PIPE.[Frac-Refrac] TIME LOG ENTRY 10:00 MIRU DS FRAC UNIT (GALLEGOS,CREW,LRS,HES,APC) TGSM EVAC AREA AND JOB OVERVIEW. INSTALLED TREE SAVER. PT LINES TO 8000 PSI. 11:20 REVERSE CIRC DIESEL UNTIL RETURNS OUT TUBING WERE CLEAN. 11:50 PUMPED SW HPBD 28 BPM AT 6700 PSI TREATING PRESSURE. ISIP 823 PSI. 12:00 MADE 3 STAGE 5 BPM PULSES, 1005 PSI CLOSURE 12:48 PUMPED 50# HEC GEL DATA FRAC, 15 BPM, WITH 2700 PSI TREATING PRESSURE. FLUSH W/2% KCL SW. SD ISIP 759 PSI. 13:50 PUMPED 120 BBL, 70# HEC GEL PAD, FOLLOWED BY MAIN FRAC, PUMPING 30 BPM, 1575 PSI TREATING PRESSURE 2 PPA. REDUCED RATE TO 15 BPM ON 7 PPA HOLD STAGE, 300 PSI TREATING PRESSURE. SWITCHED TO 50# HEC GEL AND RAMPED SAND CONCENTRATION UP TO 10 PPA. FLUSHED W/SW FOLLOWED BY 30 BBL DIESEL. MAXIMUM TBG PRESS 2993 PSI. 14:45 STOPPED PUMPING. TOTAL OF 115,750 LBS PROP PUMPED, 114,584 LBS PROP OUT PERFS , LEAVING 11,066 LBS IN PIPE. REVERSE ClRC TUBING CLEAN. 16:00 RD DS. LEAVE EQUIPMENT ON LOCATION FOR NEXT STAGE FRAC. WELL LET SHUT IN FOR S/L TAG. DSO NOTIFIED. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,4, WELL SERVICE REPORT ~ K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/17/98 PERFORATE A-3 SANDS 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 7 YES YES VETROMILE JONES FIELD AFC# CC# Signed ESTI MATE AK9637 18WST F7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 100 PSI 100 PSI 100 PSI 100 PSII 0 PSII 0 PSI DALLY SUMMARY ISWS PERFORATED A3 SANDS FROM 6876' TO 6882' & 6918' TO 6932' IN 2 RUNS, W/2 1/8 EJ, 4 SPF, BH, DOWN. TAG SAND AT I 6954' = 8' ABOVE A2 SANDS.[Perf] I TIME 06:15 08:30 LOG ENTRY SWS MIRU, HELD TGSM (SPILLS). MU SAFE GUN & PT LUB 3000# MIH W/14' - 2 1/8" EJ, 4 SPF, BH, 0 PHASED DOWN, SAFE, MPD, CCL, 2 WB. CORR TO SWS USl LOG 7-7-98. TAG SAND @ 6954' = 8' OF SAND ABOVE TOP OF A2 PERFS. PERFED FROM 6918' TO 6932'. 10:15 POH & LD GUN, ALL SHOTS FIRED. 11:30 MU & MIH W/6' - 2 1/8 EJ GUN AS ABOVE. CORR TO ABOVE LOG & PERF FROM 6876' TO 6882'. 13:00 POH LD GUN, ALL SHOTS FIRED. 13:45 REL RIG, (DIDN% NEED TO RIG DOWN FOR NEXT WELL) ARCO Alaska. Inc. · "--J KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ,~ K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/18/98 A3 FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 8 YES YES DS-GALLEGOS R IGGS FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTFTSC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann Final Outer Ann 330 PSI 600 PSI 357 PSI 600 PSII 0 PSI 0 PSI DAILY SUMMARY [Frac-Refrac]PUMPED FRAC PER PROCEDURE W 50 # HEC GEL AND 16/20 PROPANT W PROP LOC @ AN AVG. RATE OF 15 BPM AND 2700 PSI. SCREENED OUT 110 BBL INTO THE 7 PPG HOLD STAGE. PUMPED A TOTAL OF 61,882 LBS PROP W/ 45,353 LBS. OF 7 PPG TO PERFS. REVERSED OUT PROPLOC FROM TUBING W DIESEL TILL CLEAN. EXPECT TAG AT TUBING TAIL 6600'. BHP 1667PSl TIME LOG ENTRY 08:00 MIRU ,TGSM, PT. LINES TO 8000 PSI. 21 PEOPLE ON LOCATION. 09:20 PUMPED THE BREAKDOWN STAGE 150 BBL WATER @ 30 BPM AND 5800 LBS. CHANGED TO 50 # HEC GEL PUMPED 80 BBL @ 30 BPM AND 4198 PSI. SHUT DOWN AND GOT ISIP OF 1450 PSI PULSETEST @ 75 PSI DROP. 10:06 PUMPED STAGE 4 AND 5 OF THE DATA FRAC. 19 BBL 50 # HEC GEL @ 15 BPM AND2950 PSI FOLLOW W/86 BBL WATER @ 15 BPM AND 2490 PSI. SHUD DOWN ISIP OF 1308 PSI. PULSE TESTS. 11:55 PUMP STAGES 6 - 10 W 50 # HEC GEL @ 15 BPM AND 2888 PSI. FLUSH WITH 131 BBL WATER @ 15 BPM AND 2614 PSI. SHUT DOWN IN STEPS GOT ISIP 1212 PSI. 13:30 PUMP PAD AND MAIN FRAC. W/50# HEC GEL. @ 15 BPM AND 2646 PSI. W 100 BBL PAD 50# HEC GEL THEN RAMP FROM 2 PPG TO 7 PPG16 / 20 PROPANTWPROPLOC@ 15 BPM AND 2800 PSI. 14:25 SCREENED OUT 110 BBL INTO THE INTO THE 7 PPG HOLD STAGE. PUMPED 61,882 LBS OF PROPANT W/ 45,353 LBS OF 7PPG AT THE PERFS. REVERSED OUT PROP AND GEL FROM THE TUBING W/DIESEL TILL CLEAN EXPECT FILL NEAR THE TUBING TAIL 6600', BHP 1662 PSI 15:00 RDMO DS ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT ,, K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/22/98 PERFORATE B SANDS 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 11 YESI YES SWS-VETROMI LE JON ES FIELD AFC# CC# Signed EST I MAT E AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 400 PSI 310 PSI 380 PSI 290 PSII 0 PSII 0 PSI DAILY SUMMARY ISWS PERFORATED B SANDS FROM 6744' TO 6770' W/2 1/8" E J, 4 SPF, BH, 0 PHASED, DOWN. TAGGED SAND @ 6800' = 76' ABOVE A3 TOP PERF.[Perf] TIME 18:15 18:45 LOG ENTRY HELD TGSM, MU SAFE GUN & PT LUB 3000#. (NO RIG UP NEEDED FROM PRIOR JOB) MIH W/26' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLER, WB, ROLLER. CORR TO SWS USl LOG 7-7-98. PERFED B SANDS FROM 6744' TO 6770'. TAGGED SAND @ 6800' = 76' ABOVE A3 SAND TOP PERF. 20:00 POH & LD GUN, ALL SHOTS FIRED. 21:00 RIG DOWN. 21:45 RELEASED SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~, WELL SERVICE REPORT '~ K1(1D-127(W4-6)) -. WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/23/98 FRAC B-SAND DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 12 YESI YES DS-GALLEG OS LIG ENZA FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC InitialTbgPress FinalTbgPress Initial lnner Ann Final lnner Ann IlnitialOuterAnn IFinaIOuterAnn 393PSI 600PSI 378PSl 600PSIIIOPSI OPSI DAILY SUMMARY FRAC B-SAND. PUMPED TOTAL 64,526 LBS OF PROP. SCREENED OUT WITH 4.5 PPA AT THE PERFS W/A TOTAL OF 45,750 LBS OF PROP OUT THE PERFS LEAVING 12,179 LBS IN PIPE. REVERSED TUBING CLEAN. AVERAGE TREATING PRESSURE 4065 PSI. MAX TUBING PRESSURE 6495 PSl.[Frac-Refracl TIME LOG ENTRY 08:00 MIRU, TGSM, PT. LINES TO 8000 PSI, 17 PEOPLE ON LOCATION 10:05 PUMPED THE BREAKDOWN STAGE 150 BBLS OF WATER @ 30 BPM AND 6200 PSI.PULSE TESTS AT 100 PSI DROP. 10:55 PUMPED SCOUR STAGES 6-9 W/50# HEC GEL @ 15 BPM 140 BBLS. 2800 PSI. PUMPED DISPACEMENT STAGE 3, 71 BBLS OF 50# HEC GEL. 2550 PSI. PULSE TESTS. 12:15 PUMPED DATA FRAC STAGES 4 & 5.29 BBLS OF 50# HEC GEL & 76 BBLS OF WATER. PULSE TEST. ISIP 1288 PSI. 03:00 PUMPED 130 BBL 50# HEC PAD. FIRST 70 BBLS @ 5 BPM THEN TO 15 BPM. STARTED PUMPING MAIN FRAC & WENT TO FLUSH DURING STAGE 2 DUE TO NOLTE SMITH NET PRESSURE READING FAILURE. PUMPED 10,220 # OF PROPPANT, 110 BBLS OF HEC GEL. FLUSHED WITH 130 BBLS OF WATER. REPAIRED METER. 04:43 PUMPED 110 BBL PAD 50# HEC GEL, FIRST 71 BBLS @ 5 BPM REMAINDER AT 15 BPM. PUMPED MAIN FRAC @ 15 BPM 65 BBLS AT 2850 PSI, 2 PPA. 182 BBLS @ 4.5 PPA 2900 PSI. WENT TO 8.5 PPA STAGE @ 3050 PSI. 05:25 SCREENED OUT AFTER 17 BBLS INTO THE 10 PPA STAGE. PUMPED TOTAL OF 64,526# OF PROPPANT W/ PROP LOK. 45,750 # AT THE PERFS. REVERSED OUT PROP AND GEL FROM THE TUBING W/DIESELTILL CLEAN. EXPECT FILL NEAR THE TUBING TAIL @ 6600'. BHP 1662 PSI. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/24/98 PERFORATE D SANDS 2128 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 13 YES YES SWS-VETROMILE JONES FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann , Final Outer Ann 350 PSI 360 PSI 330 PSI 330 PSII 10 PSI 0 PSI DALLY SUMMARY SWS PERFORATED D SANDS IN 2 RUNS FROM 6662' TO 6698' W/2 1/8" E J, 4 SPF, BH, 0 PHASED, DOWN. TAGGED SAND 6725' = 19' ABOVE B SAND TOP PERF.[Perf] LOG ENTRY TIME 15:15 SWS MIRU, HELD TGSM. MU SAFE GUN. PT LUBTO 3000#. 16:45 MIH W/18' - 2 1/8" ENERJET, 4 SPF, BH, 0 PHASED, DOWN, SAFE, MPD, CCL, WB, ROLLER, WB, ROLLER. CORR TO SWS USl LOG 7-7-98. PERFED D SANDS FROM 6680' TO 6698'. 18:00 POH & LD GUN, ALL SHOTS FIRED. 18:45 MU & MIH W/18'- 2 1/8" ENERJET GUN AS ABOVE, CORR TO ABOVE LOG & PERF D SANDS FROM 6662' TO 6680'. TAGGED SAND @ 6725' = 19' ABOVE TOP OF B SAND PERFS. 20:00 POH & LD GUN, ALL SHOTS FIRED. 20:30 RIG DOWN. 21:00 RELEASE SWS. ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~, K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/25/98 PUMP D-SAND FRAC (DATA FRAC) DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 14 NOI YES DS-GALLEGOS LIGENZA 'FI ELD AFC# CC# Signed ESTI MATE AK9637 18WSTF7 SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann J Final Outer Ann 302 PSI 730 PSI 348 PSI 730 PSI 0 PSIJ 0 PSI DAILY SUMMARY PUMPED D-SAND DATA FRAC. BREAKDOWN 150 BLS OF WATER AT 30 BPM. AVERAGE TREATING PRESSURE 6250 PSI. SCOUR STAGES @ 15 BPM. 50 BBLS 50# HEC GEL, 30 BBLS 50# HEC GEL W/1 PPA PROPPANT, 30 BBLS 50# HEC GEL W/2 PPA PROPPANT. TOTAL OF 3257 LBS OF PROPPANT PUMPED. 97 BBLS OF 50# HEC GEL. PUMP 3- 1BBL PULSES. AVERAGE TREATING PRESSURE 2300 PSI.PUMP DATA FRAC @ 15 BPM. 33 BBLS OF 50# HEC GEL, 97 BBLS OF WATER. REVERSE OUT TUBING W/74 BBLS OF DIESEL. DOWELL COSTS WILL BE ADDED WHEN FRAC IS COMPLETE. TIME LOG ENTRY 12:30 MIRU, TGSM, PT 8200 PSI. REVERSE OUT 65 BBLS OF DIESEL.. 02:45 PUMP BREAKDOWN 150 BBLS OF WATER AT 30 BPM. AVERAGE TREATING PRESSURE 6250 PSI. INITIAL ISIP =1009 PSI. PUMPED 5 PULSE'S 1 BBL EACH. 03:00 PUMP SCOUR STAGES @ 15 BPM. 50 BBLS 50# HEC GEL, 30 BBLS 50# HEC GEL W/1 PPA PROPPANT, 30 BBLS 50# HEC GEL W/2 PPA PROPPANT. TOTAL OF 3257 LBS OF PROPPANT PUMPED. 97 BBLS OF 50# HEC GEL. PUMP 3- 1BBL PULSES. AVERAGE TREATING PRESSURE 2300 PSI. 03:45 PUMP DATA FRAC @ 15 BPM. 33 BBLS OF 50# HEC GEL, 97 BBLS OF WATER. PUMPED 3 - 1 BBL PULSES. FINAL CLOSURE PRESSURE 1130 PSI. 05:00 REVERSE OUT TUBING WITH 74 BBLS OF DIESEL. 05:30 RDMO DOWELL. ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1(1D-127(W4-6)) WELL JOB SCOPE JOB NUMBER · 1 D-127 FRAC, FRAC SUPPORT 0822980835.3 DATE DAILY WORK UNIT NUMBER 09/27/98 PUMP D SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 15 YESI YES DS-GALLEGOS LIGENZA FIELD AFC# CC# Signed ESTIMATE AK9637 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 340 PSI 890 PSI 337 PSI 1084 PSI 0 PSII 0 PSI DAILY SUMMARY FRAC D- SAND. PUMPED 60 BBLS 50# HEC AT 5 BPM, 110 BBLS AT 15 BBM. 80 BBLS OF 2# PPA @ 15 BPM, 300 BBLS 2-7# PPA @ 15 BPM, 75 BBLS 7# PPA @ 15 BPM, 75 BBLS 7# PPA @ 10 BPM, 15 BBLS 7-10# PPA @ 10 BPM. 30 BBLS 10# PPA @ 10 BPM. FLUSH 30 BBLS 50# HEC GEL @ 10 BPM. 30 BBLS DIESEL @ 10 BPM. MAXIMUM TREATING PRESSURE 2720 PSI. TOTAL OF 96,961 LBS OF 16/20 PROPPANT, 96,903 LBS TO PERFS. REVERSED OUT TUBING W/70 BBLS OF DIESEL. SHOULD BE CLEAN OF PROPPANT TO BELOW TUBING TAIL. AVERAGE TREATING PRESSURE= 2438 PSI. MAXIMUM TREATING PRESSU RE= 6537[Frac-Refrac] TIME LOG ENTRY 06:00 MIRU, TGSM, PT TO 8100 PSI. 17 PEOPLE ON LOCATION. 08:43 PUMP MAIN FRAC 60 BBLS 50# HEC GEL AT 5 BPM, 110 BBLS AT 15 BBM. 80 BBLS OF 50# HEC GEL 2 PPA @ 15 BPM, 300 BBLS 2-7# PPA @ 15 BPM, 75 BBLS 7# PPA @ 15 BPM, 75 BBLS 7# PPA @ 10 BPM, 15 BBLS 7-10# PPA @ 10 BPM. 30 BBLS 10# PPA @ 10 BPM. FLUSH 30 BBLS 50#. HEC GEL @ 10 BPM. 30 BBLS DIESEL @ 10 BPM. MAXIMUM TREATING PRESSURE 2720 PSI. MAXIMUM TREATING PRESSURE 2720 PSI. 10:10 REVERSE OUT TUBING W/70 BBLS OF DIESEL. 10:30 RDMO DOWELL. I'IF., SURVEY CALCULATION AND FIELD WORKSHEET Job No. _04.._5_O-__98_48_4' .... Sidetrack No. Page __1__.. of _.2 I:[I.r~:l~,-t Company ..A_R_C__O_._A._L~___S._KA_,!N._C: ...................................... Rig Contractor & No. _PA_R_.K__E_R_;_24_~5 ............. Field KUPARUK RIVER UNIT / / Well Name & No. 1D-PAD/1D#127/L1 Survey Section Name SPERRY SUN BHI Rep. ~~ WELL DATA Target TVD .............. (FT) Target Coord. N/S Slot Coord. N/S ...... _- 31__6 .___~. ...... Grid Correction 0.000 Depths Measured From: RKB ~ JVISL [~ SS~ Target Description ................... Target Coord. E/W Slot Coord. E/W -599.00 Magn. Declination 27.460 Calculation Method MINIMUM CURVATURE Target Direction ........... (Do) Build\Walk\DL per: 100ft~ 30mi.'.~ 10mi~ Vert. Sec. Azim. 227.89 Magn. to Map Corr. 27.460 Map North to: OTHER SURVEY DATA ................. ~ ........... ~ ....................... , Coordinate Build Rate Walk Rate - ~ i Survey Incl. I Hole =Course Vertical ..... Date _Tool ,, Depth Angle I Direction ', Length TVD | Section N(+) IS(-) I -~-~-~--~--~- DL Build (+) Right (+) Comment ................ I /ype ! (FT) (DD) J .... (_D_D_) ....... ~___(F'r) (FT)__qL_ (FT)J '(FT')-- !(Per ~00~[ Drop (-) I Left (-) ! ....... ............. _o.o_oi o.oo4,___ o.oo, ............... o.oo ' MWD , -0.~0 .... ~.(~(~ ......... ~-~-.- iT- .......... 8.MACH 1C-AKO-1.6 DEG. . 01-JUL-g8 MWDI 121.00 0.00 270.00i 121.00 121.00 ' 0.00 -',.,.,,~,"-~; 01-JUL-98! ............... i ..............~,' -- 307.08 . -0.87 1.89 1.89 ................ -~ ........................... ~ ................................... 01-JUL-98 i MWDi 290.42 I 4.00 ~L~)'i~'~ --87.97 290.30 2.50 1.66 i -4.87 3.19/ 2.80 ................. ............ ~ ............................................... ........ ~. ........... 01-JUL-98 MWDi 381.53 ~ 8.64 ~ 261.69 91.11 380.84 10.35 0.96 ', -14.81 5.32| 5.0g -14.g4 .......... t ........... ~ .............. --~ ..... F .......................... f ..............~-~ ............ 01-JUL-981 MWD', 471.38t 14.101 252.77 89.85 468.90 25.90 -~-~--. , -~';--~-~-. ~;~. . ;~-(;~--. -9.g3 O~-~U~-~~i ~W~ '~ ~'~ t ~.~ ~.~.~0 i ~.~0 ~Z.~ ~.~0 '~'ZZ i ............ -~.~ .... ~..~ ............. ~.~0 -~.0~ ....................... ~ ................................................ -] 1- ......... ----:~i-~.~ ' ' -i ' '~'1-~4 ~ ~'2~-1 ~- ............... ........................................... ....................... ~ ................. : ................... ~._ ..... ~- .................. ~, ........................ .. ..................................... -~ ....................... ~_ ......................................................................... 01-JUL-98 I MWD :; 744.56 i 34.67 [ 233.07 t 91.23 715.21 137.30 -60.06 i -130.79 6.62 ! 6.20 i -4.37 01-JUL-98i~ MWDi 834.77__ ~ i 40.61 ! 231.01 90.21 786,62 192.23 -93.98 ! -174.16 6.73i 6.58 i -2.28 ~ ...... ...... ....... - .... ............ ...... ............... ............. 01-JUL-98 MWDI 1013.26! 54.101 229.00 i 89.00 907.41 . 322.99 -178.47 -274.07 7.73/ 7.71 I -0.74 1 .............................. i ..................... ~ .............. i ............ I~ ----~ ................................. L-- ................................................................ 01-JUL-98 MWD} 1104.57| 56.991 229.11 i 91.31 959.07 ~ 398.26 -227.81 ~ -330.93 3.17 3.17 ~, 0.12 ] ........................... ~ ...................... J .......................... ~ .......... / ............. L ........................................................... ~_ 01-JUL-98 MWD I 1194.80 | 61.25 227.86 90.23 1005.37 ~ 475.68 -279.14 / -388.89 4.87 4.72 t -1.39 ............ il. ' ....... .................................................................... t__ . ..................... 01 -J U L-98 MWD 1468.66 63.40 227.84 273.86 1132.56 718.19 -441.88 -568.69 0.79 0.79 -0.01 ............. 01 -JUL-98 MWD 1745.76 64.24 229.80 277.10 1254.82 966.81 -605.59 -755.84 0.70 0.30 0.71 ......... .... 01-JUL-98 MWD 1840.31 62.72 227.81 94.55 1297.04 1051.39 -661.30 -819.50 2.48 -1.61 -2.10 ....... 02-JUL-98 MWD 2125.22 63.26 227.74 284.91 1426.43 1305.23 -831.88 -1007.47 O. 19 O. 19 -0.02 02-J U L-98 MWD 2408.55 64.70 228.67 283.33 1550.72 1559.82 -1001.56 -1197.29 0.59 0.51 0.33 .,, , , 02-JUL-98 MWD 2503.66 64.10 227.03 95.11 1591.82 1645.59 -1059.11 -1260.88 1.68 -0.63 -1.72 02-J UL-98 MWD 2598.59 62.36 226.67 94.93 1634.57 1730.33 -1117.08 -1322.72 1.86 -1.83 ~0.38 02-JUL-98 MWD 2883.39 63.71 227.34 284.80 1763.71 1984.13 -1290.16 -1508.38 0.52 0.47 0.24 .., 02-JUL-98 MWD 3165.08 64.58 227.36 281.69 1886.56 2237.61 -1461.91 -1694.82 0.31 0.31 i~, 0.01 02-JUL-98 MWD 3260.03 62.62 226.37 94.95 1928.77 2322.64 -1520.05 -1756.88 2.27 -2.06 -1.04 SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0_.4_.5(?_9~484 Sidetrack No.__ .... Page .... .2_ ..... of __2 Company ~A.R__C_ .O_A_L~,__s_~_K,~_,_I.NC: ...................................... Rig Contractor & No. PARKER- 245 ................................... Field KUPARUK RIVER UNIT Well Name & No. 1D-PAD/1D#127/L1 ......................................... Survey Section Name SPERRY SUN BHI Rep. ~l~r~l~ WELL DATA Target TVD __ (FT) Target Coord. N/S ................... Slot Coord. N/S -316.00 Grid Correction 0.000 Depths Measured From: RKB ~[, MSL [] SS[.-_, Target Description ............................. Target Coord. E/W ...................... Slot Coord. E/W -5,99.00 Magn. Declination __.2_7_:4_60_ ...... Calculation Method MINIMUM CURVATURE Target Direction ................... !O_DJ_ ....... Build~Walk\DL per: lOOfti~ 30m['ii, l Om!! Vert. Sec. Azim. 227.89 Magn. to Map Corr. _ ..... _2_7.4_6.0 ..... Map North to: .OT_.H_ER SURVEY DATA ................. T'-----'y! Survey Incl. Hole ~ Course I' Vertical Total Coordinate Build Rate ,! Walk Rate i Surve---i r ........... ]- ........................ T- ...................... .................. ! Date Tool I Build (+) Right (+)I Comment ~ Type Depth Angle Direction Length TVD [ Section N(+) / S(-) E(+)/W(-) DL ..............~ (FT)___ (DD) (D_D) (ET) (FT) T' (ET) (Fr) (Pe, ~00 F'r) Drop (-) _._~ .... _/_.eff__?)___~ ----.-----~-----02'JUL-98 [ MWD' 3544.74 63.17 227.46 284.71 2058.50 i 2576.04 -1693.16 -1941.98 0.39 0.19i 0.38 8"MACHIC-AKO-1.6DEG. . 02'JUL'98/MWD 3824.00 63.83 227.651 279.26 2183.10 i 2825.95 -1861.83 -2126.40 0.24 0.24 0.07 02-JUL-98 i MWO 4014.24 "g2.07 229'1'0! 190.24 2269.62 I 2995.36 -1974.37 -2253.03 1.15 -0.93~ ! ........ -0~-76 ! 1 ................. .; ......................................... 4 ........................................... ~ ................... , ............................................. 02-JUL-98 i MWD! 4197.85 ~ 65.30 227.50 183.61 2351,01l, 3159.91 ; -2083.86 -2375.87 1.92 1.76 -0.87 1 -~:JUL-9~ I '-Mwo 4393 65 65 62 226 95 195.80 2432.331 3338 01 -2204.82 -2506.61 0.30 0.16 -0 28 .............. .[ ...............-~ l .................................................................................................................... ~~ 03-JUL-98i MWD/ 46751316354 22675 281.48 255315 I 359218 -237868{ -269208 074 .0741 -007 ]8"MACH1C-AKO-14DEG .......... ? ...... ! ..................... d- ............................. ~ ............................ ~ ...... ~ ......................... 03-JUL-98i MWD~_~ 4771.73:64.54 225.66~ 96.60 2595.43 { 3679.00 -2438.79ff~__~_ -2754.77 1.45 1.04 :~ -1.131 03-JUL-98 ~ MWD! 5056.90 65.64 225.09 t 285.17 2715.54 ; 3937.38 -2620.,+ot -2938.84 0.43 0.39 i -0.20 '~;"~1L~['98 i "i~)-~'-~~~-6- ...... ~'~'3-- ...... ~.29-~, -~-i~ ..... ~8-;i~'~-'i ...... ;-i--;~;'~-4 ..... -2802 55 3122 12 0 77 0 77 0 07 ................................................................................. +- ' --'d, ................................................................. : 03-JUL-98I MWD 5625.80 64.18 224.25 ~ 282.74 2963.381; 4448.76 -2982.66I -3300.78 0.42,. 0.27 i.~ -0.37 ' 03-JUL-gal MWD 5909.95 64.34 225.31, 284.15 '3~)~[~9'"] ....... ~4~,'/3-~ .......... [~-1-a.34 -3481.07 0.34 0.06{ 0.37i ......................... + ............................ _' ~ 0.35 03-JUL-98 i MWD 6099.43 64.96 225.98 189.48 3167.92 I 4875.43 -3284.05 -3603.51 O.46 O.33 03-JUL-98 ~ MWD 6289.82 57.94 227.35 94.07 3257.40 5043.28 -3399.88 -3725.06 4.87 -4.74 J 1.30' ....................J~ - .................................................................. [ ......................................................................................................... 03-JUL-98 MWD 6384.53 53.98 228.54 94.71 3310.41 i 5121.74 -3452.45 -3783.31 4.31 -4.18 i 1.26 _ -- ...................................................................................................................... 03-JUL-98 MWD 6477.23 52.03 228.75 92.70 3366.19 5195.77 -3501.37 -3838.88 2.11 -2.10 0.23 03-JUL-98 MWD 6571.86 50.57 228.62 94.63 3425.35 5269.61 -3550.13 -3894.35 1.55 -1.54 -0.14 ............................................................. 03-JUL-98 MWD 6667.75 48.39 229.72 95.89 3487.65 5342.48 -3597.79 -3949.49 2.43 -2.27 1,15 .. 03-JUL-98 MWD 6857.66 46.73 229.45 189.91 3615.80 5482.57 -3688.65 -4056.20 0.88 -0.87 -0.14 03-JUL-98 MWD 7044.90 45.07 230.02 187.24 3746.10 5616.96 -3775.55 -4158.79 0.91 -0.89 0.30 03-JUL-98 MWD 7237.80 43.63 229.42 192.90 3884.04 5751.73 -3862.72 -4261.66 0.78 -0.75 -0.31 .._ 04-JUL-98 MWD 7364.08 42.72 229.37 126.28 3976.13 5838.10 -3918,96 -4327.26 0.72 -0.72 -0.04 PROJECTED TO TD ~,: .__. , I i i ri FI I I__1__ I I~1 G SEFI~Ir'G S 19-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 1 D-127 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 7,432.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AU(; 2 6 1998 AJaska 0ii & Gas Cons. ~mnlissi0n Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. Kuparuk Unit Kuparuk ID 1D-127 SURVEY REPORT 18 August, 1998 Your Ref: API-500292289000 Last Survey Date 04-July-98 Job# A KMM80272 KBE- ~1~.80' ORIGINAL sp,=:,r-,r',~-sum DRILLING SERVIr'Ec; Survey Ref: svy44 Sperry-Sun Drilling Services Survey Report for 1D-127 Your Ref: API-500292289000 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (~) (~) 0.00 0.000 0.000 -111,80 0.00 121.00 0.000 0.000 9.20 121.00 202.45 1.540 307.080 90.64 202.44 290.42 4.000 275.300 178.50 290.30 381.53 8.640 261.690 269.04 380.84 471.38 14.100 252.770 357.10 468.90 564.18 21,620 245.300 445.38 557,18 653.33 29.010 237.060 525,93 637.73 744.56 34.670 233.070 603.41 715,21 834,77 40.610 231.010 674.82 786.62 924.26 47.240 229.660 739.24 851.04 1013.26 54.100 229.000 795.61 907.41 1104.57 56.990 229.110 847.27 959.07 1194.80 61.250 227.860 893.57 1005.37 1468.66 63.400 227.840 1020.76 1132.56 1745.76 64.240 229.800 1143,02 1254,82 1840.31 62.720 227.810 1185.24 1297.04 2125.22 63.260 227,740 1314.63 1426.43 2408.55 64.700 228.670 1438,92 1550.72 2503,66 64.100 227.030 1480.02 1591.82 2598.59 62,360 226.670 1522.77 1634.57 2883.39 63.710 227.34"0-- 1651.91 1763.71 3165.08 64.580 227.360 1774.76 1886.56 3260.03 62.620 226.370 1816.97 1928.77 3544.74 63.170 227.460 1946.70 2058.50 3824.00 63.830 227.650 2071.30 2183.10 4014.24 62.070 229.100 2157.82 2269.62 4197.85 65.300 227.500 2239.20 2351.00 4393.65 65.620 226.950 2320.53 2432.33 4675.13 63.540 226.750 2441.34 2553.14 Local Coordinates Northings 0.00 N 0.00 N 0.66 N 1.66 N 0.96 N 3.26 S 13.77 S 32.42 S 60.06 S 93.98 S 133,62 S 178.47 S 227.81S 279.14 S 441.88 S 605.59 S 661.30 S 831.88 S 1001.56 S 1059.11S 1117.08 S 1290.16 S 1461.91S 1520.05 S 1693.16 S 1861.83 S 1974.37 S 2083.86 S 2204.82 S 2378.68 S Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (~) (°/100~) (~) 0.00 E 5959348.96 N 560490,67 E 0.00 0,00 E 5959348.96 N 560490.67 E 0.000 0.00 0.87W 5959349.61N 560489.79 E 1.891 0.21 4,87W 5959350.58 N 560485.78 E 3.195 2.50 14.81W 5959349.80 N 560475.85 E 5.317 10.35 31.96W 5959345.44 N 560458.74 E 6.367 25.90 58.33W 5959334,72 N 560432.45 E 8,455 52.50 91.45W 5959315.81N 560399.49 E 9.165 89.58 130.79W 5959287.85 N 560360.37 E 6.616 137.30 174.16W 5959253.58 N 560317.27 E 6,730 192.23 221.89W 5959213.56 N 560269.86 E 7,482 254.21 274.07W 5959168.29 N 560218.05 E 7.729 322.99 330.93W 5959118.50 N 560161.58 E 3.167 398.26 388.89W 5959066.70 N 560104.04 E 4.869 475.68 568.69W 5958902.52 N 559925.56 E 0.785 718.19 755.84W 5958737.31 N 559739.72 E 0,703 966.81 819.50W 5958681.09 N 559676.51E 2.476 1051.39 1007.47W 5958508.99 N 559489.93 E 0,191 1305.23 1197.29W 5958337.80 N 559301.48 E 0.588 1559.82 1260,88W 5958279,73 N 559238.35 E 1.678 1645.59 1322.72W 5958221.27 N 559176.99 E 1.864 1730.33 1508.38W 5958046.70 N 558992.73 E 0.518 1984.13 1694.82W 5957873.46 N 558807.67 E 0.309 2237.61 1756.89W 5957814.82 N 558746.08 E 2,266 2322.64 1941.98W 5957640.22 N 558562.38 E 0.392 2576.04 2126.40W 5957470.08 N 558379.32 E 0.244 2825.95 2253.03W 5957356.51 N 558253.60 E 1.147 2995.36 2375.87W 5957246.04N 558131.65 E 1.925 3159.91 2506.61W 5957124.03 N 558001.89 E 0.303 3338.01 2692.08W 5956948.69 N 557817.82 E 0,742 3592.18 Comment Kuparuk 1D Continued... 18 August, 1998 - '13:08 - 2 - DrillOuest Sperry-Sun Drilling Services Survey Report for '/D-'/27 Your Ref: API-500292289000 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (fi) (~) (fi) 4771.73 64.540 225.660 2483.63 2595.43 2438.79 S 5056.90 65.640 225.090 2603.74 2715.54 2620.48S 5343.06 63.430 225.290 2726.77 2838.57 2802.55S 5625.80 64.180 224.250 2851.58 2963.38 2982.66 S 5909.95 64.340 225,310 2974.99 3086.79 3164.34S 6099.43 64.960 225,980 3056.11 3167.91 3284.05 S 6195.72 62.400 226.130 3098.80 3210.60 3343.94 S 6289.82 57.940 227.350 3145.60 3257.40 3399.88 S 6384.53 53,980 228.540 3198.61 3310.41 3452.45 S 6477.23 52.030 228.750 3254.39 3366.19 3501.37 S 6571.86 50,570 228.620 3313.55 3425.35 3550.12 S 6667.75 48.390 229.720 3375.85 3487.65 3597.79 S 6857.66 46.730 229.450 3504.00 3615.80 3688.64 S 7044.90 45.070 230.020 3634.30 3746.10 3775.55 S 7237.80 43.630 229.420 3772.24 3884.04 3862.72 S 7364.08 42.720 229.370 3864.33 3976.13 3918.96 S 7432.00 42,720 229.370 3914.23 4026.03 3948.96 S Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100fi) (fi) 2754.77W 5956888.07 N 557755.62 E 1.449 3679.00 2938.84W 5956704.91N 557573.02 E 0.426 3937.38 3122.12W 5956521.37 N 557391.21E 0.775 4195.44 3300.78W 5956339.82 N 557214.01E 0,423 4448.76 3481.07W 5956156.70 N 557035.18 E 0.341 4704.33 3603.51W 5956036.01N 556913.72 E 0.457 4875.43 3665.64W 5955975.62 N 556852.06 E 2.662 4961.69 3725.06W 5955919.21 N 556793.10 E 4.871 5043.28 3783.31W 5955866.17 N 556735.28 E 4.309 5121.74 3838.88W 5955816.80 N 556680.10 E 2.111 5195.77 3894.35W 5955767.60 N 556625.03 E 1,547 5269.61 3949.49W 5955719.50 N 556570.27 E 2.435 5342.48 4056.20W 5955627.79 N 556464.30 E 0.880 5482.57 4158.79W 5955540.05 N 556362.41 E 0.913 5616.95 4261.66W 5955452.06 N 556260.24 E 0.778 5751.72 4327.26W 5955395.30 N 556195.09 E 0.721 5838.10 4362.23W 5955365.01N 556160.37 E 0.000 5884.16 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 227.890° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7432.00ft., The Bottom Hole Displacement is 5884.16ft., in the Direction of 227.847° (True). Comment Projected Survey Kuparuk 1D Continued... 18 August, 1998 - 13:08 - 3 - DrillQuest Sperry. Sun Drilling Services Survey Report for 1D-127 Your Ref: API-500292289000 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 7432.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0,00 E 4026.03 3948.96 S 4362.23 W Comment Tie-on Survey Projected Survey 18 August, 1998 - 13:08 - 4 - DrillQuest 0 I~11 I_1_ I ~ I~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 23, 1998 ~,: ~VD Formation Evaluation Logs 1D-127, AK-MM-80272 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~3, Anchorage, AK 99518 1D-127: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22890-00 2" x 5" TVD Resistivity & Gamma Ray Lbgs: 50-029-22890-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries. Inc. Comoanv WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs Septernber 16, 1998 1D-127, AK-MM-80272 1 LDWG formatted Disc with verification listing. API#: 50-029-22890-00 PI,EASE ACKNOWLEDGE RECEllYr BY SIGNING AND RETURNING THE ATrACltED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 9~5 Date: -~cF ~" '':~$ -' -~'- ..... ,. f, .., ^' ".-.e.,' 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Dresser Industries. Inc. Comnanv 9/4/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11476 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: West Sak (Reservoir Analysis Logs) ,,, Well Job # Log Description Date Color RF Sepia Floppy Print ....... . Disk . WS 1D-126 ¥-~ IC>~ 98373 REPROCESSEDUSIT 980629 WS 1D-127 O~--IL~C~ 98373 REPROCESSEDUSlT 980707 / 1i/ WS 1 D-131 ~ ~- I ~ © 9 a 373 REPROCESSED USIT 980714- ~ .1 ,,~"'" ,. SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. . ,: TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19. 1998 Thomas W. McKav Shallow Sands Team Leader ARCO Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit ID-127 ARCO Alaska, Inc. Permit No 98-109 Sur. Loc.: 316'FNL. 599'FEL. SEC. 23. TI IN. R10E. UM Btmholc Loc: 992'FSL, 292'FWL, SEC. 23. TI 1N. R10E. UM Dear Mr. McKav. Enclosed is thc approved application for permit to drill thc abovc referenced wcll. Thc pcrmit to drill docs not cxcmpt you from obtaining additional permits required bx' law from other govcrnmcntal agencies, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Bloxvout prevention equipment (BOPE) must bo tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE tcst performed before drilling below the surface casing shoc must bc givcn so that a rcprcscntativc of thc Commission ma-,' xvitncss the test. Notice may bc given by contacting thc Colnmission pctrolcum field inspcctor on the North Slope pagcr at 659-3607. David W. Johnston Chairman '~ BY ORDER OF THE COMMISSION dlf ench~sures l)epartmcnt et' Fish & (}amc. tlabitat Section w,o cncl. l)¢partment ot' Environmental Conservation w,-o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PEP, B/lIT TO DP,ILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory J--J StratigraphicTest FJ Development Oil X Re-Entry Deepen Service r'J Development Gas FJ single Zone X Multiple Zone J'--J 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, inc. RKB 41', Pad 70' feet Kuparuk River Field 3. Address 6. Property Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 316' FNL, 599' FEL, Sec. 23, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1308' FSL, 635' FWL, Sec. 23, T11N, R10E, UM 1D-127 #U-630610 At total depth 9. Approximate spud date Amount 992' FSL, 292' FWL, Sec. 23, T11N, R10E, UM 6/19/98 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property lineI 1D-124 7478' MD 292' @ TD feet 45' @ 100' feet 2560 4004' TVD .feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 64.96° Maximum surface 1356 psig At total depth 1782 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 77' 41' 41' 118' 118' +_200 CF 9.875" 7.625" 29.7# L-80 BTC MO£ 7437' 41' 41' 7478' 4004' 746 Sx Arcticset III & 363 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. 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 Conductor - .- ~ Surface ~. ~, L E!'V ~ P Intermediate Production Perforation depth: measured true vertical ~'~aBka. 0ii & Gas Cons, Ca~issior. t 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X I~?~lli'r~l-~rogram X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X Signed21' I hereby certifythat the foregoing is true and correct to the best of my knowledge.~~t,,,,,i,_~ ~- ~ CommissionTitleuse OnlyShall°w Sands Team Leader Date ~//~ Perm, j,t_Number J AP, number J Approve, date (¢//~ J See cover,attar for ~,/~,,,~ c] 50- O,~,'¢~ _, ~__.~___ ~- ¢~:~ other requirements Con~litTons' of approval Samples required F.; Yes ~j No Mud Icg lequifed - [-- Yes ,~ No Hydrogen sulfidemeasures j--jYes ~No Directional survey required j~jYes r-J No Required workingpressureforBOPE [-~2M ~ 3M ~] 5M [--] 1OM ~] 1SM Other: 0rigJnai Sign0ci~uy ~//~/(~ David W. Johnston by order of Approved by Commissioner the commission Date ARCO Alaska, Inc. ' .... Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 1, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1D-127 West Sak Phase lA Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1 D pad. The well is designed including hydraulic fracturing stimulation treatments using resin coated type proppant material. The stimulation procedure is designed to control sand production expected in these unconsolidated formations. The well is planned as a producer well using a progressive cavity ESP ("PCESP") to artificially lift the well. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-127, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). ' 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is June 19, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Since ,/" ~ '~ Thomas A. Brockway ~ Operations Drilling Engineer Attachments: cc: West Sak 1 D-127 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 Drill and Case Plan for West Sak 1 D-127 (L1) Frac-for-Sand Control Producer General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 120' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 7-5/8" 29.7# L80 BTC casing to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOP stackand pressure test same to 3,000 psi. 7. Pick up 6-3/4" mill tooth bit with 3-1/2" drill pipe and collars. Trip in and drill out stage collar. Clean out to PBTD. 8. Shut in BOP's and pressure test casing to 2,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Swap well over to non-freezing completion brine. Filter brine to desired level. Trip out. 10. Pick up 3-1/2" tubing deadstring and TIH. Circulate filtered brine to desired level. 11. Hang tubing in wellhead, install back pressure valve, and nipple down BOP stack. Nipple up and pressure test production tree. Secure well., 12. Release rig. 1D-127 (L1) Page 1 TAB,06/01/98,v1 Completion Plan for West Sak 1D-127 (L1) Frac-for-Sand Control Producer Four-Stage, Frac-for-Sand Control Completion (Off Rig Fracs) General Procedure: Well Preparation 1. Rig up frac equipment on well, and pressure test lines and production tree. Pull back pressure valve, and pressure test tubing and annulus. 2. Rig up E-line unit, and make correlation run as required with GR/CCL to correlate logs for perforating. NOTE: The number of stages frac'd may decrease from four (4) to three (3) depending on log results and final completion design strategy. Stage 1 3. Rig up thru-tubing perf guns for Stage 1 frac job which includes the West Sak A2 sands. RIH with perf guns, and position guns on depth. 4. Perforate Stage 1 overbalanced, and POOH with E-line. 5. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 1 interval. 6. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 1 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 1 from Stage 2 to follow. Pressure test sand plug as required. 7. RIH with slickline and confirm sand top above Stage 1 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 2 8. Rig up thru-tubing perf guns for Stage 2 frac job which includes the West Sak A3 sands. RIH with perf guns, and position guns on depth. 9. Perforate Stage 2 overbalanced, and POOH with E-line. 10. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 2 interval. 11. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 2 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 2 from Stage 3 to follow. Pressure test sand plug as required. 12. RIH with slickline and confirm sand top above Stage 2 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 3 13. Rig up thru-tubing perf guns for Stage 3 frac job which includes the West Sak A4 and B sands. RIH with perf guns, and position guns on depth. 14. Perforate Stage 3 overbalanced, and POOH with E-line. 1 D-127 (L1) Page 2 TAB,06/01/98,v1 15. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 3 interval. 16. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 3 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 3 from Stage 4 to follow. Pressure test sand plug as required. 17. RIH with slickline and confirm sand top above Stage 3 perfs. Use CTU as required to jet sand plug top to desired PBTD. Stage 4 18. Rig up thru-tubing perf guns for Stage 4 frac job which includes the West Sak D sands. RIH with perf guns, and position guns on depth. 19. Perforate Stage 4 overbalanced, and POOH with E-line. 20. Mix gel for frac job. Pressure test lines. Rig up, establish injectivity, and perform data frac on Stage 4 interval. 21. Mix epoxy / resin coated proppant and perform frac-for-sand control frac job on Stage 4 interval, pumping specified volume of proppant. Leave frac sand inside casing to isolate Stage 4 from tubing tail. Pressure test sand plug as required. 22. RIH with slickline and confirm sand top below tubing tail. Use CTU as required to jet sand plug top to desired PBTD. 23. Set back pressure valve in tubing hanger, pressure test production tree and secure well. Release frac, E-line, CTU, and slickline equipment as required. Pull Deadstring, Clean Out Well, Run ESP and Production Tubinq 24. MIRU completion rig on well. Nipple down production tree and nipple up BOP stack on wellhead. Install 3-1/2" rams unless VBR's are available. Pressure test BOP stack to 3,000 psi. Pull back pressure valve. Pull tubing hanger and circulate well to clean brine as required. TOH and lay down deadstring. Pick up rock bit and casing scraper and TIH with workstring. Clean out sand plugs, proppant, and perforating debris to PBTD below base of West Sak interval. Circulate well to clean brine. TOH with workstring. Pick up Centrilift ESPCP (progressive cavity ESP) motor, seal assembly, and tubing crossover on 3-1/2" production tubing. Run in well with ESPCP motor assembly with power cable and data gathering information wire attached to tubing. Attach Raychem heat trace cable to tubing at pre-determined depth to position bottom of heat trace below permafrost, and spaced out correctly to avoid surface splicing of heat trace cable. 25. 26. 27. 28. 29. 30. 31. 32. 33. 1 D-127 (L1) Page 3 TAB,06/01/98,v1 34. Position ESPCP at desired depth, set tubing hanger and run electrical penetrators through same. 35. Make surface electrical connections as required, and set back pressure valve in tubing hanger. 36. Nipple down BOP stack, and nipple up production tree. Pressure test production tree. Secure well. 37. Release rig and turn well over to production. Note: For E-line retrievable ESPCP pumps, the pump components may be run in the well with slickline after the completion rig has released from the well. 1 D-127 (L1) Page 4 TAB,06/01/98,v1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-127 (L1) Drillincl Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drillinq Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A combination surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-127 (L1) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diver[er system only for well control purposes. 1 D-127 (L1) Page 1 TAB,06/01/98,v. 1 Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ft, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.7 ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,453' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP = (3873 ft)(0.46- 0.11 psi/ft) = 1356 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 7- 5/8" 29.7# L80 BTC-MOD casing to be used has a burst rating of 6,890 psi; 70 % of this burst rating is 4,823 psi. A deadstring will then be run in the well in preparation for off-rig perforating and fracture stimulation treatments. A completion rig would then return to the well following fracture stimulation work to remove the deadstring, and to install the ESP pump, power cable, heat trace, and production tubing. Drillinq Area Risks: Drilling risks in the West Sak 1D-127 (L1) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby Kuparuk wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-127 (L1). Well Proximity Risks: The nearest existing well to West Sak 1D-127 (L1) is WS 1D-124 (G3). As designed, the minimum distance between the two wells would be 45' at 100' MD. Annular Pumpin.q Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-ID. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-127 (L1) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 7-5/8" combination surface / production casing and prior to the drilling rig moving off of the well. 1 D-127 (L1) Page 2 TAB,06/01/98,v. 1 C~,o~,~ ~ {~=. For: BROCKWAY Dote plotted: 21-~oy-98 Plot Reference ;s ~ 10-127/L1 Ve~. ~3. Coordinotes ore ~n lee~ reference s~ot ~127. T~e Vertical Depths ore reference ~8 (Parker ~245). 48OO I ARCO Alaska, ...... Ine Structure : Pod 1D Well : L1 Field : Kuporuk River Unif Locofion : North Slope, AloskoI <- West (feet) 4400 4000 3600 3200 2800 2400 2000 1600 I I I I I I I I I I I I I I I 1200 800 400 I I I f I 400 400 4O0 800 1200 1600 2OO0 2400 2800 3200 3600 4000 4400 227.89 AZIMUTH 5453' (TO TARGET) ***Plone of Proposol*** ESTIMATED SURFACE LOCATION: 316' FNL, 599' FEL SEC. 23, T11N, RIOE Ugnu Sands RKB ELEVATION: 111' KOP TVD=250 TMD=250 9EP=O BEGIN TURN TO TARGET TVD=550 TMD=550 OEP=4 19.71 DLS: 6.00 deg per 100 ft 25.60 31.53 43.44 55.58 Angle Drop Angle Drop West Sak Sands TARGET- West Sak A3 3ase West Sok Sends 7 5/8 Casing EOC TVD=1141 TMD=1560 DEP=555 TO LOCATION: 992' FSL, 292' FWL SEC. 23, TllN, RIOE g?O Az Begin Turn to Tarc Permafrost TARGET LOCATION: 1308' FSL, 635' FWL SEC. 23, T11N, RIOE TARGET TVD=3599 TMD=6860 DEP=5453 SOUTH 3656 WEST 4046 40O 8O0 1200 1600 2000 2400 28OO 3200 3600 4000 4400 MAXIMUM ANGLE 64.96 DEG B/ PERMAFROST TVD=1624 TMD=2501 DEP=1587 T/ UGNU SNDS TVD=2863 TMD=5429 DEP=4239 BEGIN ANGLE DROP TVD=3177 TMD=6171 OEP=4912 END ANGLE DROP TVD=3322 TMD=6438 OEP=5134 T/ W SAK SNDS TVD=3453 TMD=6638 DEP=5285 TARGET A3 TVD=3599 TMD=6860 DEl: 63.25 DLS. 6.00 deg per 100 ft. 51.25 TARGET ANGLE 49 DEG B/ W SAK SNDS TVD=3873 TM0=7278 DEP=5768 TO - CSG PT TVD=4004 TMD=7478 DEP=5919 i i i i i 0 400 800 I I I I I i i I i i II i ii i i i i i 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 VerticalSection (feet)-> Azimuth 227.89 with reference 0.00 N, 0.00 E from slot #127 i i i i i i i 5200 5600 6000 6400 I v 120 -i- (D 160 .4- 200 0 ICreated by finch For: BROCKWAY] Dote plotted: 21-May-98 Plot Reference ts WS 10-127/L1 Vets. ~3. Coordinates are ~n feet reference slot #127. True Vertical Depths ~ RKB (Parker ~245)./ ~rr~ j ARCO Alaska, Inc. Structure : Pad 1D Well : L1 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 800 760 720 680 640 600 560 520 480 4-40 400 360 320 280 240 200 160 120 80 4-0 0 40 80 80 I I I I I I I I I I ~ I I I I I [ I I I I I I I I I I I I I I I I I I I I I 1000 ...... ~ 2100 5OO 4O 120C 1 .... 1500 240 1100 1,300. 22OO 2100 . . 280 320 ~"/'"" 1500,.-" 360 /~'"'" 400 440 480 ~ , , , , , , ~ , , 800 760 720 680 640 600 ..... . .500 D600 17oc %o.9..--'"'8o0....-'- '" ,oo .-'~°_~oo 11oo ~ n .... "" -'"' 700,// / ,.,'~00 ~ vu~..-- ...-' / ' ,-' 1200 ...... 900 ..... /,/ ' 500. 1300 ....... . ...... .., ?oo -.t.~Bo 1900 800.// 1100.--'""' .. /' " ,.'i lOO ......... 1~oo.. ... .. 1 300,--'"'"'"' .,'t'(~00 -/ // ,/1 200 900 .-'"'" 1200 ..'"'" //' '/ /, 1100//' /, / x''~300 1000 / · · / , 1500 · '/ 1100 1200,,-" /{400 , 560 520 480 400 / / / / / 1100 / 300 ,/ 1100 )~,--~500 ,.. /'800 ~110~0 , , ~s_9.0 2800 ,'/ 120{ ]oo j zooZ ....... 800 290~' 1300 i800 /'900 O 280~ 2000 600 1400 /900 "~700 / ~ ' / ] / : 800 ,' 1500 ¢1000 i 2000~ 1 600 ~ ~ 1100 I I I I I I ] I I I I I I I I I I I I ~ 410 / 4-4-0 400 360 ,320 280 240 200 160 120 80 4-0 0 80 <- West (feet) 4O 80 120 160 ~ 200 '-~ 24-0 I 280 % 320 360 400 44-0 480 ARCO Alaska, l Cr.ot.d by~n~h For: BROCKWAY] Structure : Pad 10 Well: L1 Date plotted : 21-MoX-98 / Plot Reference isWS 1D-127/L1 Vers. t5. / Field : Kuparuk River Unit Location : North Slope. Alaska Coordinates are {n feet reference slot #127. / True Vcrticol Depths ~ RKB (Parker ~24S)./ <- West (feet) 2~00 2¢00 2300 2200 2100 2000 1900 1800 1700 1600 1~00 ~400 1300 ~200 1100 1000 900 800 700 600 500 400 4oo / 31oo ' ;;oo ...... ~'~og .... ?~oo ~oo _......-:T~. oo ~9oo ..... ~'~oo ...... ' .......-"" ../...-""' 1500 600 ....... ~8oo ........ ....... ..-"f~oo 7OO 800 900 ~- 1000 .-I-- 0 (,/'J 11o0 I ¥ 1200 1300 1400 15OO 1600 .-- .-' 1700 ..-" 2000 -' 2100 ..."~i 80O ..... ~'~oo ...-~'~5t30_____ "1900 ..... ...--- .... ~:;~oo ........ ..... ~:~'oo ........ ~'~00 ...... 2100 /~/ 2200 12oo,.,,' 1300 ,,,'" ,,'(5oo /'/' .-/" 1300 ..... ~oo ,,, ,,, ..--'"" --" 1400/'///'1600 14-00 50,0/./,//,,,i'700','/- 1500 :30~'/"/ 1 //?" 1 600 ,'" ~oo,...:;::-f~soo ~5oo/1,, 400 // 700, /'.'/1900 2700," 1 , ;';'" ;/1500 /7 1800 2800 ," /,.;;;',;;/ ,," ~.900/' ,,:;;E~:oo ,' 1800,,';/ 1900 3000// .;;""' 0/,~ 600 ,ss' / ~;' 3300/ / //~100 2000 ~0,," / 180C 1900 ;200 /" /' / .,., / 21 O0 /"1700 / ./¢¢¢'/' 2200 / / 1900 4¢;2000 ,' I i I I i i i I i i i i I i i i I I I I i i i i i i i i I I i i i i i i i i i i I i 2500 2¢00 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 400 <- West (feet) 17oo 400 500 600 7oo 8OO 900 0 1000 .-.I- 1100 I v 1700 1600 1500 1400 1300 1200 C~ce%¢d by finch For: BROCKWAY] Dote plotted : 21-May-g8 / Plot Re~'erence is WS 10-127/L1 Vets. if3. / Coord~notes ~re in fcct reference slot #127. ~ ARCO Alaska, Inc. Structure : Pad 1D Well : L1 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 5400 5200 5000 4800 4600 4400 4200 4000 3800 3600 3400 3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 1400 I I I I I I I I I ~ I I I I I I I I I I I I I I I I I I I J I I I I I I 1600 1800 2OO0 2200 24O0 2600 '-'S 2800 0 J 3000 V 3200 2500..J~ 2700 .."" 2300.?;;' ,.......-"'"' /'.;?21 O0 2900 ..-" ..;7 31 O0 ..'"' ..2' 3300 ..-" 2500..2.;;/ 2500 3700 ,.-- ,'~'300 2700.,,':,:':;::':'::"' 2900 2700 /)4500 ~ oo ./' 2900/,/' // / 3100//?/ /"2300 3300 /"//"'2700 ,' 3500//// ,,, 3700,./' // ,' 3900 / /' ," ¢100 .." /" /' /' J-'2~r .."~9 oo /2500 ///../' ///~1 oo ,,,,/ ..' / 53oo ,,," .-/"//" 31 O0 ./~500 ///' 2700 , .,,,.' /5700 ,/3300 //5go0 ;"~100 /'/" /'3300 .,'"~500 .//~1 O0 ./3500 6 .4'3oo ° .///' O0 41 O0 /"3700 ./~900 3400 3600 3800 4000 I ~ I 1400 2100 1600 1800 2300 W00 ,' 2000 / / / / 3900 " /;"21 O0 2200 ,, ,. ,- ,. 2400 26OO 2800 0 3400 3600 3800 4000 I i t i i t I I I I I I I I I I I i I I i I i I [ i I I I I [ I i I I I I I I I I I 5400 5200 5000 4500 4600 4400 4.200 4000 3800 3600 3400 ,.3200 3000 2800 2600 2400 2200 2000 1800 1600 1400 1200 <- West (feet) 3200 3000 I V ARCO Alaska, Inc. Pad 1D L1 slot #127 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE Baker Hughes INTEQ REPORT Your ref : WS 1D-127/L1 Vets. ~3 Our ref : prop2198 License : Date printed : 22-May-98 Date created : 16-Apr-97 Last revised : 21-May-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 58.208,w149 30 36.370 Slot Grid coordinates are N 5959348.702, E 560490.529 Slot local coordinates are 316.00 S 599.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is lim/ted to clearances less than 500 feet DECREASING CLEAP~LNCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PMSS ¢O-5462'~,,J3,Pad 1D PMSS <0-4778~>,,H4,Pad 1D PMSS <0-5015'>,,GT,Pad 1D PMSS <0 - ?340~,,10,Pad 1D PMSS ~556-7024~>,,9,Pad 1D MSS <3311-8200'),,7,Pad 1D PGMS <O-8610'),,6,Pad 1D PGMS ¢O-8930~),,5,Pad 1D PGMS c0-?502'),,4,Pad 1D PGMS <O-8070'),,3,Pad 1D P~MS <0-9783'),,2,Pad 1D P~MS <O-8365'),,1,Pad 1D WS 1D-101/C5 Vets. #3,,CS,Pad 1D PMSS <1957-5265'),,JS,Pad 1D WS 1D-108/A3 Vets. #3,,A3,Pad 1D WS 1D-104/A7 Vets. #3,,AT,Pad 1D WS 1D-103/B6 Vets. #3,,B6,Pad 1D WS 1D-102/A5 Vets. #3,,AS,Pad 1D 1D-D Version #2,,1D-D,Pad 1D 1D-F Version #2,,1D-F,Pad 1D WS 1D-107/B4 Vets. #1,,B4,Pad 1D 1D-B Version #3,,1D-B,Pad 1D WS 1D-151/Gll Vets. #1,,G11,Pad 1D WS 1D-138/K6 Vets. #1,,K6,Pad 1D WS 1D-161/L7 Vers. #l,,LT,Pad 1D Closest approach with 3-D MinimumDistance method Last revised Distance M.D. Diverging from M.D. 1-Dec-9? 67.1 640.0 640.0 9-Nov-97 86.0 560.0 560.0 13-Nov-97 184.5 760.0 760.0 28-Apr-98 238.8 640..0 640.0 29-Apr-98 180.0 120.0 120.0 6-Nov-97 150.7 720.0 720.0 13-Nov-97 47.0 20.0 460.0 13-Nov-97 72.5 290.0 290.0 4-Aug-92 192.7 350.0 350.0 4-Aug-92 313.0 20.0 350.0 4-Aug-92 432.9 330.0 330.0 10-Dec-97 552.9 350.0 350.0 21-Jano98 508.0 300.0 300.0 24-Nov-97 122.6 680.0 680.0 22-Jan-98 388.0 300.0 300.0 21-Jan-98 463.0 300.0 300.0 21-Jan-98 478.0 290.0 290.0 21-jan-98 493.0 300.0 300.0 24-Nov-97 32.0 310.0 310.0 24-Nov-97 141.S 620.0 620.0 17-Apr-97 403.0 310.0 310.0 24-Nov-~7 60.2 502.6 7477.7 15-Apr-97 230.9 250.0 250.0 16-Apr-97 257.0 300.0 300.0 16-Apr-9? 346.3 250.0 250.0 WS 1D-160/K8 Vets WS 1D-159/L9 Vets WS 1D-157/K10 Vets WS 1D-156/J9 Vets WS 1D-155/H8 Vets WS 1D-154/J11 Vets WS 1D-153/H10 Vets WS 1D-150/F10 Vers. WS 1D-152/G9 Vets. WS 1D-149/F8 Vets. WS 1D-148/E11 Vets. WS 1D-147/E9 Vets. WS 1D-146/D10 Vets. WS 1D-145/Cll Vets. WS 1D-144/D8 Vets. WS 1D-143/C9 Vets WS 1D-139/B8 Vets WS 1D-140/A9 Vets WS 1D-142/B10 Vets WS 1D-141/A11 Vets WS 1D-158/L11 Vets PMSS <381-6092t>, PMSS <0-5126'>,, PMSS <0-4850'>,, PMSS <0-50%7'>,, PMSS <0-5205'>,, PMSS <0-5142'>,, PNSS <0-4590'>,, #1,,KS,~-~'ID #1,,Lg,Pad 1D #1,,K10,Pad 1D #1,,Jg,Pad 1D #1,,HS,Pad 1D #1,,J11,Pad 1D #1,,H10,Pad 1D #1,,F10,Pa~ 1D #l,,Gg,Pad 1D #1,,FS,Pad 1D #1,,Ell,Pad 1D #1,,Eg,Pad 1D #l,,D10,Pad 1D #1,,C11,Pad 1D #1,,DS,Pad 1D #1,,Cg,Pad 1D #1,,BS,Pad 1D #1,,Ag,Pad 1D #1,,B10,Pad 1D #1,,All,Pad 1D #1,,L11,Pad 1D ,CT,Pad 1D D6,Pad 1D D4,Pa~ LD G3,Pad 1D ET,Pa~ 1D E3,Pad 1D ES,Pad 1D PMSS <0-4515'>,,F4,Pad 1D PMSS <0-4530'>,,F6,Pad 1D PMSS <O-4414'>,,G5,Pad 1D WS 1D-136'J7 Vets. #1,,JT,Pad 1D WS 1D-111 WS 1D-112 WS 1D-113 WS 1D-114 WS 1D-116 WS 1D-122 WS 1D-123 WS 1D-125 WS 1D-110 'B2 Vets. /Al Vets /C1 Vets /D2 Vets /El Vers /F2 Vets /O1 Vets /H2 Vets, IC3 Vets. #3,,B2,Pad 1D #3,,Al,Pad 1D #3,,el,Pad 1D #3,,D2,Pa~ 1D #3,,El,Pad 1D #3,,F2,Pa~ 1D #],,Q1,Pad 1D #3,,H2,Pa4 1D #3,,C3,Pad 1D WS 1D-131tL3 Vers. #3,,L3,Pa~ 1D TOTCO Survey,,WS-8,Pad 1D WS 1D-134/L5 Vers. #3,,LS,Pad 1D WS 1D-132/K% Vets. #3,,K4,Pad 1D WS 1D-126/J1 Vets. #5,,J1,Pad 1D WS 1D-128/K2 Vets. #3,,K2,Pad 1D 16-Apr-97 16-Apr-97 15-Apr-97 15-Apr- 97 15-Apr- 97 15-Apr-97 15-Apr- 97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr- 97 15-A~r-97 15-Apr- 97 15-Apr- 97 15-Apr-97 15-Apr- 97 15-Apr-97 15 -Apr- 97 15-Apr-97 15-Apr- 97 16 -Apr- 97 27-Jan-98 19-Ja=- 98 12-Jan-98 6-Jan- 98 7-Jan- 98 30-Dec-97 22 -Dec- 97 16-Dec-97 19-Dec-97 8-De¢-97 10-Feb-98 22-Jan-98 22 -Jan- 98 22-Jan-98 26-Jan-98 26-Jan-98 26-Jan-98 26-Jan-98 26-Ja~-98 22-Jan-98 21-May-98 21-May- 98 21-May- 98 21-May-98 20-May- 98 21-~ay- 98 333.5 320.9 296.4 284.5 273.0 261.8 251.0 221.6 240.7 213.0 205.2 198.1 192.0 186.9 182.9 180.0 181.0 178.9 178.4 178.0 308.5 449.5 420.0 375.0 45.0 225.0 255.0 209.7 165.0 150.0 135.0 206.3 343.0 298.0 283.0 268.0 238.0 118.0 102.8 28.0 358.0 105.0 241.0 189.4 120.0 15.0 15.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 290.0 100.0 100.0 100.0 100.0 180.0 330.0 100.0 100.0 100.0 700.0 310.0 250.0 290.0 270.0 310.0 310.0 366.7 310.0 300.0 250.0 880.0 607.2 240.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 290.0 100.0 100.0 100.0 100.0 180.0 330.0 100.0 100.0 100.0 700.0 310.0 250.0 290.0 270.0 310.0 310.0 366.7 310.0 300.0 250.0 880.0 607.2 240.0 250.0 3020.0 West' $ak 1D-127 (L1) Produce7' Well Four (4) Stage Frac-for-Sand Control with 3-1/2" Deadstring 16" Conductor Casing @ 80' Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) 3-1/2" Tubing Deadstdng 9.3# L-80 EUE 8RD-Mod (to fmc through off-rig) 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Sudace/Pmduction Casing, 29.7# L-80 BTC-MOD Cemented to Surface (+/- 7478' MD / 4004' TVD) A2 Sand Frac'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v. 1 West Sak 1D-127 (L1) Producer Well Four (4) Stage Frac-for-Sand Control Completion 16" Conductor Casing @ 80' 3-1/2" Production Tubing 9.3~ L-80 EUE 8RD-Mod Raychem Heat Trace (through permafrost) Weatherford Gemoco 754HO 7-5/8" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200' TVD below permafrost) Power Cable for ESP Centrilift Camco 3-1/2" x 1" 'KBMM' Gas Lift Mandrel Amtic Lift 3500 psi Shear circulating valve pro-loaded in GLM (circulate well for freeze protection purposes) ESP Pump Section Centrilift ESP Gearbox Centrilift 7-5/8" Casing Marker Joint 29.7# L-80 BTC-Mod (set +/- 50' above top perforation) ESP Motor Section Centrilift D Sand Frac'd with Resin Coated Proppant B + A4 Sands Frac'd with Resin Coated Proppant A3 Sand Frac'd with Resin Coated Proppant 7-5/8" Combination Surface/Production Casing, 29.7# L-80 BTC-MOD Cemented to Sudace (+/- 7478' MD / 4004' TVD) A2 Sand Fmc'd with Resin Coated Proppant ARCO Alaska, Inc. TAB, 05/18/98, v.2 KUPARUK R~VER UNIT - WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC ! i HCR 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES· . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVEAND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY' OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THATAN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP~N WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PS! BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20'- 2000 PSI ANNULAR PREVENTER. TWM, 9/1~97 8 1 7 13 West 6 > I 5/8" 5000 BOP STACK Sak Operations - Producer Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PS! WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY 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 MMIT 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 ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE ENE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE UNES. 7. TEST TO 250 PSI AND 30(X:) PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, MNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. -TEST BOTi'OM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUTOF HOLE. CLOSE BUND RAMS AND TESTTO 3000 PSI FOR 3 MINUTES. I~.EED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESELAND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE ;3-1/'2- TO 6' OR 4-1/2' TO 7' PIPE ODSAS APPROPRIATE. 1. 16'- STARTING HEAD 2. 11' - 5000 PSI HORIZONTAL TUBING HEAr., 3. 11' 5000 PSI X 13-5/8' 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8' - 5000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 5. 13-5/8' - 5000 PSI PIPE RAMS 6. 13-5/8'- 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8' - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8' - 5000 PSI ANNULAR TWM, 9/22/97 Rood _ D.S, I'D i ~ ~ClNI~ MAP 122~; ~2~ d~ 123 I 12~ N 25~ 126 :1 :127~ 128 , Q 6 ~ ~o I NO LEGEND SE[ SHE~ ~ 2 FOR NOTES ~O LO~TION INFORMATION .o gx/sr/~ conductors ~ ~OUNSBURY · "AS-STAKED" CONDUCTOR LOCAnON~~~/~ A ASSOC[ATES, INC. ~ "PROPOSED" CONDUCTOR LOCA~ON ~~-~N~ P~N~ suR~YO~ AREA' 1D M~ULE XX UNIT' D1 ~ DRILL SI~ 1-D ARCO Alaska, Inc. ~r ~ST SAK PHASE lB - ~ CONDUCTORS As- S~A~.~ ~OCA~ONS ,~,~,, ~/~./a~ NSK 6.104-d14 1 OF 2 0 __{ -- I-~ ~D.S. IB J ~'~_~ '~ NO /,,_r- c.P.r.~ ?,,\ / ~""------.~ ELEVATIONS SHO~ ARE BRITISH PETROLEU~ ~EAN PIT C SEA LEAL. ALL DISTANCES SHO~ ARE TRUE. 9 LARE~( PIT . ~. CONDUCTORS ARE LOCATED ~IN P~OTRAC~D SEC~ONS 14 ~ 2~, TO,SHIP. 11 NOR~, RANGE I0 EAS~ 4. DATE OF SUR~K' 5/~6/98, FIELD BK. L98-42 Pgs. 8-14. , ~ 5 ~ SAK-1 ~ 5. DRILL SITE l-O GRID NORTH IS ROTATED 00' 01' 05" ~ ~T ~o~ ~.~.~. ~ON~ ~ ~,~ ~O,T,. ~~ ~ ~ ~iS ~ ~ ~ ( ,. SEE DRA~NG NSK-5.5-1 FOR AS-BUILT LOCA~ONS OF ~ ~__ v SURly ~ ,o~.,o,.,o~.,,~.,,,-,~,.,~,.,~.,~o.,~ , ,~, ,.o ~ ~ ~' CEA-OIOX-6104015 FOR CONOUCTORS 9 ~ 10. ~CINITY ~AP SCALE: ~" = I MILE , SEC. SEC. PAD O. G. Well A.S.P.s LA TI TUDE L ONGI TUOE Sec. 14, T. 11 N., ~.10 ~. F.S.L.F.E'L. 108 ~5,959,738.9 560,490.6 70' ~8' 02.05" 149' 30' 36.28" 74' 596' 70.4' 62.4' 1ZO ~5,959,708.9 560,490.6 70' ~8' 0~.75" Z49' 30' 36.28" 44' 596' 70.4' 66.5' ~1~ ~5,959,693.9 560,490.6 70' ~8' 0~.60" Z49' ~0' 36.29" 29' 596' 70.4' ~.5' Sec. 2~, T. 11 N., R. 10 ~. F.N.L.F.E. LZ IZ2 ~5,959,648.9 560,490.6 70' ~8' 0~.16" 149' 30' ~6.30" Z6' 597' 70.4' ZI3 ~ ~,959,6~3.9 560,490.6 ZO' ~8' 0~.01" ~49' ~0' ~.~0" 3~' 597' 70.4' 63.2' ~4 ~5,959,618.9 560,490.6 70' ~8' 00.87" ~49' ~0' ~6.30" 46' 597' 70.4' 6~.2' 116 ~5,959,588.9 560,490.6 70' ~8' 00.57" 149' ~0' ~6.3~" 76' 597' 70.4' 122 5,959,469.0 560,490.7 70' 1Z' 59.39~ Z49' ~0' 36.~4" ~96' 598' 70.5' ~23 5,959,453.9 560,490.7 70' ~7' 59.24" 149' ~0' 36.34" 2~' 598' 70.4' ~4.2' ~25 5,959,379.2 560,490.7 70' ~7' 58.5~" Z49' 30' ~.36" 286' 599' 70.~' 64.3' ~26 5,959,363.9 560,490. 7 70' 17' 58.36" ~49' 30' ~6.36" 301' 599' 70.3' 64.3' ~27 5,959,348.9 560,490.7 70' 17' 58.21' ~49' ~0' ~6.36" ~6' 599' 70.3' 64.3' 128 5,959,~34.1 560,490.7 70' 17' 58.06~ Z49' 30' ~6.37" ~3Z' ~99' 70.3' 64.5' ~3~ 5,959,244.0 560,490.7 70' 17' 57.18" ~49' ~0' 36.39" 42~' 600' 70.5' 69.9' 152 5,959,229.2 5~0,490. ? 70' 17' 5703" 149' ~0' ~.39~ 436' 600' 70.4' 69.8' 134 5,959,~53.8 560,490.8 70' ~7' 56.29" I49' ~0' ~6.4~" 5~' 601' 70.5' 69.~' · ~ Proposed Iocotion, work in progress LOUNSBURY & ASSOCIATES, INC. AREA: ID MODULE: XX UNIT: D1 ~ DRILL Sl~ 1-D · ARCO Alaska, Ino. co, uc o s WELL PERMIT CHECKLIST WELL NAME .... PROGRAM: exp [] de redrll [] serv [] wellbore seg [] ann. disposal para req [] GEOL AREA ~',~ d3 UNIT# //?/_,~ ~j ON/OFF SHORE ~,v'~ N COMPANY FIELD & POOL ~'/C),/,_~c:) INIT CLASS Z~z,,-" /-'~_?/ ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 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 long string to surf csg ........ -Y---N-- 18. CMT will cover all known productive horizons .......... ~.~ N 19. Casing designs adequate for C, T, B & permafrost ....... y~ N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to ~('3~O psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. Y Permit can be issued w/o hydrogen sulfide measures ..... ~YY N,.,/~,,~ ,/~ Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones ............. , Seabed condition survey (if off-shore) ............. ~ Y N ' Con, tact.nam, e/phone for weekly progress reports ...... .j Y N / exploratory only] ENGINEERING 30. 31. 32. 33. 34. GEOLOGY With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . ._.._...-~-. Y N (B) will not contaminate freshwater; or caus~p.~~ste... Y N to surface; (C) will not impair mechanic~grity of the well used for disposal; Y N (D) will not damage p~ing formation or impair recovery from a Y N pool; and / (E) will not cirEumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ANNULAR DISPOSAL 35. DATE GEOLOGY: ENGINEERING: UlC/Annular ~DH....,' COMMISSIOn. RNC- ~ co do ~'1 l~/'~ ~' Commentsllnstructions: M:cheklist rev 05~29~98 dlf:C:\msoffice\wordian\diana\checklist 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. Sperry-Sun Drilling Services LIS Scan Utility Fri Sep 11 11:03:15 1998 Reel Header Service name ............. LISTPE Date ..................... 98/09/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/09/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, WEST SAK MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD MWD RUN 1 AK-MM-80272 S. BURKHARDT D. BREEDEN Anchm'age 1D-127 500292289000 ARCO ALAS~%., 'rNc. SPERRY-SUN DRILLING SERVICES ll-SEP-98 MWD RUN 2 AK-MM-80272 S. BURKHARDT D. BREEDEN 23 lin 010 .00 111.80 70.30 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7432.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. 4. WELL 1D-127 REACHED A TOTAL DEPTH (TD) OF 7432'MD, 4026'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.00t Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH 121 0 121 0 121 0 121 0 121 0 124 0 125 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 7386 0 7386 0 7386 0 7386 0 7393 5 7386 0 7431 5 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 125.0 4449.0 2 4449.0 7432.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Loggi.ng Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 121 7431.5 3776.25 14622 121 GR 13.266 138.811 68.9067 14546 121 RPX 1.0613 2000 47.0245 14531 121 RPS 0.0907 2000 55.3105 14531 121 RPM 0.1995 2000 67.5354 14531 121 RPD 0.127 2000 81.2774 14531 121 ROP 10.9387 900.975 283.941 14613 125.5 FET 0.0716 10.4273 0.384002 14525 124 Last Reading 7431.5 7393.5 7386 7386 7386 7386 7431.5 7386 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 7431.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 121.0 4410.0 RPM 121.0 4410.0 RPS 121.0 4410.0 RPX 121.0 4410.5 GR 121.0 4418.0 FET 124.0 4410.5 ROP 125.5 4449.0 $ LOG HEADER DATA DATE LOGGED: 02-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 4449.0 TOP LOG INTERVAL (FT): 121.0 BOTTOM LOG INTERVAL (FT): 4449.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 65.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : TOOL NUMBER P1033CRG6 P1033CRG6 9.880 9.9 SPUD MUD 182.70 285.0 MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.3 600 9.8 6.500 5.740 8.000 5.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 1 API 4 1 68 4 2 RPX MWD 1 OHMM 4 1 68 8 3 RPS MWD 1 OHMM 4 1 68 12 4 RPM MWD 1 OHMM 4 1 68 16 5 RPD MWD 1 OHMM 4 1 68 20 6 ROP MWD 1 FT/H 4 1 68 24 7 FET MWD 1 HOUR 4 1 68 28 8 30.6 First Name Min Max Mean Nsam Reading DEPT 121 4449 2285 8657 121 GR 13.266 130.971 66.3156 8595 121 RPX 1.0613 2000 71.2431 8580 121 RPS 0.0907 2000 84.6972 8579 121 RPM 0.1995 2000 105.67 8579 121 RPD 0.127 2000 128.741 8579 121 ROP 28.8721 900.975 306.301 8648 125.5 FET 0.0716 5.3083 0.297847 8574 124 Last Reading 4449 4418 4410.5 4410 4410 4410 4449 4410.5 First Reading For Entire File .......... 121 Last Reading For Entire File ........... 4449 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 4410.5 7386.0 RPM 4410.5 7386.0 RPS 4410.5 7386.0 FET 4411.0 7386.0 RPX 4411.0 7386.0 GR 4418.5 7393.5 ROP 4450.5 7431.5 $ LOG HEADER DATA DATE LOGGED: 04-JUL-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 7432.0 TOP LOG INTERVAL (FT): 4449.2 BOTTOM LOG INTERVAL (FT): 7432.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 42.7 MAXIMUM ANGLE: 65.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA TOOL NUMBER P1033CRG6 P1033CRG6 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9.880 9.9 LSND 184.60 210.0 8.2 5OO 3.8 3.400 2. 674 3. 900 3.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 t 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 38.4 First Name Min Max Mean Nsam Reading DEPT 4410.5 7431.5 5921 6043 4410.5 GR 26.9009 138.811 72.649 5951 4418.5 RPX 2.4591 104.281 12.1068 5951 4411 RPS 2.5578 127.538 12.9537 5952 4410.5 RPM 2.5903 131.083 12.5694 5952 4410.5 RPD 2.692 99.344 12.8653 5952 4410.5 ROP 10.9387 636.331 251.515 5963 4450.5 FET 0.09 10.4273 0.508131 5951 4411 Last Reading 7431.5 7393.5 7386 7386 7386 7386 7431.5 7386 First Reading For Entire File .......... 4410.5 Last Reading For Entire File ........... 7431.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/09/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/09/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 98/09/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
