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Home My WebLink About198-133 RECEIVED k� • °\241 FEB 0 3 2017 WELL LOG TRANSMITTAL# AOGCC To: Alaska Oil and Gas Conservation Comm. January 9, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 2 /Co/2017 v1. K. BENDER SGA Ea �� +2 : RE: EM Pipe Xaminer: 1D-28 Run Date: 10/25/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1D-28 Digital Data(LAS), Digital Log file, Casing Inspection Report 1 CD Rom 50-029-23237-00 EM Pipe Xaminer(Processed Log) 1 color log 50-029-23237-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: i vQi22ctr I3..e,ig.e • • v ConocoPhillips Alaska IECEnQED P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 MAR 9 2012 March 9, 2012 IpcfriNitifill MAR Qk Ma Alaska Oil & Gas Cons. Commission Anchorage Commissioner Dan Seamount Alaska Oil & Gas Commission 3 333 West 7 Avenue, Suite 100 art 3 Anchorage, AK 99501 1' t �. \, Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells were found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped in the fall of 2011. The corrosion inhibitor /sealant was pumped on various days in January and February 2012. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Martin Walters at 907 - 659 -7043, if you have any questions. Sincerel , MJ veland ConocoPhillips Well Integrity Projects Supervisor • • Co oc®Phlll"aps Alaska Inca Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 3 -09 -2012 1B, 1 C,1 D,1 E PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date if bbls ft gal 1B -02 50029205310000 1801330 SF NA 16" NA 2.98 1/21/2012 18-06 50029206030000 1810750 8' 1.50 5'6" 9/11/11 18 1/21/2012 WSW-04 50029208330000 1821590 6'4" 1.30 24" 9/11/11 6.8 1/21/2012 WSW -06 50029208510000 _ 1821770 20" NA 20" NA 2.13 1/21/2012 1C-11 50029227140000 1961720 SF 1.50 22" 9/11/11 4.68 2/10/2012 1C-18 50029229390000 _ 1990050 SF NA 18" NA 2.55 2/102012 1C -26 50029229440000 1990510 , SF NA 18" NA 3.75 2/10/2012 1D-128 50029229000000 1981330 2" NA 26" NA 3.83 2/102012 cfjp, • MEMORANDUM To: Jim Regg +~ P.I. Supervisor '~~<~ ~!'(~~/G FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC iD-128 KUPARUK RIV U WSAK 1D-128 Src: Inspector .NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ ~-- Comm Well Name: KUPARUK RIV U WSAK 1D-128 Insp Num: mitRCN100718143045 Rel Insp Num: API Well Number: 50-029-22900-00-00 Permit Number: 198-133-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --- ~--- Well 1D-128 ype InJ. N ~' TVD 3452 I,e~ 30 1730 - I 1640 1630 P.T.D 1981330 TypeTest SPT ~ Test psi ~ 1730 ~ OA Interval 4~TST p/F P - Tubing ]zs zoo 12s 1zs Notes: - ~~, i~ 1` ~> ~` . Thursday, July 22, 2010 Page 1 of 1 04/30/09 ~~~~ NO. 5203 i Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # :~. i y ~.,.r ~.,xt :_~ ~~U~ Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnkeri 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 3F-03 ANHY-00070 INJECTION PRO ' 2D-03 1 E-29 3G-13 3F-18 ANHY-00075 804C-00030 ANHY-00079 B04C-00031 FILE - ~ ~ PRODUCTION PROFILE - PRODUCTION PROFILE l 9 INJECTION PROFILE ~ _ ~/ P 04/04/09 04/10/09 04/14/09 04/15!09 1 1 1 1 1 1 1 1 1 D-117 B14B-00027 RODUCTION PROFILE / INJECTION PROF ~ 04/15!09 1 1 1 D-128 1 H-21 1D-120 AYS4-00057 B14B-00028 AYS4-00058 ILE ~ " }- INJECTION PROFILE PRODUCTION PROFILE L INJECTION PROFIL 04/16/09 04116!09 04/17/09 1 1 1 1 1 1 2K-22 1E-95 AYS4-00059 AYS4-00061 E IBP/SBHP INJECTION PROFIL 04/17/09 04/18/09 1 1 1 1 1Y-04 3F-02 1 G-04 AYS4-00071 AYS4-00063 B14B-00036 E Z„ - INJECTION PROFILE PRODUCTION PROFILE c _ SBHP SURVEY 04/20/09 04/28/09 04/22/09 1 1 1 1 1 1 iR-03A AYS4-00063 ~, e _ G( SBHP SURVEY 04/23/09 1 1 iG-O6 61 ~ } -1_ ~. ~O~ _~~p ~ ~ 9--/ (p 04/23/09 1 1 46-00035 SBHP SURVEY ~~ l~~ -~ ~'~~~-~ 04/23/09 iR-10 B14B 000 ~~ °- 1 1 2F-02 1R-15 - 31 AYS4-00060 B14B-00032 SBHP SURVEY - ~~ c - INJECTION PROFILE ~ L+ .- /~ I U SBHP SURV '"' 04!20/09 04/19/09 1 1 1 1 EY, - ~ _ ~ G 04/20/09 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. f/VE~~ L~ ,.; ;~ TR~4/1~~11/lll'T~4L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907J fi59-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspectaon(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 following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Anchorage, AK 99518 ~~'°`~~ ~~~ 1. ~ ~ ~ Fax (907j 245-8952 1) 2] Caliper Report 02-Mar~09 Caliper Report 03-Mar~09 1 D~128 1 Report / EDE 50-029-22900-00 1 E~-02 1 Report / EOE 50-029-20531-00 ~J_~ ~ ~- . `A~'~~..~.. -..-, ;, ,~ ,, ,. Signed . ~ ~~ ~` `l - Date rt f a :~ Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 98518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL a°:.7~~?C:ia~~£1~s :33~f'1~J~~~JsT9 WEBSITE ~V~af'.t\7,i1~2e~G£Y''a%+L,~33"i3 C:\Documents and Settings\Oamer\Desktop\Transmit_Cunoco.doac • • Memory Gatiper & Magnetic Thictcness "Tarot S La Results Summary 9 Company: ConocoPhillips Alaska, Inc. Weil: 1D-128 Log Date: March 2, 2049 Field: Kuparuk Log No.: 10544 State: Alaska Run No.: 4 (2"d MIT, 3rd MTT) APi No.: 50-029-22900-00 Pipet Desc.: 3.5" 9.3 ib L-80 EUE Top Log Intvl.: Surface Pipet Use: Tubing & Liner $ot. Log Intvl.: 5,880 Ft. (MD) Pipet Desc.: 5.5" 15.51b L-80 BTCM Top Log Intvl.: Surtace Pipet Use: Production Casing Bot. Log Intvl.: 221 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 The caliper log Is tied into the OS Nipple Gay 5,745' (Driller's Depth), while the M7T data is tied Into the Mandrel Hanger ~ 0'. This is the second time this well has been logged with a POS caliper and the third time with the 12 Arm Magnetic Thickness Tool (MTT). The MTT responds to the total thickness of metal of the 3.5" tubing, 5.5" production casing and the 16" conductor pipe. Passes at SHz, BHz, 10Hz and 12Hz were made at 20 fpm, with the 10Hz pass selected for analysis in this report. 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. INTERPRETATION OF CALIPER LOG RESULTS The caliper log was run to assess the condition of the 3.5" tutrng, particularly for any indications of buckling caused by subsidence. The caliper recordings indicate slight buckling ftam surface to 1,300', with moderate buckling recorded from -1,300' to the end of the interval logged. A 3-0 log plot of the caliper recordings across an interval of slight buckling from surtace to 1,000' is included in this report. The caliper recordings indicate that the 3.5" tubing and liner logged appear to be in good to poor condition with respect to corrosive damage, with a maximum wall penetration of 79% recorded in a line of pits in joint 173 (5,508'). Recorded damage appears in the form of isolated pitting, often in a line. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. This is the second time a PDS caliper has been run in this well and the tubing and liner logged. A compar"son between the current and previous log (July 28, 2005) indicates an increase in corrosive damage during the time between logs. A graph illustrating the difference in maximum recorded penetrations on a joint-by joint basis between logs is included in this report. ProActive Diagnostic Services, Inc. J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9485 Fax: (281) 565-1369 E-mail; PDS~imemorylog.com Prudhoe Say Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~;;-fit:- /r_-~~ ~ lam?"~. f r~`~C:'~~ • 3,5" TUBING -MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits (79%) Jt. 173 @ 5,508 Ft. (MD) Line of Pits (78%) Jt. 168 ~ 5,333 Ft. (MD) Line of Pits (74%) Jt. 180 ~ 5,762 Ft. (MD) Scattered Pitting (72%) Jt. 181 @ 5,845 Ft. (MD} Line of Pits (72%) Jt. 165 ~ 5,237 Ft. (MD) 3.5" TUBING -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 11%) are recorded throughout the tubing and liner logged. 3.5" TUBING -MAXIMUM RECORDED ID RESTRICTIONS: No significant l.D. restrictions are recorded throughout the tubing and liner logged. COMPARISON TO PREVIOUS MTT LOG RESULTS A comparison of the current 10Hz pass to the previous 10Hz passes (October 7, 2007 and December 29, 2006) indicates a new area of significant metal foss over the interva120' - 25'. The current log indicates a maximum arcumferencial metal loss of 9% within this interval, where previous logs show no significant metal loss. The current log indicates a slight increase in recorded metal loss over the interval from 10' to 17', showing a maximum circumferencial metal loss of 15% relative to the previous log which indicated a maximum of 13°~ circumferential metal loss over this interval. There appears to be little, if any, change in metal loss recorded over the interval 33' -37'. The current log indicates a maximum metal loss of 12°~ within this interval, which closely matches the readings from the previous log. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous logs is included in this report. The current log was pulled at 20 fpm, while the previous logs were run at 45 fpm. The slower logging speed used for the current log results in a much more stable tool response through the previously recorded metal loss area from 10' to 17', with the current metal loss curve closely following the peaks of the data recorded through this interval in the previous log. The current log included a 5Hz pass and the metal loss curve from this pass is included in the comparative overlay plot of this report. The 5Hz pass supports the development of the new area of metal loss indicated from 20' to 24' and indicates a higher degree of metal loss than the 10Hz pass over intervals where significant metal loss is indicated. Since a 5Hz signal is theoretically capable of penetrating or °seeing" more metal than a 10Hz signal, it is believed that the difference in the values from the 5Hz and 101iz passes supports the conclusion that the metal loss is from the outer pipe strings of the completion. In the 2007 and 2006 logs, calibration samples were only taken within the concentric pipe that included the conductor. As a result, calculated metal thickness below the conductor appears to show metal loss due to the absence of the extra metal from the conductor pipe. The current log includes an additional calibration applied below the conductor, so the calculated metat thickness no longer reflects a loss due to the absence of the conductor. INTERPRETATION OF MTT LOG RESULTS The 10Hz MTT tog results cover the interval from surface to 221'. Changes in metal volume are relative to the calibration points at 18' and 150', where the readings are assumed to represent undamaged pipe- All other readings are relative to these reference points. A maximum 15% circumferential metal loss is recorded in the interval between 10' -17'. A log plot of the 10Hz MTT pass is included in this report. The Delta Metal Thickness (°~} curve in these plots refers to total metal surrounding the MTT tool. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS'amemorylog.com Pr~~dhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • A 1-9°~ circumferential metal loss is recorded in the interval between 20' - 25'. A 1-4% circumferential metal loss is recorded in the interval between 25' - 30'. A 12% circumferential metal loss is recorded in the interval between 33' - 37'. A 1-4°!o circumferential metal loss is recorded in the intervals between 46'-52'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percen# 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 Analysts: Waldrop (M177, Burton/Lawrence/Yang (MTn Witness: C. Fitzpatrick ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888} 565-9085 Fax: (281} 565-1359 E-mail: pDS~amemorylog.com Prudhoe Bay Field Office Phone: (907} 559-2307 Fax: (907} 559-2314 ' • • PDS Multifinger Caliper 3D Log Plot `~. __ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 D-128 Date : March 2, 2009 Description : Detail of Caliper Recordings Across Interval of Slight Buckling from Surface to 1,000' o° o• so° ~eo° z~o° o° I ^ • 500 - Joint l5 i - ~- - - - _ ,~ " ar"„ _ Joint 16 55 .. """"H ~a 0 __~..-,-_....._ Joint 17 "' ~..r.... 60 ~ = Joint 78 0 i ~__ ~' _; ;~. ._ Joint 19 .__~ tit? 650 ~ "" ______.._ . : __ _ Joint 20 e 1 ~ °°;•-, a Slight Buckling -~ 700 Joint 21 _: ~,~„ -.... Joint 22 ~- 750 _ ~°°. ~ .. - ~. Joint 23 _ ,~„_ . ~.,,, _ Joint 24 8OO Slight Buckling _ Joint 25 ' +- ° Slight Buckling .a~~ ~. 850 _ Joint 26 .,, . Slight Buckling -- "'yew ,.. Joint 2T 900 '; a .~ Joint 28 ~.~.L..,...._ ...~~`~ 950 s- Joint 29 Sli ht Bucklin °j +~~ g g «~~,~,R,,,, Joint 30 Sli ht Bucklin - g g Nominal ID (1/1000 in.) 2500 3500 Min ID (1/1000 in.) 2500 3500 Comments Depth Max ID (1/1000 in.) (Off-Center) Image Map (Centered) Image Map 1ft:750ft 2500 3500 0° 90° 180° 270° 0° 0° 90° 180° 270° 0° Maximum Recorded Penetration `~ Comparison To Previous Well: 1 D-128 Survey Date: March 2, 2009 Field: Kuparuk Prev. Date: July 28, 2005 Company: ConocoPhillips Alaska, Inc. Toot UW MFC 24 No. 218183 Country. USA Tubing: 3.5" 9.31b L-80 Overlay Masc . Rec. Pen. ( mils) 0 1 00 2 00 0.1 8 18 28 38 48 58 68 78 ,. E 88 0 z 98 'o 108 118 128 138 148 158 168 178 180.2 ^ March 2, 2009 ^ July 28, 2005 300 Difference Correlation of Recorded Dama€ Pipe 1 3.5 in (36.6' - 5850.1') Well: Field: Company: Country: Survey Date: • ;e to Borehole Profile 1 D-128 Kuparuk ConocoPhillips Alaska, Inc. USA March 2, 2009 ^ Approx. Tool De viation ^ A pprox. Borehol e Profil e 1 40 25 813 50 1604 75 ~-- 2389 '" ~ w ~ ~~ ` '-' u ~ A C Z ~ 10(1 t 3181 ~. •o °' O 125 3969 150 4760 175 5547 GLM 1 182 5850 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 182 ~~M~ Well: 1 p-128 Field: KupaNk CompanY~ ConocoPhillips Alaska, Inc. Country: USA Weight Grade & Tubing: Nom.Op o ~ nnf L$~ - Penetration and Metal Loss (°~ wall) metal loss body enetration body tf11A _ p 200 150 100 50 0 `~" 0 to 1 to 40 to 10 to 20°to 85% over 85% 10% 1% 20% 40 /° ' 1 ~ 19 8 ed tO 2S Dints ana52 Number of 9 0 gene. ~ 164 2 0 0 0 loss 5 Da ge Configuration (body ) 150 100 51 ~_ 0 118 0 - PDS Repot Overview Body Region Analysis pate: March 2, 2009 Survey UW MFC 24 No. 218183 Tool Type 1.69 Tool Size: 24 No. of Fingers: C. ~/tlaldro Ana st: Upper len. Lower ., __ in Nom. Upset ~ ~ ,~~ 6.0 ins Damage Profile (°~ wall) -, metal loss body 100 _ penetration bodyn 50 0 4 0 GLM 1 Bottom of Survey ~ 182 Analysis Overview page 2 v isolated 8eneral line '~~~° iblehole corrosion corrosion corrosion pitting PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: ~ LATI O N SHEET 1 D•128 Kuparuk ConocoPhillips Alaska, Inc USA March 2, 2009 Joint No. Jt. Depth (Ft.) Pc~n. Uln~~t (Ins.) Pen. Body (Ins.} Pen. % titetal Loss °;~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 37 0 0.01 ~' U 2.93 P P 1 U 0.02 9 1 2.90 1.1 72 tt 0.0 7 n 2.93 PUP 1 82 t~ .0 9 S 2.93 P P 85 0 .02 9 I 2.94 3 117 U 0.0 9 1 .9 4 148 U 0.01 .5 I 92 Sli ht buc in . 5 180 0 0.0 1 ~ I 2.92 6 11 0 0 03 13 5 2 96 li ht bucklin . 7 243 (t 0.03 11 S 2.94 8 2 5 u 0.02 ti ' .9 9 07 0 0.02 is I 2.9 10 38 0 0.02 ~) E~ 2.90 Sli ht buc lin 11 370 t~ 0.0 1 U I 2.9 Sli ht buckii 12 402 (I 0. 11 t~ 2.93 43 t) 0.03 11 1 2.96 Sli bucklin . 14 465 tt 0. 3 1.3 ~ .96 Sli ht buc in . 1 496 U 0.02 £3 5 2.95 1 5 8 tl 0.03 1; s .9 17 60 t I 0 03 12 1 2.93 18 591 0 04 14 ~ .95 19 3 t t 0.04 1 f3 -1 2.95 20 6 4 ll 0.05 1 J 6 2.95 li t buckli 21 686 a 0.03 13 5 2.96 1 0 3 13 5 .96 23 750 n 0.03 11 2 2.94 24 82 t ~ 0 03 12 _' 4 Sli t uc in . 25 813 tt 0.03 13 d 2.95 Sli htbucklin . 26 45 0 0.03 1;S 5 2.92 li htb in . 27 876 0 0.03 12 5 2.96 8 908 U 0. 3 11 I 2.93 29 940 t) 0.04 1 7 (, 2.96 Sli ht buckli 30 97 0 0.04 14 5 2.94 Sli ht bu lin . 31 1003 0 0.03 10 I 2.94 Sli ht Bucklin 3 1 35 a 0.04 14 1 .92 33 1066 ~~+ 0.04 I t3 t3 2.95 Sli ht Bucklin . 4 1098 t ~ 0.04 17 (~ .93 35 1129 +~ 0.04 t' U 2.96 36 1161 t+ 0.03 12 6 2.91 SI' buc 37 1193 U 0.03 10 1 2.91 38 12 0 0.0 ~~ I 2.94 39 1256 U 0.02 6 2.95 40 1288 U .02 8 -t .92 41 1319 U 0.02 9 .' 2.94 Bucklin . 1351 U 0. 2 t _' 2.9 ucklin . 43 1382 a 0.03 Lt ~ 2.91 44 1 14 +~ 0.03 1., 1 2.90 uc lin . 45 1446 t ~ 0.02 ti I 2.91 46 14 7 t ~ .04 1 5 - .9 47 1509 U p.02 i f 2.93 Bucklin . Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 1 D•128 Kuparuk ConocoPhillips Alaska, Inc. USA March 2, 2009 Joint No. Jt. Depth (Ft.) I'~~n. t ll„r~i (In..) Pen. Body (Ins.) Pen. % ~tc~t~~l I cri "4, Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1541 t J 0. 4 14 .92 49 1 7 U 0.04 15 I 2.92 ucklin 0 1604 U 0. 3 13 ~ 2.93 B cklin . 51 1635 U 0.04 17 2.93 52 1667 a 0.0 17 c, 2.92 53 1699 O 0.05 18 .91 54 1730 t J 0.04 17 ~ 2.92 Bucklin . 55 176 t ~ 0.05 19 2.91 Bucklin . 56 1793 a .05 18 2.93 57 1825 ! ~ 0.06 22 i, 2.9 Isolated ittin . 58 18 7 u 0.0 2U 1 2.91 Buckli 59 188 U 0.08 33 2 2.91 I lated itti 60 1920 U 0.02 ~ I 2.91 61 1952 U .06 22 4 2.90 ola e i 'n . 62 1984 t J 0.04 1 i (, .91 B ck in . 63 2015 tJ 0.06 25 t> 2.91 Isolated ittin . 64 2047 U 0.06 ~: 2.93 Isolated ittin . 6 078 U 0 06 24 ~' 3 Is I ted ittin . 66 110 U 0.06 22 (i 2. 1 I I t d it ~n . B cklin . 67 2140 tJ 006 23 I 1 late ' ti 68 217 a 0.05 20 t9 .93 Isolated i tin 6 2203 U 0.10 39 2.94 L' e f its 70 234 a 0.09 35 8 2.93 ~ne o its. Bucklin . 71 2266 U 0.07 27 ? 2.93 Line of its. 72 O 0.0 36 .92 'n f 73 2329 ll.l)t3 0.05 20 _' 2.91 Line of its. 74 3 0 O 0 9 34 ? .93 ine f its Buckli 75 2389 U 0.05 21 _' 2.93 Line of its. 76 422 a 0.05 19 77 2453 n 0.06 22 b 2.95 Line of its. 78 485 t) 0.05 0 b 2.93 cklin . 79 2516 i) 0.04 17 7 2.92 80 548 U 0.03 l a 1 2.91 81 2579 tl 0.07 28 (~ 2.93 Isolated itti 8 2611 (1 0.1 4V 7 2.93 Isolated ittin .Buckli 83 2643 t~ 0.04 14 2.94 84 2674 ~ J 0. 4 1 £3 6 2.92 85 2706 t~ 0.06 2~' 2.91 Line of its. 86 2737 a 0. 5 2 I 2.91 L' e of i Buc i 87 2769 U 0.09 35 _' 2.90 Line of its. 88 2801 t) 0.09 37 ; .9 Line f its. 89 2833 tJ 0.13 5l) i 2.94 Line of its. 0 2864 U 0.1 49 ~~ 2.91 ine of its. Buc lin . 91 2896 u. I I 0.07 28 7 2.92 Line of its. 92 292 U 0.11 ~ t 6 2.9 Line f its. 93 2959 t) 0.14 53 (> 2.90 Line of its. 94 2991 ~ ~ 0.10 41 ~ 2.92 Line f BucMin . 95 3023 tJ 0.09 35 ~ 2.92 Line of its. 96 3054 O 0.10 38 2.93 L~ne of 97 3086 U 0.12 46 2.93 Line of its. Penetration Body Metal Loss Body Page 2 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEEP 1 a12s Kuparuk ConocoPhillips Alaska, Inc. USA March 2, 2009 joint No. Jt. Depth (Ft.) I'en. (-ltx~~t (Ins.) Pen. Body (Ins.) Pen. °/> ~1et.il Loss ",~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 98 3118 t) 0.10 41 I tl 2.96 Line of its. BucMin . 99 3149 t) 0.08 3 "3 2. Li of i 100 3181 t) 0.1 56 (> 2.9 ine of i 0 321 f) 0.10 ~t9 3 2.95 L'ne of its. 0 344 t) 0.03 1 3 I 2.92 Bu lin . 10 327 0 0.12 4b ; 2.92 Line of its. 104 3307 U 0.13 5 i t~ 2.92 ine of its. 105 33 8 U 0.11 45 .9 Line of its. 106 8 O 0.09 34 7 2.91 ine of i 107 3399 C) 0.16 62 b 2.9 ine of its. Bucklin . 432 U.t)7 0. 0 41 -} .91 Lin of its. 109 3463 U 0 09 3G 4 .94 ine of i 110 3495 ~) 0.10 a~) ~) .95 Line of its. 111 526 ~) 0.10 41 4 2 9 Line f its. Bu in . 112 3558 U 0.12 X17 't 2. 1 Line of its. 113 3589 U 0.1 5O 2.93 Line f its. 114 3621 U 0.14 54 (~ 2.96 Line of its. 11 3653 l) 0.15 59 ~) 2.92 Line f its. Bu in 116 368 ~) 0.11 45 4 7 L'ne of its. 117 3716 0 .14 55 7 1 i of i 118 3748 U 0.11 42 7 .94 i of its. 19 3779 U.U~) 0.12 49 ~) .91 Line of its. uckl'n . 120 3811 t~ 0.17 65 l U .93 Line of its. 121 3842 O 0.14 >7 t, 2.93 Line of its. 1 874 U .1 ~t~ -1 .97 Lin f ~ts 123 3905 tt 0.16 r, , 'i 2.91 Line of its. Bucklin . 124 3937 t) 0.11 -14 f3 2.92 Line o i 125 3969 0 0.10 4I 4 2.90 _ Line of its. 1 6 4001 U 0.14 5b ti 2.91 i e o its 127 4030 U 0.16 b5 1 u 2.92 Line of its. Bucklin . 128 4062 t) .16 i,2 ~ .93 Line of its. 129 4094 t) 0.14 54 (, 2.92 Line of its. 130 4125 U 0.17 (~~ (~ 2.91 Line of its. 131 4157 U 0.14 54 ~ 2.91 Lin of its. Bucklin . 13 4189 (~ 0.15 5v 5 2.92 ine o i - 133 4220 t~ 0.12 4(~ `> 2.92 Line of its. 134 4252 a 0.1 49 - .9 ine of i - 135 4283 t~ 0.11 44 t~ 2.92 Line of its. Bucklin - 1 6 4315 O.OS 0.12 49 ~ 2.91 'n of its. 137 4347 (? 0.14 57 -1 2.91 Line of its. - 138 438 O .14 .54 4 0 e of its. 139 4412 t) 0.14 55 (> 2.90 Line of its. Bucklin . 1 4443 0 0.13 51 ~) 2.92 Li of i 141 4475 t) 0.12 X17 t3 2.92 Line of its. 42 4506 O 0.12 ~i7 is 2.95 ine f i 143 4538 u.t)5 0.11 ~l5 r~, 2.93 Line of its. B cklin . 144 4570 O 0.12 Ott 2.91 Line o its. 145 4601 r) 0.14 5.~ r,, 2.92 Line of its. 146 4 33 t) .17 (,7 I t ~ 93 Line of its. 147 4665 r) 0.12 4ti ~ ~ 2.90 Line of its. Bucklin . Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • ELATION SHEET 1 D-128 Kuparuk ConocoPhillips Alaska, Inc USA March 2, 2009 Joint No. Jt. Depth {Ft.) I'~~n. UI»~~i (In,.) Pen. Body (Ins.) Nc~n. °/~ Mct,il log, °~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 1 4696 t) 013 5Z IU 2.90 Line of i . 14 4728 c) 0 14 54 5 2.9 Line of its. 1 0 4760 a 0.13 5U 4 2.93 i f its. 151 4792 U 0.14 is (, 2.91 i e f i B cklin . 15 4822 O 0.12 4' ~ 2.92 ine of i 153 4853 t) .13 5u is .91 ine o its. 1 4885 t).U(, 0.12 4i 2.93 ine of its. 155 4917 U 0.12 -17 2.93 Line of its. Bucklin . 156 4 48 l) 0.13 49 ~i .92 ine of its 157 4980 a 0.1 4th 4 2.89 Line of i 158 012 U 014 54 5 .92 Lin of its. 1 9 5043 U 0.14 5(~ b 2.91 Li of i ucklin . 1 0 50 4 ~) 0 15 5F~ I t) 2 91 Line of its. 161 5106 a 0.14 57 ' ~ 2.9 Line of its. 1 137 tt 0.14 5~ 'i 2. 3 'ne of its. 1 3 5169 t) 0.1 b4 I I 2.93 Line of its. Buc in . 1 4 5200 U 0.14 5I ') .9 Line of its. 165 5232 U.It) 0.18 72 ~ 2.93 Line f its. 16 52 3 0 0.13 5.3 `"> 2.8 Line of i 167 295 U .1 > i 1 i e of its. uc in . 168 5326 l) 0.20 7~3 '> 2.91 L~ne f i 69 5357 U 0.13 5O ~ 2.91 Line of its. 170 5389 U 0.18 69 (~ 2.91 ~ne f its. 171 5420 t) 0.17 6~~ b 2.91 Line of its. Bucklin . 52 t) 0.15 b1 5 .89 in of 173 5483 U 0.20 ; ~~ t, 2.91 Line of its. 174 5515 O.l)ff 0.18 7U 7 2.91 ine f its. 175 5547 O 0.18 71 I I 2.91 Line of its. Bucklin . 17 5578 l) 0.18 72 1 U 2.91 Li of i . 177 5610 O 0.17 67 b 2.91 Line of its. 178 5642 11.11) 17 67 (~ .91 Line of i 178.1 5673 (~ O.1S U1 !> 2.95 PUP Line of its. Bucklin . " 178. 5686 u 0 O t) N A GLM 1 atch ®7:0 178.3 5693 t) 0.12 4~ -l 2.93 PUP Li a of its. 79 5708 tt 0.17 (,'i I~) 2 Line of its. 179.1 5739 t ~ 0.03 I I 2.93 PUP Bucklin . 179. 5745 u 0 U i~ 2.81 DS-Ni le N 179.3 5747 t) 0.04 15 2.93 PUP 180 5752 11.11) 0.19 74 ') 2.92 Line of its. 180.1 5783 U 0.03 1 _' _' 2.91 PUP Bucklin . 1 57 9 u 0 U u 3.00 ak r GBH-22 LS W 12' a s 180.3 5808 t) .13 5U t, 2.90 PUP Isolated ittin . 181 5819 tLl)5 0.1 ~ 2 .91 To of 3.5" Liner. Sca ter ittin . 182 5850 t) 0.17 66 t, 2.91 Perforations. Bucklin . _ Penetration Body Metal Loss Body Page 4 r~ ~r r~ r~ r~ r^~ rr r~ r~ r~ r~ r r r r~ r~ r~ r~ r^~ ~-~u ~ PDS Report Cross Sections ~~ Well; 1D•128 Survey Date: March 2, 2009 Fief d: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA ~.\o. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 Anal st: C. Waldro Cross Section for Joint 173 at depth 5507.854 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wail area = 95 Tool deviation = 35 ° Finger 2 Penetration = 0.201 ins Line of pits 0.20 ins = 79% Wall Penetration HIGH SIDE = UP LJ C J Cross Sections page 1 ~~ `cam PDS Report Cross Sections Well: 1D-128 Survey Date: March 2, 2009 Field: Kuparuk Tool Type: UW MFC 24 No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 Analyst: C. Waldron Cross Section for Joint 168 at depth 5333.043 ft Toof speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 92 Tool deviation = 45 ° Finger 3 Penetration = 0.197 ins Line of pits 0.20 ins = 78% Wall Penetration HIGH SIDE = UP i • Cross Sections page 2 i~D-128 Comparison to Previ~ MTT Log Overlay March 2, 2009, October 7, 2007 and December 29, 2006 PNOAGiWE ~VIQNQSi~C SERVICES, ~14G. Database File: d:lwarriorldatal1d-1281comp2.db Dataset Pathname: comp Presentation Format: 24COMP-1 Dataset Creation: Mon Oct 1519:11:03 2007 Charted by: Depth in Feet scaled 1:150 -40 Deta Metal Thickness 2007 (10 Hz) (%) 40 -40 Deta Metal Thickness 2006 (10 Hz) {%) 40 -40 Delta Metal Thickness 2009 (5Hz) (%} 40 -40 Delta Metal Thickness 2009 (10 Hz) {%) 40 0 Delta Metal Thickness Metal 20 Delta Metal Thickness 2009 (10 40 60 Metal Thickness 2006 (10 Hz} of 80 100 120 140 160 180 Delta Metal Thickness) 20016 (10 T ~T rT a Metal Thickness 2007 (10 Hz) 200 Thickness 220 -40 Detta Metal Thickness 2007 (10 Hz) (%) -40 Detta Metal Thickness 2006 (10 Hz) (%) -40 Delta Metal Thickness 2009 (5Hz) (%} -40 Dena Metal Thickness 2009 (10 Hz) (%) 40 40 1 D-,B Recorded Magnetic Thickr~s Log Data - 10Hz Pass - ~s~~~e ~o u,~ a~~ P~,wE n~w~+as.rc sE~B, ~~. (Surface to 221'} March 2, 2009 Database File: 1d-128.db Dataset Pathname: 10up.1 Presentation Format: 2.6scale Dataset Creation: Tue Mar 03 09:53:101009 by Calc Warrior 7.0 STD Cas Charted by: Depth in Feet scaled 1:150 -50 Delta Metal Thickness (%) 50 2.6 MTTP01 (rad) 12.6 0 Line Speed (ft/min) -200 -6.2 MTTP12 (rad) 3.8 Tree (Not Picturl d) 3.5" Collar 5" 10 Metal Loss ~ 1 20 Metal Loss 4% Metal Loss 30 „ .. 3.5" Collar Pup Jt. 5" Collar 40 3.5" Collar~~ ..5" Collar Metal Loss 50 Jt. 2 60 70 -~---I 80 5" Collar Jt. 3 90 00 5" Collar 110 --}-j 120 5"" }C-of-I~ar Jt 4 130 5" 150 Jt. 5 160 5" Collar 3.5" 180 Jt. 6 190 u~ia~ 200 5" Collar 210 etal Thickness Jt. 7 220 Delta Metal Thickness (%} 50 2.6 MTTP01 (rad) 12.6 Line Speed (ftlrnin) -200 -6.2 MTTP12 (rah) 3.8 CASING I TUBING 1 LINER DETAIL Tu ita Dsscrla#ron ARCO Alaska, Inc. WELL: iD-'128 DATE: 814!98 i AF 1 PAGES ouus~u'aiy w s # ITEMS a~w.u,. ..w ................~,~..~ COMPLETE DESCR1PT1ON OF EQUIPMENT RUN _ RKB #o Tobin Head Flan a LENGTH _ 39.33 DEPTH TOPS 1 't u "t u 't 177 'ts u 't Vetco Han er &Tobin F'u Jt. 3.5" 9.3# L-80 EUE 8rd Mod T 3.5" 9.3# L-BO EUE 8rd Mod T Pu Jt. 3.5° 9.3# L-80 EUE 8rd Mod 3.5" 9.3# L-8(1 EUE 8rd Mod Tb 3.5" 9.3# L-80 EUE $rd Mod T ~ Cameo 3.5" x i" KGB-2-9 Mandrel w1DV & Latch 2.901D 4.725 JD 2.65 31.64 g•~ 2.25 5586.83 14.65 6.51 39.33 41.98 73.62 83.46 85.71 5672.54 5687.19 u 't 1 't u 3.5' 9.3# L~80 EUE 8rd Mod 3.5" 9.3# L-80 EUE 8rd Mad T _ 3.5" 9.3# L-80 EUE 8rd Mod T Cameo 3.5" "DS" Ni w! 2.812" No Go Prafiie 4.5513 DD 14.18 31.13 6.10 1.22 5693.SD 5707.98 _ 5739.11 5745.21 u 1 "t 't 3,5" 9.3# L-8U EUE 8rtl Mod 3.5" 9.3# L-80 EUE 8rd Mod T 3.5" 9.3# L-80 EUE 8rd Mod T 6.15 30.57 6.15 5745,43 5752.58 5783.15 5 ace out Baker 3.5°'G13H22' Locator Sea! Ass . W/ 12' seats 3" tD x 4" UD 1.130 .83 5789.30 5790.30 To ofi SBE =__»> 5791.13 1 D 'ts left out #181 thru #190 Remarks Strin Wei hts with Blocks: ??K# U , ??iC# Dn $K# Blocks. t .an ??? joints of tubin a~. Drifted tubing GLMs 8~ han~e er with 2.867" plas#lc rabbit. Used Arctic G+':~de APt Madifisd No Lead thread t:amtwund on all c~nnec~ions. Tubing is rton-coatexi. Parker ~ #245 Drr7lin Supervisor. Fred Herbert • • IfV~Lo~ L~~ TR~4/1/,~11~fTTAL ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) f59-5102 ~~~~~ N~~' ~ ~ 207 RE : Cased Hole/Open Hofe/Mechanical Logs and/or Tubing Inspection(Caliper j MTT) The technical data fisted below is being submitted herewrd,. lease acknowledge receipt by returning a signed copy of this transm"rttal letter to the following BP Exploration (Alaska), Inc. PPxrotechnical Data Center Attn: Andy Farmer LR2 -1 900 E. Benson Bhvd. Anchorage, Alaska 99508 and (~~li `q~'-c~ao~ PrbActive Diagnostuc Services,. Inc.. ~~ C ! q `?~ - ! 33 Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907j 245-8951 1 ] MTT O6-0ct-07 1 D~119 1 Report 50-029-22836-00 2~ MTT 07-0ctr07 1 D-128 1 Report _ ' 50-D2~-229~~D0 Signed : ~~ Print Name: ~~_.LY ~r" ~^ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245.88952 E-MAIL: ~clsas~c~y~~a:~~s-r~ra>ca~~~~~.~3~"i WEBSRE:•rv+~rr~.c~rr~~~~:t!®~.r~r~ D:~SVtaster Copy_00_pD5ANG20~adZ_Wotd\Distci6utionlTransatida!_ShxfslTtazmmit_Otiginal_New.doc • Memory Magnetic Thickness Tool Log Results Sumrn~ry Company: ConocoPhittips Alaska, Inc. Weft: 1D-128 log Date: October ?, 2007 Field: Kuparuk Log No.: 8640 State: Alaska Run No.: 2 API No.: 50-029-22800-00 Pipet Desc.: 3.5" 9.3 Ib L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvt.: 192 Ft. (MDj Pipet Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log intvt.: Surface Pipet Use: Production Casing Bot. Log Intvl.; 192 Ft. {MDj Pipe3 Desc.: 16" 62.581b. H-40 Welded Top Log Intvl.: Surface Pi e3 Use: Conductor Pipe Bot. Log lntvl.: 121 Ft. (MDj inspection Type : Assess Changes in Corrosive Damage (Metal Loss} to Production Casing. COMMENTS: This MTT data is tied into the Mandrel Hanger @ 0' Depth. This is the second log of this welt with the 12 Arm Magnetic Thickness Tool {MTTj. The Magnetic Thickness Tool responds to the total thickness of meta{ of the 3.5" tubing and 5.5° production casing, with some influence from the 16" conductor pipe. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in meta! surrounding the tool, but not distinguishing in which pipe string the change in meta{ thickness occurs. In this log, the MTT was calibrated down hole (57'), where the readings are assumed to represent undamaged tubing and casing. AI{ other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. COMPARISON TO PREV,~IOU_S MTT LOE3 RESULTS A comparison between the current log and the previous (December 29, 2006) indicates a slight increase in metal foss over the interval from 12' to 1 T and 34' to 36' as recorded by the MTT. A log plot overlay of the average metal thicknesses recorded by the MTT for the current and previous log fs included in this report. The indication of tens metal below the conductor in this log compared to the previous appears to be a calibration feature ra#her than metal loss. INTERPRETATION OF ,fi,JfTT LOG SULTS : The MTT log results cover the interval ftom surface to 192`. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%j curve in these plots refers to total metal surrounding the MTT toot. A maximum 13% circumferentia[ meta! loss is recorded in the interval between 10' -17'. A 12% circumferential metal loss is recorded in the interval between 33' - 37'. A 4°l6 circumferential metal loss is recorded in the intervals between 22' - 26', 28' - 31' and 46'-52'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5" and 16" pipe. l# at4 of the metal loss is specflc to the 5.5" production casing, the percent metal loss from that pipe a{one is probably higher than the numbers expressed. Some of the metal foss indicated could be from either the 3.5" tubing or 16" conductor. Field Engineer: K Miller Analyst: M. Lawrence & J. Burton Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O, Bax 1369, Sta~fard, TX 7,'497 Phone: (2S1) ar (&88~ 56S-90S5 Fax: (281) 565-1369 E-mail: PDS~memoryiog.com Prudhoe Bay Field (J~fice Phone: (907} 659-2307 Fax: (907) 659-2314 ~~ r ~ -~33 Comparison to Previou~TT Log Qverlay October 7, 2007 and December 29, 2006 ~Gi~VE aIYgNO67~C $ERV{CQ ANC. Database File: d:lwarriorldatal1d-1281comp.db Dataset Pathname: comp Presentation Format: 2.4 comp Dataset Creation: Mon Oct 1519:11:03 2007 Charted by: Depth in Feet scaled 1:150 -50Delta Metal Thickness 2007 (%) 50 -50Delta Metal Thickness 2006 (%) 50 Delta Metal Thickness -I--1 0 Metal Thickness 10 20 30 40 50 60 70 80 90 100 110 120 130 140 150 160 170 180 190 Metal Thickness 2007 (%) 50 Metal Thickness 2006 (%} 50 ii i~ ii ii ii ii ~uu ~~ 110 3.~' Collar 120 " 3.5 _ 5.5" Co llar ~ ~, , _ Jt. 4 _ ~.. 130 !•.~ ~~~ i 3.5" Collar 4 150 3.5" Jt. 5 160 5" Co llar . - - - , - -- - ` 170 ~~ I " -" -" 3.5 Collar -- -- - - 180 _~, - 3.:i' I L Jt. 6 ' 190 ~ i 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%} 50 -6.6 MTTP12 (rad) 3.4 Magnetic Thickness I (10 HZ Log} ~' October 7, 2007 Pwo^crlre D1~grgsrlc Siwdcg Mc. Database File: d:lwarriorldatal1d-12811d-128.db Dataset Pathname: 10hz.1 Presentation Format: 2.2 scale Dataset Creation: Mon Oct 1518:53:13 2007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:50 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%} 50 -ti.6 MTTP12 (rad) 3.4 Tree (Not Pictured) 3.5" Coll ar 0 Pu p Jt (No t Pi ctur ed 5.5 " Co llar ~ i r _f- .z l i D elta Me tal T hickness Lin e Sp ee 10 r-~ 13 % M etal Los s 7 3.5" Jt.1 c"- ~ 0 ~ _ ~ ~ --- I ~ <S L_ c~' 4% Met al L oss 4% Met al L oss 30 ~~ 3.5" __ . tal Loss Pup Jt. 5.5" Clollarl -~H 40 3.5" Collar~~ I _ ~ Pup Jt 3.5" Collar -~1-~ 4% Metal Loss 50 60 3.5" Jt. 2 70 LSPD (tymin) 100 ~.2 MTTP01 (rad) 12. Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3. . . Conocói'hillips 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 7th Avenue, Suite 100 Anchorage, AK 99501 SCA."lNED JUL 1 1 20D7 ~-,\33 \0\ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells fÌ'om 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 fÌ'om 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. ;;~ Mœ{ 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 PTD# cement pumped cement date inhibitor sealant date ft bbls ft oaf 1 D-09 198-065 23" na 5 6/9/2007 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 6/9/2007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/912007 10-107 200-177 2" na 3.2 6/912007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/912007 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 6/9/2007 10-118 197-229 2" na 1 6/912007 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 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/9/2007 10-128 198-133 2" na 1 6/912007 10-129 197-213 2" na 1 6/912007 10-130 197-183 23" na 5 6/912007 Kuparuk Field June 9,2007 . . WELL LOG TRANSMITTAL - , ~.~ ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 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 Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 Report 1 Report 1 D - 128 1C - 190 MTT Log MTT Log 1!.r29-0ec.fJ6 VIe- let'\< - t"3~ 30-Dec-06 u:r.Œ.. ,.gO'"3 -ðOS 5CANNED JAN 0 8 2007 Signed: ~}L êhr ì:<.ftIM? fÎ//D. L1uV-P/1/1 Date Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: ~-'.".: -' .0 .... ." -::.:¡ : ~ .:'. : J. '..:.' , WEBSITE ; }. ~-=,. - ,~- 0 .,. ~,;, D:\OO_PDSANC-200CI\Z _ 'WT ord\Distribution\ Transmittal ,_ Sheets\Transmit__Original.doc I I I I I I I I I I I I I I I I I I I . . Memory Magnetic Thickness Tool Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 1D-128 Log Date: December 29, 2006 Field: Kuparuk Log No. : 6139 State: Alaska Run No.: 1 API No.: 50-029·22900-00 Pipe1 Desc.: 3.5" 9.3 Ib L·80 EUE 8RD Top Log Intvl.: Surface Pipe1 Use: Tubing Bot. Log Intvl.: 191 Ft. (MD) Pipe2 Desc.: 5.5" 15.5 Ib L-80 BTCM Top Log Intvl.: Surface Pipe2 Use: Production Casing Bot. Log I ntvl.: 191 Ft. (MD) Pipe3 Desc.: 16" 62.58 lb. H-40 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 121 Ft. (MD) Inspection Type: Assess External Corrosive Damage (Metal Loss) to Production Casing. COMMENTS: This MTT data is tied into the Mandrel 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 thickness of metal ofthe 3.5" tubing and 5.5" production casing, with some influence from the 16" conductor pipe. 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 MTT was calibrated down hole (60'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 3.5" tubing, 5.5" casing, and 16" conductor pipe. INTERPRETATION OF MTT LOG RESULTS: The MTT log results cover the interval from surface to 191'. A log plot of the entire pass, plus a detailed section of any interval showing damage is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool. A maximum 10% circumferential metal loss is recorded in the interval between 10' . 17'. A 8% circumferential metal loss is recorded in the interval between 33' - 37'. A 3% circumferential metal loss is recorded in the intervals between 28' - 31' and 46'·52'. A 2% circumferential metal loss is recorded in the intervals between 22' - 26'. The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5",5.5" and 16" pipe. If all of the metal loss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some ofthe metal loss indicated could be from either the 3.5" tubing or 16" conductor. I Field Engineer: D. Cain Witness: C. Kenedey I Analyst: M. Tahtouh & J. Burton ProÁ.cthle Diagnostic Services F'hone: (281) or (888) 565-9085 Fax: Prudhoe Bay Field Office Pilone: P,(} Box 1369, Stafford. T>( 77497' 565-1369 E-rna¡l: PDs@rnemory'0e1::CEIVED 659,2307 Fax: (907) 659-2314 B"'t:. JAN 0 9 2007 UTC- JC:;1f - 133 o\Iaska 0i1 & Gas Cons. eommission Anchorage I I I I I I I I I I I I I cIrk Magnetic Thickness (10 HZ Log) F'noÁCrivE DIAqNOsdc SERvicES, INC. Database File: d \warrior\data \1 d-128\ 1 d-128. db Dataset Pathname: 10HLog.1 Presentation Format: 2.2 scale Dataset Creation: Tue Jan 0212:05:302007 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1150 . - 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Meta! Thickness (%) 50 -6,6 MTTP12 (rad) 3.4 -~ -20 < ~ ! 1 .j;, I < 1= II -10 - Tree I 1 I-- ] I ==:. Hanger I-- -5.5" Colla Pup Jt IT -","" 3.5" Collar ~~~--- -....-..- -.. .--. , :::: r- I ~ t r1 I 10 ../'" 1:::-10% Meta! Loss_ 'P 3.5" , ::; \1 Ji. 1 .. I 20 ~ ~ - ....-- - -- e--.. 1--·· ¡ 20/¡ M~tal TOSS -.-- -- .- -[- -- ~ I I I - 30 - 3.5" Collar' 3% M~tal ~oss ~ ! T r W'~ ( 8% Metal Lo~s- ......... , 1 Pup Jt Z _"I 1_ ~ -~--- -. . t ':::J.J' Collar 40 I T-' Pup Jt 35"C . -( ;:: ~3.5" hOllar- ¿ 1 3% Metal Loss 50 <-.. ( 3.5" } ~ Jt 2 '- b- -. \ ¡..._. < 60 - ~ - -- - -- ~¡¡... ~ ~ - - I --- - 1:1 70 - - - _Bottom of 16' 3.5" Collar ¡ ¡ it .. -rConduGtor+ --f-'+ ¡- . I 1 1 I .":'1 T-;:!í'T ¡;f I :::Jiii ! <I IJi· 1 ~ I ~ I I I I I I I I I I I I I I I I I I I I I I I I I I II'~-.I 80 ~.~~ "'h,. I ft <... <...." -~ - , 5.5" Collar - '-- 90 I . 3.5" .". "i I ':;¡:I . .- Jt 3 I 100 ~ - -- 1 --- .. 110 3.5" Collar ~ ----~ ¡Ir' e ~ 120 - ..... ~.5" Collar 3.5" ¿ -;.;:; r - ..- Jt. 4 -- ----- -- - '.. I 130 -..-...- 1-· ..._-...... 'J I ...... -- <I I ~ j ~Ollar 140 ~ I I-- I-- ~ " Ì1 - I--- 1(' 150 r\ ~ , ,--.-.. ( e-.-- i 3.5" .-... 3tj -e-.-- ~--- ) Jt. 5 '-I--- ~mw'^ ) . + -1--... \ I 160 ~I--- '> IS"COllar è , ~.:'" <: t;:: ...:::. - 11 "". :( 1 - ~ ""'æ " ~ r:'-¡ 170 ~ ...-..- - I'-- .;¡ j 35" Collar ~ - ~ ( I - -- - ~ 180 . - - .~ 3.5" - - Jt. 6 - - 1an 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 ·50 Delta Metal Thickness (%) 50 ·6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I £ ÞS. Magnetic Thickness (10HZ Log) PnoAcrivE DIAqN05Jic SERvicES, INC. Database File: d\warrior\data\1d-128 top 20\1d-128.db Dataset Pathname: 10HLog.1 Presentation Format 2.2 scale Dataset Creation: Tue Jan 02 12:05:302007 by Calc Sondex Warrior VTO Charted by: Depth in Feet soaled 150 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 I Tree ! Hanger I , ¡¡ Pup Jt -.. - ----+-- -~ (' .. ').- 5.5" Collar - ,;3.5" Collar "::::'1> [Y ." ? ",- .,' -" /f (2 - ~ f- "' '[; .~, "Yo ~ < - '" ~ 1, j '" r~ :" - ...-.. ......... ------- ---- -;"2 I c . ';,> I~ 1'1 , ..¿ ~ I 10 1 ~ 1'1 -J 1;1 I I,/~ !). I~ / I .;/ ./ ¿ ) ) IJ , I ~ )' ¡. .~" ~1 )::. ~ , ~{ I ~ I-+- 10% Metal > ¿ ( ~\ ~< ~ \, ~ ~\: "' .~\; 'S <~\ "<\ ~:~ 1'\. ~ 3.5" \ \ r:. '1 I I Jt 1 '" .11# ~ c, \ ~ l¡> .~~ I I Š Line Speedi ,r+" ::~. ., " .< < I ?- ¿ 1="; 20 ;> "'" I c=: : e~ I I_ I , ,.> d '1 / I I I ~ II '" ~> p þ "" :: :> I ~'I ~ , ¡ ;, I')", >, 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thiokness (%) 50 -6.6 MTTP12 (rad) 3.4 I I I I I I I I I I I I I I I I I I I <!a~. Magnetic Thickness (10 HZ Log) P'ROÁc"fivE DIAq""""ic SERvlcE5, INC. - Database File: d\warrior\data\1d-12825'-55'\1d-128.db Dataset Pathname: 10HLog.1 Presentation Format: 2.2 scale Dataset Creation: Tue Jan 0212:05:30 2007 by Calc Sondex Warrior VTO Charted by: Depth in Feet scaled 160 .. 122 0 LSPD (ftlmin) -100 2.2 MTTP01 (rad) -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 3.4 ( LV U ~ ;;..- ..- -- ~ I ~ I "' ~, 1 I ~ { , ~ 3.5" I I I 2% Metal Loss c "' ¿ .::; < '" I Jt 1 "- Line Spee< ~ \1 )1 '¡ I... ~ < ¡~ . r3% Metal Loss 30 "" " ~ ~ , ? ~ ¡,. ___1 I "r ~ ~ <.., ~ I-H - :~ ( ~:;. ~ -----:3.5" Colla --- , ( .......... _ [,#.1/' ---'--f-- \ \ l" 'I,. t,_ \ ~ I ' '\ [\;> \ \ ' I ~ \:::;:, , I '::¡.. r\ I 1 Pup Jt . 1. J'r";~ ~ t '\'" \ î., j I Ì> C) \ ~ '; I ). I ~ t~I\' ):. " r> " ); .. I-- 5.5" Collar =- >- · foY" f> % .L I r I 40 I? ~ I 3.5" Collar I Pup Jt. ( '-: 'f' ' - ~ ~ . 3.5" Collar ,- '-l , I ~ ~ ;, ;C. 2 ~. ~. \. ( , I ~¡,. ì 3% Metal Loss 50 ~ ; , I , ..L f---..... \... ,'" (ì I 3.5" I I ;~. (I Jt 2 ¡, I I á'LI !~ I I ~.,~ .I-I_- a LSPD (ftlmin) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%) 50 -6.6 MTTP12 (rad) 34 I I . .. " . KRU 1 D-128 ,um '" " API: 500292290000 WellT\It)e: INJ Imil de;;ï5) SSSV Tvoe: NONE OrlO ComOietion: 8/6/1998 D: 19 dea /fi)6580 Annular Fluid: 3% KCI 8.7 000 Last W /0 n: PULL WRP Refer. Ref Lon Date: Last UDdate: 7/2212006 Last 459 TD: 6580 ftKB Last Tan /13/2006 Max Hole Anale: 68 dea I1J) 1843 PRODUCTION ·...,..AI..L . Wi;5jj(ji Descrintion Size Ton Bottom TVD wt Grade Thread Gas Lift CONDUCTOR 16.000 0 121 121 62.58 HAO WELDED Valvei PRODUCTION 5.500 0 5793 3455 15.00 L,80 BTCM PRODUCTION 3.500 5794 6568 4179 9.30 L-80 EOË '.""" Size I Top I Bottom T TVo I wt I Grade I Thread 3.500 0 I 5790 T 3452 I 9.30 L,80 EUE Interval TVO Zone Status Ft SPF Date Tvee Comment 5866 . 5895 3522 - 3549 WSD 29 4 3/18/1999 IPERF 12.25" HCBH ","'=KC.'" 5929·5951 3581 - 3601 WSB 22 4 3/18/1999 2.25" HCBH 5974 - 5982 3623 - 3630 WSA4 8 4 3/18/1999 I 2.25" HCBH 6020 6028 3665 - 3673 WSA3 8 4 3/18/1999 1 2.25" HCBH 6038 - 6056 3682 - 3699 WSA3 18 4 3/18/1999 IPERF 225"HCBH 6062 6070 3705 - 3712 WSA3 8 4 3/18/1999 IPERF 2.25" HCBH 6091·6103 3732 - 3743 WSA2 12 4 3/18/1999 IPERF 2.25" HCBH 6117'~56'3774 \Ale; A? 19 4 IPERF '?' 'I-Ir.Rf..J GåsI"fft liD I TVD 1 ~'::' M,oTypoT V M" I V Typo 1 V DD I....'" 1 Port I TRO 1 Date Run I Vlv Cmnt ~,R7 33591 r-AMU KBG ~ r1MV 1.0 RTM 0000 aT T ~eouin. ....................... c='c,~oo, De h Tyee Description ID "üõ';;X;óí 5745 3411 NIP 'OS' NOGO. 2.812 5790 3452 SBE BAKER GBH·22 LSA W/12' SEALS 3.000 6450 4068 I PLUG Set Baker bridne "Ilinfer a PBTD. 0.000 ~=~ mo,no """~; Perf (5966-5895) -.- - - - -. - - -- - I--- Perf (5929·5951) - I------ Perf (5974-5982) -- I------ f'Bn (6020·60281 -- I--- Perf (6038..8056) - I------ Perf (6062-6070) = b Perf (6091-·6103) - --... Perf (6117-6136) - I--- _. I------ 0027(;0) I I I I I I I I I I I I I I I I MEMORANDUM . TO: J" R ----. C) /:0/ " illl egg "I<:¿:-) v! ;"'( LCD P.I. Supervisor I ( FROM: John Crisp Petroleum Inspector Well Name: KUPARUK RIV U WSAK 10-128 Insp Num: mitJCr06073 1101642 Rei Insp Num M1TOPOOOOOl280 Packer Well 1O-12S ¡Type Inj. ! W ! TVD P.T. 1981330 TypeTest I SPT ! Test psi Interval 4YRTST P/F P Notes .2 bbls pumped for test. Monobore, no OA. Wednesday, August 02, 2006 State of Alaska . Alaska Oil and Gas Conservation Commission DATE: Wednesday, August 02, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC \D-128 KUPARUK RIV U WSAK 1O-l28 ~, \ ~3 tq'O Src: Inspector Reviewed By: -r;z,Z-- P.I. Suprv _~ / Comm NON-CONFIDENTIAL API Well Number 50-029-22900-00-00 Inspector Name: John Crisp Inspection Date: 7/29/2006 Permit Number: 198-133-0 Depth 3452 ! IA L 1500 'OA / Tubing 15 Min. 30 Min. 45 Min. 60 Min. Pretest Initial --~~-- 925 1690 1670 1670 , . 575 i 600 600 600 G I'). ¡'(' "1" Page I of I MEMORANDUM e e State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .--¡ I I // /J '" . -; ~'~Î'~' 1""1'( (¡ !! C:::, ! l0 , L ( DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC 10-128 KUPARUKRIVUWSAK !D-128 \ q'ð~ \33 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv Jï3i2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV U WSAK ID-128 API Well Number 50-029-22900-00-00 Inspector Name: Jeff Jones Insp Num: miÚJ0607III754IO Permit Number: 198-133-0 Inspection Date: 7/IO/2006 ReI Insp N urn Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well I !D-l28 ¡Type Inj. I W ! TVD ! 3452 ! IA I 1780 i 1770 1760 I 1740 I ! 40 I , I' I I j --~--- I I i P.T. ! 1981330 TypeTest i SPT I Test psi ! 1500 OA , , , I I F / Tubing! , I ! Interval 4YRTST P/F 800 800 810 ! 810 800 i I Notes Monobore injector, 1.9 bbls diesel pumped. Test held additional 15 minutes & lA pressure failed to stabilize, I well house inspected; no exceptions noted, ¡/' Wednesday, July 12,2006 Page 1 of I ·.".:':.:.:.:.'.'" . ::::.:¡¡¡'.'.:::li.¡¡¡¡i.'¡,:i:: ConocoPhilUps .AI..a. S..k.. a..,...f.'.".. c...... , ' .. ',: 11D-128' . ........ I API: 500292290000 ~~i~~ SSSV Type: NONE 00:3,500, 10:2.992) °ROOUCTlON (0-5793, 00:5.500, Wt:15.00) NIP (5745-5746, 00:4.550) SSE (5790-5791, 00:4.000) °ROOUCTlON (5794-6568, 00:3.500, Wt:9.30) Perf (5866-5895) Perf (5929-5951) Perf (5974-5982) Perf (6020-6028) Perf (6038-6056) Perf (6062-6070) Perf (6091-6103) PLUG (6450-6451, 00:2,750) e e KRU 1 D-128 Descri tion 10/31/05 Schlumbepgep NO. 3513 Schlumberger -DCS 2525 Gambell Street, Suite 400 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 SCANNED NOV 2 3 2005 Attn: Helen Warman ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk '--' Well Job# Log Description Date BL Color CD 1R-16 11015756 PRODUCTION PROFILE 10/24/05 1 2X-10 11015758 PRODUCTION PROFILE 10/26/05 1 c..--" 1 D-128 11015759 INJECTION PROFILE 10/27/05 1 3J-06 11072927 SBHP SURVEY 10/30/05 1 3J-07 A 11072926 SBHP SURVEY 10/30/05 1 2Z-29 11072924 PRODUCTION PROFILE 10/28/05 1 1 A-02 11022938 INJECTION PROFILE 10/18/05 1 1 Q-26 11022937 PRODUCTION PROFILE 10/17/05 1 1G-16 11015753 INJECTION PROFILE 10/21/05 1 2A-08 11015755 INJECTION PROFILE 10/23/05 1 2G-15 11072919 PRODUCTION PROFILE 10/23/05 1 2N-329 11022935 PRODUCTION PROFILE 10/15/05 1 2Z-07 11022936 PRODUCTION PROFILE 10/16/05 1 3G-02 11056697 PRODUCTION PROFILE 09/20/05 1 2B-03A 11015749 PRODUCTION PROFILE 10/05/05 1 3N-09 (REDO) 11015722 PRODUCTION PROFILE 08/29/05 1 -- 2C-04 11022934 INJECTION PROFILE 10/14/05 1 '~M-07 (REDO) 11015737 INJECTION PROFILE 09/26/05 1 2A-01A 11072922 INJECTION PROFILE 10/26/05 1 1R-10 11015757 INJECTION PROFILE 10/25/05 1 2Z-08 11072920 INJECTION PROFILE 10/24/05 1 1 E-170 11015750 USIT 10/19/05 1 1J-154 11022931 USIT 10/12/05 1 2F-03 11015763 INJECTION PROFILE 10/31/05 1 1L1 SIGNED: DJJ DATE: I ~ (ÛmI A~l- Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. I tiff -I'l:\. MEMORANDUM TO: THRU: FROM: Chair Jim Regg P.I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission Randy Rued~n h'/r~/D3 DATE: June 20, 2003 ~I~'tl~'~SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 1-D 114, 122, 128, 132 John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I qB-q,4 IType,nj.I S I~.v.D. I~{TubingI 100 1100 1100 I,oo I,nte~va,I 4 P.T.D.I 1981590ITypetestl P I Testpsil 883 I Casingl 360 I 26201 26001 26001 P/F I u Notes: We,II qD-q22 ITypel,j.I S I ~.V.D. I~o I~u~,.~l ~,~o I,~o I,,~o I~,~o I,nterva, I 4 P.T.D.I 1981490 ITypetestl P I Testpsil 883 I Casingl POS. 1250012490124901 P/FI ~P Notes: WellI 1D-128I Type,nj.I s I T.V.D. I~ I Tu~,i,gl soo I ~oo I ~,oo I~ooI lntervall 4 P.T.D.I 1981330ITypetestl I Testpsil 863 I Casingl 80 I 25001 24901 2490 I P/F I -P Notes: WellI 1D-132 [Typelnj.[ S [ T.V.D. 13489I Tu~i.gl~35o I~o I~o I~o [Interval[ 4 P.T.D.I 1981210 ITypetestl ITestpsil 872 I Casingl POS. I 25001 24901 2490 I P/F I -P Notes: P.T.D. I Type test Notes: / , ./ Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER IN J. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details As noted in the above report all wells passed. Well houses were found to be clean and orderly. M.I.T.'s performed: 4 Number of Failures: 0 Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. ~CANNED JUL :3 ! 2003 2003-0620_M IT_KRU_ 1 D- 132is.xls 7/9/2003 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b,~ c_ 99239 CBT W/PSP/SCMT 990221 1 1C- 18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 b~. ~ ~--- 99248 SCMT 990216 1 1D-125 99249 CBT W/PSP/SCMT 990220 1 1D-114 L,~ ~ ~- 99246 CBT W/PSP/SCMT 990421 1 1D-128 99247 SCMT 990215 1 1 D- 122 ~ ~ ¢_.. 99244 CBT W/PSP/SCMT 990226 1 1D-111 b~ c. 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 ~,c f ¢_ 99242 SCMT 9901' 22 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. , !!,,,Jl',t 1 6 '199*) ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-128 (Permit No. 98-133) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-128. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~, K1(1D-128(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-128 P E R FO RATIO N S-E-LI N E 0104991643.2 DATE DAILY WORK UNIT NUMBER 03/16/99 SET BRIDGE PLUG & PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 4 NO YES SWS-J O H NSON JOH NS FIELD AFC# CC# Signed ESTIMATE AK9645 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 500 PSI 200 PSI 200 PSII 0 PSII 0 PSI DAILY SUMMARY SET BRIDGE PLUG AT 6450' RKB AND PERFORATE 6117' TO 6136' RKB[Perf] TIME LOG ENTRY 13:00 MIRU E-LINE AND HOT OIL UNIT 15:30 RIH WITH CAST IRON BRIDGE PLUG, TIE IN AND SET PLUG AT 6450' POOH 20:00 PRESSURE TEST BRIDGE PLUG TO 2500 PSI OK. 20:15 RIH WITH 19' 2.5" HALLOW CARRIER BH PERF GUNS, TIE IN AND SHOOT PERFS 6117' TO 6136' RKB. POOH 23:55 RIG DOWN, TO CONTINUE PERFS IN THE A.M. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,~' K1(1D-128(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-128 P E R FO RATIO N S-E-LI N E 0104991643.2 DATE DAILY WORK UNIT NUMBER 03/18/99 PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 NO NO SWS-ELMORE JOHNS FIELD AFC# CC# Signed ESTIMATE AK9645 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 200 PSI 200 PSI 200 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED A-2 , A-3 , A-4 SANDS , TO CONTINUE PERF JOB IN THE AM.[Perf] TIME LOG ENTRY 07:00 MIRU E-LINE UNIT. PRESSURE TEST TO 3000 PSI. 08:00 HELD ON SITE SAFETY TALK. 08:15 RIH WITH 12 FT. 2.5 HALLOW CARRIER PERF GUN. TIE IN WITH CCL AND SHOOT 4 SPF, 6091 TO 6103. POOH 10:15 RIH WITH 8 FT. GUNS AND TIE IN & SHOOT PERFS 6062 TO 6070'. POOH 12:15 RIH WITH 18 FT GUN AND TIE IN AND SHOOT PERFS 6038 TO 6056' POOH 14:15 RIH WITH 8 FT PERF GUN, TIE IN AND SHOOT PERFS 6020 TO 6028', POOH 16:15 RIH WITH 8 FT GUN AND TIE IN AND SHOOT PERFS 5974 TO 5982' POOH 18:00 RDFN ARCO Alaska. Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT ,, K1(1D-128(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-128 P E R FO RATIO N S-E-LI NE 0104991643.2 DATE DAILY WORK UNIT NUMBER 03/19/99 PERFORATE "B" & "D" SANDS DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 NOI NO SWS-ELMORE JOH NS FIELD AFC# CC# Signed ESTIMATE AK9645 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 400 PSI 400 PSI 200 PSI 200 PSII 10 PSI 0 PSI DAILY SUMMARY PERFORATED "B" SANDS AT 5929' TO 5951 AND "D" SANDS AT 5866' TO 5895'.[Perf] TIME LOG ENTRY 07:00 MIRU E-LINE 08:00 HELD JOB SITE SAFETY MEETING 08:20 RIH AND TIE IN TO PERF LOG. SHOOT 4 SPF WITH 2.5" HC GUNS AT 5929' TO 5951', POOH 10:30 RIH ANDTIE IN WITH PERF LOG. SHOOT PERFS AT 4 SPF AT 5875' TO 5895', POOH 12:40 RIH AND TIE IN WITH PERF LOG. SHOOT 4 SPF PERFS AT 5866' TO 5875' POOH. 13:45 RDMO " STATE OF ALASKA "- ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F-'[ GAS [~ SUSPENDED E~ ABANDONED~ SERVICE ~1 Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-133 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22900 4 Location of well at surface : ', .... :;;:' iii,:! ~~ 9 Unit or Lease Name 331' FNL, 599' FEL, Sec. 23, Tl1 N, R10E, UM-- i~~.;.,.. !~ "i":i"i: ' i~ Kuparuk River Unit At Top Producing Interval · 10 Well Number 2231' FSL, 1586' FWL, Sec. 23, T11 N, R10E, UM i~,..~.~ .: West Sak 1 D-128 At Total Depth ~~ 11 Field and Pool 2080' FSL, 1386' FWL, Sec. 23, T11 N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation 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.~,l '~ 115 Water Depth, if offshore 16 No. of Completions 30-Ju1-98 02-A,g-98 ~ ~//_~/~"~ ~jr(oI NA feetMSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 6580' MD & 4191' TVD 6450' MD & 4068' TVD YES M NO U NA feet MD 1518' APPROX 22 Type Electric or Other Logs Run GR/Res, CCL 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" 260 sx AS II 5.5" x 15# L-80 SURF. 5793' 8.5" 374 bbls AS III, 102 bbls Class G 3.5" 9.3# L-80 5793' 6568' 8.5" (included above) 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5866'-5895' MD 3522'-3549' TVD 4 spT 3.5" 5781' N/A 5929'-5951' MD 3581'-3601' TVD 4 spT 5974'-5982' MD 3623'-3630' TVD 4 spt 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 6020'-8028' MD 3665'-3673' TVD 4 spT DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6038'-6056' MD 3682'-3699' TVD 4 spt N/A N/A 60~2'-6070' MD 3705'-3712"[VD 4spt 6091'-6103' MD 3732'-3743' TVD 4spf 6117'-6136' MD 3756'-3774' TVD 4spT 27 PRODUCTION T.S¥ U Date First Production Method of Operation (Flowing, gas lift, etc.) Injector :i.- · Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS'OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 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 29. 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 5861' 3518' Base West Sak Sand 6319' 3945' Annulus left open ~ freeze protected with diesel. 31. LIST OF AI-I'ACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. i 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 10-407 198-133-0 KUPARUK RIV U WSAK 1D~128 50- 029-22900-00 PHILLL~S ALASK~ ~C Roll #1: Start: Stop MD 06580 TVD 04191 Roll #2: Start Stop Completion Date: /~3~/9~9 Completed Status: 1WINJ Current: T Name Interval D 878L.-'/''''~' 2 SPERRY MPT/GRJEWR4 L DGRJEWR4-MD ~'~'~AL 121-6580 L DGR/EWR4-TVD ""~"~{qNAL 121-4191 L INJP ~ 5720-6185 L SCMT ~ 5750-6460 L SCMT R SRVY CALC--r- R SRVY RPT~,''''''~' FINAL .~El~i~) 5750-6460 2/15/99 BH 121-6580. SPERRY 0-6580. OH OH OH CH CH CH OH OH Sent Received T/C/D 10/21/98 10/22/98 10/21/98 10/22/98 10/21/98 10/22/98 1/27/00 2/4/00 2/18/99 2/24/99 6/8/99 6/16/99 4/14/99 4/15/99 9/2/98 9/3/98 Wednesday, March 28, 2001 Page 1 of 1 2/18/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 All'N: Sherrie NO. 12347 Company Alaska Oil & Gas Cons Camm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Well Job # Log Description Date Blueline Sepia Print 1D-128 SCMT 990215 1 1 1D-132 SCMT 990216 I 1 1L-09 PRODUCTION PROFILE W/DEFT 990207 I 1 2H-07 PRODUCTION PROFILE 990129 I 1 2T-10 bJr,_., INJECTION PROFILE 990212 1 1 3N-11 t.,t.~ ~. INJECTION PROFILE 990211 I ] SIG~(~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: Anchorage Date: 1/7/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-128 WELL ID: AK9645 TYPE: -- AFC: AK9645 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/30/98 START COMP: RIG:RIG % 245 BLOCK: FINAL: WI: 0% SECURITY:0 AP1 NUMBER: 50-029-22900-00 07/30/98 (D1) TD: 883' (883) SUPV:CUNNINGHAM MW: 9.0 VISC: 314 PV/YP: 39/50 DRILLING 8-1/2" HOLE @ 1902 APIWL: 8.2 Move rig 105' from 1D-132 to 1D-128. Accept rig on 1D-128 @ 1230 hrs. 7/30/98. N/U diverter and function test. spud and drill 8.5" hole to 883' 07/31/98 (D2) MW: 9.6 VISC: 226 PV/YP: 41/47 APIWL: 5.6 TD: 3980' (3097) SLIP AND CUT DRILLING LINE SUPV:PENROSE/CUNNINGHAM Drill 8.5" hole from 890' to 3128'. Short trip out to 1990'. Hole tight @ 2558' and swabbing. Ream out to 2188' Trip in to bottom. Tag tight spot at 2584', ream to 2634' Tag tight spot at 2793', ream to 2846'. Drill 8.5" hole from 3128' to 3980' 08/01/98 (D3) MW: 9.6 VISC: 208 PV/YP: 35/47 APIWL: 5.0 TD: 5687' (1707) DRILLING 8-1/2" HOLE @ 6329' SUPV:PENROSE/CUNNINGHAM Ream from 3616' to 3980' Drill 8.5" hole from 3980' to 5687' 08/02/98 (D4 MW: 9.8 VISC: 300 PV/YP: 53/64 APIWL: 3.8 TD: 6580'(893) TOOH, LAY DN BHA, HOLE OPENER SUPV:PENROSE/CUNNINGHAM Drill 8.5" hole from 5687' to 6580' POH for hole opener. Attempt to swab, pull to 5876', packing off, ream out to 5782'. Ream out o[ hole from 5727' to 5064', t%ght spots 3745'-3023', 1289 -910', 450'-320'. RIH w/hole{opener, tight @ 3834' TIH, tight spots 3834'-4398', 4682'-5156', 5420'-5629' 08/03/98 (D5 MW: 9.8 VISC: 79 PV/YP: 34/29 APIWL: 4.0 TD: 6580'( 0) N/U BOPS (2ND STAGE OF CMT JOB WENT WELL.) SUPV:PENROSE/CUNNINGHAM Run 3.5" x 5.5" casing. Pump first stage cement stage. 08/04/98 (D6 TD: 6580' ( 0) SUPV:FRED HERBERT MW: 9.1 rISC: 73 PV/YP: 18/16 RUNNING 3.5" TUBING APIWL: 8.4 Cement 2nd stage. ND diverter. NU BOPE and test. Clean out cement, stage collar, wash to 2559' Date: 1/7/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 08/05/98 D7) TD: 6580' 0) SUPV:FRED HERBERT 08/06/98 D8) TD: 6580' 0) SUPV:FRED HERBERT MW: 9.1 rISC: 44 PV/YP: 11/ 8 DISPLACING WELL WITH 3% KCL BRINE APIWL: 8.0 Run 3.5" tubing. Not stung into PBR. Attempt to work into PBR. Could not work down at all. Mill on possible junk & clean out to bottom of PBR. Pump slug. MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED @ 1330 HRS FROM 1D-128 APIWL: 0.0 Run 3.5" completion string. Freeze protect well. ND BOPE. Release rig @ 1330 hrs. 8/6/98. i '" SURVEY CALCULATION AND FIELD WORKSHEET ~"'~~r~ I Job No. _0.~_5~__._997~86___ Sidetrack No. Page __ 1__ .... of 2 Company _A.R_c_o._AL~__.s_ _KA,_!.N_.C.: Rig Contractor & No..P_A_R_.K_E_R.D_.RIL__L_I_N.G,.C_ 0_ ..-_ ~_245 Field KUPARUK RIVER UNIT Well Name & No. 1 D-PAD/1D-#128/K2 W~ ............................................................... Survey Section Name Definitive Survey ...... BHI Rep. ROBBY BARNARD. WELL DATA Target TVD .................. __0~')_ ........ Target Coord. N/S ............ Slot Coord. N/S . _.-_33!_._...00_ .... Grid Correction .... 0.000 .... Depths Measured From: RKB ~ MSL~ SS~ Target Description ............. Target Coord. EAN ......... Slot Coord. EAN -599.00 Magn. Dbclination 27.430 Calculation Method MINIMUM CURVATURE Target Direction (DD1 Build\Walk\DL per: lOOft[~ 30m '- 1Omi'! Vert. Sec. Azim. 228.88 Magn. to Map Corr. 27.430 Map North to: OTHER . . _ . SURVEY DATA i Survey · Survey '= Incl. Hole Course Vertical Total Coordinate ' Build Rate Walk Rate Date ~ Tool ' Depth ! Angle i Direction Length TVD Section N(+) /S(-) :' '~(+)'/W(') DL Build (+) Right (+) Comment i Type ! (eT) . . (DD) i (DD~ (FTi (FT) (FT) ~ (FTI (Per 100 VO~ Drop 6) Left (-) ~ : 0.00 ! 0.00 0.00 0.00 0.00 0.00 '. 0.00 i 'TIE IN POINT , 30-JUL-98: MWD '. 121.00 I 0.00 : .0 0.08 0.00 ~ 0.00 0.00 ; 0.00 6 3/4"MACH 1C-AKO-1.4deg. "' 30-JUL-98 I MWDI 28965 040I 31274 16865 28965 006 040 , -043 024 0.24 30-JUL-98 MWD~ 377.13 0.45! 28001 ~ 8748 377.13 i 0.31 0.67 I -0.99 0.281 0.06 30-JUL-98t MWDI 468.37 ~ 0.59 { 277.46: 91.24 468.36 : 0.85 ......... 0.79 i ....... -1.81 ._ 0.16[ 0.15 : ................... t ............ ~ ............. f- .......... 1 ........................ i !! ............................. 5128-1 -1 .~-6' i-~ .................................... ---~.73 : .................... " ....................................... ...................... ·/ / i 230'20 i4 ................... 90.61 650.39 ; 17.66' -9.07 -15.53 6.09 ; 6.03[ -6.59 1 30-JUL-98[ MWD t 651.42 ~-10.61 1 ................... i ............. ~ ......................... ~- .................................. -I .........................................................] MWDf 744.11 ! 12.25,~/ 227.24;'~ .................... 92.69 741.24 :. 36.02 -21.21 I, -29.31 1.88i 1.77 i -3.19 i 30_JUL.98-~- -j- ................... ~ .............................................................................. ~ , ....................................................................................... .... , .... ......... ........ ........... ~qi-~'"~';-'I; 82.73 -53.36 !r ............... ......... --~3.25 6.23 ' ................. 6.23I'~ -0.011 ..............................al_JUL.Q8 MWD :'101-6-22: . ............................. 25.56 227.34!' .................................................... 90.28 1000.14 '! 1 7.35 -7 .01 8.54 6.64 6.62 ............................................................................................................. 31-JUL-98 MWD 1107.46 28.01 .... 227.31{ 91.24 1081.59 ; 158.45 -104.88[ -'[118.77 2.69! 2.69i -0.03 I 31-JUL-98 MWD 1197.77 33.25 231.40-/ 90.31 1159.28,] 204.42 -134.73 -153.73 6.24l~' 5.80; 4.53[ ........... T 9.59 / 2.68 31 -JUL-98 MWD 1288.32 41.93 233.83 90.55 12~ ~-~9-~66 -168.14 -197.64 9.72~- ~ ..................................................................... 'i -- 31-JUL-98 MWD 1379.40 47.01 231.35 91.08 1295.95 I 323.11 -206.93 -248.26 5.89 5.58 ~ -2.72 31-JUL-98 MWD 1470.34 49.81 230.02 90.94 1356-~"-"' ...... ~91108 -250.03 -300.86 3.27 -;~-~-! -1.46 31 -JUL-98 MWD 1561.08 57.14 228,95 90.74 1410.28 463.94 -297.39 -356.24 8.13 8.08 -1. lt~ , ,_ 31-JUL-98 MWD 1649.73 60.50 228.16 88.65 1456.17 539.78 -347.60 -413.07 3.87 3.79 -0.89 31 -JUL-98 MWD 1842.82 68.42 227.49 193.09 1539.35 713.83 -464.50 -542.06 4.11 4.10 -0.35 31 -JUL-98 MWD 2125.59 65.63 227.44 282.77 1649.71 974.06 -640,48 -733.88 0.99 -0.99 .0.02 31 -JUL-98 MWD 2407.49 65.88 226.99 281.90 1765.47 1230.99 ..815,07 -922.52 0.17 0.09 -0.16 31 -JUL-98 MWD 2689.40 67.11 229.43 281.91 1877.92 1489.46 -987.31 -1115.26 0.91 0.44 0.87 , , 31 -JUL-98 MWD 2978.15 65.73 230.85 288.75 1993.43 1754.02 -1156.92 -1318.38 0.66 .0.48 0.49 ~--.--,~.-.-~.- , "~ ........ 92.53 2031.52 I 1838.30 -1210.10 -1383.83 0.14 ] .0.08 } 0.13 31-JUL-98 MWD 3070.68 65.66 230.97I ,' " SURVEY CALCULATION AND FIELD WORKSHEET ~ i Job No. 0~_5~.._.9._9_._486' Sidetrack No. Page __2.___ of __~_._. Company _A.R__C~._A.._L~_.~_K~__,__I_N_C_: Rig Contractor & No. .p_A__R_K_ER__D_R!L__L_IN_G_,_C._O._-_~24.5 Field KUPARUK RIVER UNIT I Well Name & No. 1__~_ P__A_D/~I__.D-_ #__12_8./__K2- .............................. Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. WELL DATA Target TVD ........ (FT) Target Coord. N/S ................. Slot Coord. N/S ;3_3..! ...0~._ ..... Grid Correction ._ __0._.0~0__ ....... Depths Measured From: RKB ~ MSL b_~ SS~! Target Description Target Coord. E/W .... Slot Coord. E/W -~599.00 .... Magn. D'eclination 27.430 Calculation Method MINIMUM CURVATURE Target Direction (DD_) Build\Walk\DL per: lO0ftlX 3Om!- 10m;" Vert. Sec. Azim. 228.88 Magn. to Map Corr. 27.430 Map North to: OTHER . . SURVEY DATA · ,, . . Survey Survey Incl. ; Hole Course Vertical Total Coordinate Build Rate Walk Rate Date . Tool Depth . Angle i Direction : Length TVD Section N(+) / S(-) E(~) / W(-) DL Build (+) Right (+) Comment Type (F'r) . tOID) : (DD) (FT) (FT) . (Fl') (FT') (Per 100 FTI' Drop (-) ! Left (-) 31-JUL-98 ' MWD 3260.62 . 67.50 ' 230.89 189.94 2107.01 2012.47 -1319.94 -1519.14 0.97 0.97 -0.04 :6 3/4"MACH lC-AKO-1.4deg. 31-JUL-98'i MWD 3545.05 : 67.021 227.41 ' 284.43 2216.98 ! 2274.73 -1491.48 i -1717.54 1.14. -0.17 i -1.22 ......... ~ ..... ~ ....... i .... i ......... ~ .............. ~ .............. i ............................................... ...... ~, ....... t ...................... 31-JUL-98 i MWDi 3831.04 ~: 63.70 i 225.05 i 285.99 2336.21 i 2534.35 -1671.21 -1905.26 1.38 -1'.16 ! -0.83 ...... .......... i ...... ........ ............................ _2026.36 0.66 ', 0.49 0.49 01-AUG-98 ! MWD : 4019.64 64.63 ! 225.98:1 188.60 24181~,0 1 ..... ' '0i:~,'U'~':~8'! MWDi 4207.15 I 63.62i ..... ~2~i~--!-187.51 2500.24 i 2872.41 ....... ~11-~41-94-!' -2149.98 ....... i"'~'-:~ .0.54 i 1.22 0'i-:/~,U~'~'i ~I~V~'D-!' '~493.3~ ! 62.17.---2'~'~'.'50-'! 286.17 2630.62' 3127.11 ....... -:~)~-~i~6i .... '~-38-~-~ ........... ~i'~6"i-0.51 i' -0.27 1 01-AUG-98i MWDi 4779.73 62.69! 231.12 286.41 2763.22 3380.93 -2241.23; -2531.42 1.13i .... 0.18! 1.261 01-AUG-98 '~ MWO i 5063.46 i 57.26 } 228.59 ; 283.73 2905.15 ~= 3626.42 -2399.42 ! -2719.21 2.06i -1.91 -0.89 01-AUG-98i MWD :. 5157.02 i 52.71 t 230.01 i 93.56 2958.83 i 3703.02 -2449.39 ! -2777.27 5.02 ! -4 86 ~ 1.52 ' .... : ~ 4.391 i (~i :~,UG:'9~"i' '-~V~D' ;¢ 5;~0;9;~' i"'481~'0 'f ~;~;":'~;~" i ...... ~';~[~)~i .... 3018.29"-' ....... '3-~'~5~'(~'; ................ :~'; ~i" '; :;~8~';~4-~ ....................... i ]~.'2'~/--; ........... ;'1-~--¢~-"!'-"-i~1-~-&-'~-'-'-~X~2:~,~; ..... '*--~:;; ...... 2~.22 95.93 3155.71 3908.60 -2580.45; -2935.75 5.85 i 01-AUG-98 j MWD_~ 5536.21~. 35.58t 229.36I 93.80 3230.42 3965.29 -2617.43 ,I.L ........ .-.,2_97___8_..'7__2__- ...... ~'~'T ....... ~.~'::~.74-'~ ~'.'~ ,l-AUG-98t MWDi 5632.49 I 30.38 228.08 96.28 3311.16 4017.68 -2651.96 ! -3018.12 5.45 ............... · ~ .......... .t- ............. ~ .............................. ~ 02-AUG-98t MWD i 5728.02 ~ 25.13 228.24~ 95.53 3395.67 4062.15 -2681.63 i -3051.25 5.50 -5.50 0.17 02-AUG-98 MWD' 5822.6__6__~ 22.70 233.01~ 94.64 3482.19 4100.47 -2706.01 t -3080.83 3.28 -2.57 5.04 02-AUG-98 MWD 6010.67 21.13 232.80 188.01 3656.61 4170.46 -2748.32 -3136.80 0.84 -0.84 -0.11 -- 02-AUG-98 MWD 6296.03 20.31 232.45 285.36 3923.51 4271.21 -2809.60 -3217.04 0.29 -0.29 -0.12 02-AUG-98 MWD 6521.37 19.41 232.43 225.34 4135.44 4347.61 -2856.27 -3277.72 0.40 -0.40 -0.01 --. 02-AUG-98 MWD 6580.00 19.41 232.43 58.63 4190.74 4367.06 -2868.15 -3293.16 0.00 0.00 0.00 PROJ BHC=4367.06 @ 228.95deg. Kuparuk Unit Kuparuk 1D 1D-128 SURVEY REPORT 27 August, 1998 Your Ref: API-500292290000 Last Survey Date 02.August.98 Job# AKMMS0306 KBE - 111.80' DRILLING SERVICES ORIGINAL Survey Ref: svy58 Sperry-Sun Drilling Services Survey Report for '1D-128 Your Ref: API-500292290000 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (fi) (~) 0.00 0.000 0.000 -111.80 0.00 121.00 0.000 0.000 9,20 121.00 289.65 0.400 312.740 177.85 289,65 377.13 0.450 280.010 265.33 377.13 468.37 0.590 277.460 356.56 468.36 560.81 5.150 236.170 448.87 560.67 651.42 10.610 230.200 538.59 650.39 744.11 12.250 227.240 629,44 741.24 834.66 13.890 226.380 717.64 829.44 925.94 19.580 226.370 805.02 916.82 1016.22 25.560 227.340 888.34 1000.14 1107.46 28.010 227.310 969.79 1081.59 1197.77 33.250 231.400 1047.48 1159.28 1288.32 41,930 233.830 1119,17 1230.97 1379.40 47.010 231.350 1184.15 1295.95 1470.34 49.810 230.020 1244.51 1356,31 1561.08 57,140 228.950 1298.48 1410.28 1649.73 60.500 228.160 1344.37 1456.17 1842.82 68.420 227.490 1427.55 1539.35 2125.59 65.630 227.440 1537.91 1649.71 2407.49 65.880 226.990 1653.67 1765.47 2689.40 67.110 229.430 1766.12 1877.92 2978.15 65,730 230.850 1881.63 1993.43 3070.68 65.660 230.970 1919,72 2031.52 3260.62 67.500 230.890 1995.21 2107.01 3545.05 67.020 227.410 2105.18 2216.98 3831.04 63.700 225.050 2224.41 2336.21 4019.64 64.630 225.980 2306.60 2418.40 4207,15 63.620 228.270 2388.44 2500.24 4493.32 62.170 227.500 2518.82 2630.62 Local Coordinates Northings (ft) 0.00 N 0.00 N 0.40 N 0,67 N 0.79 N 1.46 S 9.07 S 21.21 S 35.23 S 53.36 S 77.01 S 104.88 S 134.73 S 168.14 S 206.93 S 250.03 S 297.39 S 347.60 S 464.50 S 64O.48 S 815.07 S 987,31 S 1156.92 S 1210.10 S 1319.94 S 1491.48 S 1671.21 S 1790.15 S 1904.94 S 2075.76 S Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (~) (~) (~) (°/t00~) (~) 0.00E 5959904.19N 560484.14 E 0.00 0.00E 5959904.19N 560484.14E 0.000 0.00 0.43W 5959904,59 N 560483.70 E 0.237 0.06 0.99W 5959904.85 N 560483.14 E 0.279 0.31 1.81W 5959904.97 N 560482.32 E 0.155 0.85 5.73W 5959902.68 N 560478.42 E 5.109 5.28 15.53W 5959895.00 N 560468.68 E 6.085 17.66 29.31W 5959882.75 N 560455.01E 1.879 36.02 44.23W 5959868.61N 560440.20 E 1.824 56.49 63.25W 5959850.33 N 560421.33 E 6.234 82.73 88.54W 5959826.47 N 560396.22 E 6.636 117,35 118,77W 5959798.36 N 560366.22 E 2.685 158.45 153.73W 5959768.23 N 560331.50 E 6,241 204.42 197.64W 5959734.47 N 560287.86 E 9.723 259.46 248.26W 5959695.27 N 560237.55 E 5.894 323.11 300.86W 5959651.74 N 560185.30 E 3.267 391,08 356.24W 5959603,94 N 560130.31E 8.133 463.94 413,07W 5959553.28 N 560073.88 E 3.866 539.78 542.06W 5959435,34 N 559945.83 E 4.114 713.83 733.88W 5959257,82 N 559755,44 E 0.987 974.06 922.52W 5959081.72 N 559568,21 E 0.170 1230.99 1115.26W 5958907,94 N 559376.86 E 0.906 1489.46 1318.38W 5958736.69 N 559175.11E 0.657 1754.02 1383.83W 5958682.99 N 559110.09 E 0.140 1838.30 1519.14W 5958572.06 N 558975.67 E 0.969 2012.47 1717.54W 5958398.94N 558778.66 E 1.141 2274.73 1905.26W 5958217.70 N 558592.40 E 1.382 2534,35 2026.37W 5958097.79 N 558472.25 E 0,663 2703.80 2149.98W 5957982.01 N 558349.56 E 1.224 2872.41 2338.95W 5957809.67 N 558161.98 E 0.560 3127,11 Comment Kuparuk 1 D Continued... 27 August, 1998 - 15:15 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-128 Your Ref: API-500292290000 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth Nothings (~) (fi) (fi) (fi) '4779.73 62.690 231.120 2651.42 2763.22 2241.23 S 5063.46 57.260 228.590 2793.35 2905.15 2399.42 S 5157.02 52.710 230.010 2847.03 2958.83 2449.39 S 5250.93 48.700 231.230 2906.49 3018.29 2495,51S 5346.48 44.380 230.300 2972,20 3084.00 2539.35 S 5442,41 38.810 229.220 3043.91 3155.71 2580.44 S 5536.21 35.580 229.360 3118.62 3230.42 2617.43 S 5632.49 30.380 228.080 3199.36 3311.16 2651.96 S 5728.02 25,130 228.240 3283.87 3395.67 2681.63 S 5822.66 22.700 233.010 3370.39 3482.19 2706.00 S 6010.76 21.130 232.800 3544.89 3656.69 2748.34 S 6296.03 20.310 232.450 3811.71 3923.51 2809.60 S 6521.37 19.410 232.430 4023.64 4135.44 2856.27 S 6580.00 19.410 232.430 4078.94 4190.74 2868.15 S Local Coordinates Global Coordinates Dogleg Ve~ical Eastings Nothings Eastings Rate Section (fi) (fi) (fi) (°/100fi) (fi) 2531.42W 5957642.66N 557970.84E 1.135 3380.93 2719.21W 5957482.96 N 557784.33 E 2.063 3626.42 2777.27W 5957432.52 N 557726.68 E 5.019 3703.02 2833.42W 5957385.96 N 557670.90 E 4.387 3775.65 2887.13W 5957341.68 N 557617.54E 4.576 3844.95 2935.75W 5957300.20 N 557569.26 E 5.854 3908.60 2978.72W 5957262.87 N 557526.58 E 3.445 3965.29 3018.12W 5957228.02 N 557487.46 E 5.449 4017.68 3051,25W 5957198,09 N 557454.58 E 5.496 4062.15 3080.83W 5957173.47 N 557425.19 E 3.279 4100.47 3136.83W 5957130.69 N 557369.53 E 0,836 4170.50 3217.04W 5957068.78 N 557289.82 E 0.291 4271.21 3277.72W 5957021.63 N 557229.51E 0.399 4347,61 3293.17W 5957009.62 N 557214.17 E 0.000 4367.06 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 228.880° (True). Based upon Minimum Curvatu~-type calculations, at a Measured Depth of 6580.00ft., The Bottom Hole Displacement is 4367.06ft., in the Direction of 228.946° (True). Comment Projected Survey Kuparuk 1D Continued... 27 August, 1998 - 15:15 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-'128 Your Ref: API.500292290000 Kuparuk Unit Kuparuk 1D Comments Measured Depth (ft) 0.00 6580.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 4190.74 2868.15 S 3293,17 W Comment Tie-on Survey Projected Survey 27 August, 1998 - 15:15 - 4 - DrillQuest OF:IICI--lNG S ~::: I=t ~J I r' ~:: S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-128, AK-MM-80306 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention ot~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/tlS, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22900-00 OCT 22 1998 Oil & vas t;o,s. ~mm~s~ion An~orage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A FIr~aee~ar InrhlefH=e Ine, F'nmnonw mi:Ill--I--lNG S ~: I:!~./I C G S LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 21, 1998 1D-128, AK-MM-80306 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,//G, Anchorage, AK 99518 1D-128: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22900-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22900-00 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 0 I::t I I--I_ I I~1G S~I:I~./I C E S 02.Sep-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 1D-128 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 6,58O.OO' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo.~ DATE: Chairman THRU: Blair Wondzeil. ~ ~;[~ FILE NO: P. I. Supervisor FROM: Chuck Scheve, ~ '~ SUBJECT: Petroleum Inspector August 4, 1998 aaxkhdfe.doc BOPE Test Parker 245 KRU 1 D-128 PTD # 98-133 Tuesday August 4, 1998: I traveled to ARCOs 1D-128 Well being drilled by Parker Rig 245 and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows/the test lasted 2.5 hours with no failures. The testing went well with good test procedures being employed by the Parker crews. The rig was clean and all related equipment appeared to be in good working order. The location though crowded was well organized. Summary: I witnessed the initial BOPE test on Parker Rig 245 drilling ARCOs West Sak 1 D-128 well. Parker 245, 8~4~98, Test time 2.5 hours, 0 failures Attachment: aaxkhdfe.xls X Unclassified Confidential (Unclassified if doc. removed ) Confidential ....... STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 5 1/2 Test: Initial X Workover: Parker Rig No. 245 PTD # ARCO Rep.: 1D-128 Rig Rep.: Set @ 6,570 Location: Sec. Weekly Other DATE: 8/4/98 98-133 Rig Ph.# 659-7670 Bill Penrose John Crisp 23 T. ~ 1N R. fOE Meridian Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok PTD On Location ok Standing Order Posted BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve (Gen) ok Well Sign Drl. Rig Hazard Sec. ok ok ok Quan. Test Press. I 250/3000 I 250/3,000 1 250/3,000 I 250/3,000 I 250/3,000 2 250/3,000 NA P/F P P P P P P MUD SYSTEM: Visual Alarm Trip Tank ok ok Pit Level Indicators ok ok Flow Indicator ok ok Meth Gas Detector ok ok H2S Gas Detector ok ok FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly I IBOP Ball Type Inside BOP Test Quan. Pressure P/F I , 250/5,000 i P CHOKE MANIFOLD: No. Valves No. Flanges Manual Chokes Hydraulic Chokes Test Pressure P/F 2 FuncSoned 1 Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 6 ~ 2100 avg. 3,000 P 1,700 P minutes 28 sec. minutes 26 sec. X Remote: X Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 28 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659=3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: ofig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector FI-021L (Rev.12/94) STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: aaxkhdfe Chuck Scheve TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Julv 14. 1998 Thomas W. McKa~r', Shallow Sands Team Lcadcr ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re~ Kupamk River Unit 1 D- 128 ARCO Alaska Inc. Permit No. 98-133 Sur. Loc. 33 I'FNL. 599'FEL. Sec. 23. T11N. R10E, UM Btmholc Loc. 2091'FSL. 1408'FWL. Sec. 23. T11N, R10E, UM Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. ID-128. Plcasc note that any disposal of fluids generated from this drilling operation which are pumpcd down thc surface/production casing annulus of a pcrmitted existing well on Drill Site I-D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill docs not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a period longer than one year. Please note that with ,,'our Permit to Drill a service well you have requested an exception to the rcquiremcnts detailed in 20 AAC 25.005(c)(8), 20 AAC 25.033¢) and 20 AAC 25.06 l(a) which apply to exploratory and stratigraphic tcst wells. Thc pcrmit to drill docs not cxcmpt you from obtaining additional pcrmits required bv law from othcr govcrnmcntal agcncics, and docs not authorize conducting drilling operations until all other required permitting dctcrminations arc made. Thc blowout prevention cquipmcnt (BOPE) must be tcstcd in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of thc injection wells must bc demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before opcration, and of thc BOPE test performed before drilling bcloxx' the surface casing shoe, must be given so that a reprcscntativc of the Commission may witncss the tests. Notice ma',' be given bv contacting the Commission pctroleum ficld inspector on the North Slope pagcr at 659-3607. Chairmahx'-..,.~ ./) BY ORDER E COMMISSION dlf/Enclosure CC~ Dcpartmcnt of Fish & Game. Habitat Section w/o cncl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 Oas Cons, la. TypeofWork Drill X Redrill I lb TypeofWell Exploratory [~ StratigraphicTest E] Development Oil Re-Entry DeepenI Service X Development Gas F~ SingleZone X Multiple Zone 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 D.D/esignation 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) 331' FNL, 599' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 2201' FSL, 1533' FWL, Sec. 23, T11N, R10E, UM 1D-128 #U-630610 At total depth 9. Approximate spud date Amount 2091' FSL, 1408' FWL, Sec. 23, T11 N, R10E, UM 7/21/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-106 6516' MD 1408' @ TD feet 28.6' @ 800 feet 2560 4101' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 65.15° Maximum surface 1370 psig At total depth 1800 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 69' 41' 41' 110' 110' +_200 CF 8.5" 5.5" x 15.5# L-80 BTC MOl:: 6475' 41' 41' 6516' 4101' 680 Sx Arcticset Ill, 3.5" 9.3# EUE 8rd 422 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 Intermediate Production Liner .¢r Perforation depth: measured i \~ i ~,..~ ~ true vertical 20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and,(;jor,rect to the best of my knowledge Signed ' Title Shallow Sands Team Leader Date ~ . Commission Use Only Permit N~umber I APl number I Approval date /~/~__ ¢¢ See cover letter for -. ~ ou '" I '~ '~ 50- 0 ~¢/ _ 2 ~ q' ~) 0 Cf other requirements Conditions of approval Samples required [-- Yes F'~ No Mud Icg required I' Yes ~ No Hydrogen sulfidemeasures r--~Yes [~No Directional surveyrequired ,[~Yes ~ No Required workingpressureforBOPE ~]2M ~] 3M ~] 5M [~ 1OM [-~ 15M Other: by order of 7 Approved by Original Signed 8y Commissioner the commission Date ~ ~ I III , , David W. Johnston Subm t in triplicate Form 10-401 Rev. 7-24-89 Drill, Case and Completion Plan for West Sak 1D-128 (K2) Monobore Iniector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 8-1/2" 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 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string 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 stack and pressure test same to 3000 psi. 7. Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. 8. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore injector. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. 13. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 14. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 15. Rig up E-line unit and RIH with through-tubing perforating guns. 16. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 17. Install back pressure valve, shut in and secure well. 1 D-128 (K2) Page 1 TAB, 06/26/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS Drillincl Fluid Type Extended Bentonite Slurry Drilling Fluid Properties: West Sak 1D-128 (K2) 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 % Drilling 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 tapered 5-1/2" x 3-1/2" 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-128 (K2) 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 diverter system only for well control purposes. 1D-128 (K2) Page I TAB,06/26/98,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 3,499' MDFFVD. 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 = (3913 ft)(0.46 - 0.11 psi/fi) = 1370 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 5-1/2" x 3-1/2" 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 5-1/2" 15.5# b80 BTC casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drillinq Area Risks: Drilling risks in the West Sak 1D-128 (K2) 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 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-128 (K2). Well Proximity Risks: The nearest existing well to West Sak 1D-128 (K2) is KRU 1D-06. As designed, the minimum distance between the two wells would be 28.6' at 800' MD. Annular Pumping 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-128 (1(2) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-1/2" tubing tieback string and prior to the drilling rig moving off of the well. 1 D-128 (K2) Page 2 TAB,06/26/98,v.1 A cr¢ot,o ~ f~c~ For: BROCKWAY oot~ plotted: 1-Jun-§8 Plot Rsference ~s ~ 10-12B/K2 VO~. ~. Coord;notes ore ~n ~eet ~eference sial ~128. T~e VeHico~ Dep[hs ore reference ~8 (Porker ~2~5). 300 300 600 900 1200 1500 1800 2100 2400 2700 30O0 3300 3600 3900 4200 3O0 ARCO Alaska, Structure : Pod 10 Well: 128 Field : Kuparuk River Unit Location : North Slope, Alaska 3500 3150 2800 2450 I I I I I I I 228.88 AZIMUTH 4179' (TO TARGET) ***Plane of Proposal*** <- West (feet) 2100 1750 1400 1050 I I I I I I I ESTIMATED ~'~ 'I~Ei[,, SURFACE LOCATION: 331' FNL, .~' FEL SEC. 23, TllN, RIOE 700 350 0 I I I I I Begin Turn to -_-OC Permafrost. RKB ELEVATION: 111' K0P TVD=600 TMD=600 DEP=0 5.94 BEGIN TURN TO TARGET TVD=683 TMD=683 DEP=3 11.78 1 7.73 23.70 DLS: 6.00 deg per 100 ft 29.68 35.67 41.66 47.66 53.65 EOC TV0=1472 TMD=1692 DEP=554 Angle Drop nu Sands West Sok Sands - EOD ;ET - West Sok A3 West. Sok Sands 5 1/2 Casing Pt BASE PERMAFROST TVD=1629 TMD=2065 DEP=893 MAXIMUM ANGLE 65.15 DEG TARGET LOCATION: 2201' FSL, 1533' FWL SEC. 23, T11N, RIOE TARGET TVD=3645 TMD=6031 DEP=4179 50UTH 2748 WEST 5148 TO LOCATION: 2091' FSL, 1408' FWL SEC. 25, TI1N, RIOE 550 350 7OO 1050 1400 1750 2t00 2450 280O 3150 TARGET ANGLE 20 DEG I i i i I 0 300 600 BEGIN ANGLE DROP TVD=2851 TMD=4973 DEP=3531 65.78 T/ UGNU SNDS TVD=2916 TMD=5110 DEP=.3652 53.78 4~;/-/d~8---~-a., DLS: 5.00 deg per 100 ft '~8.78 ~ 33.78 '/,,, 28.78 ~,, 23.78 T/ W SAK SNDS(EOD) WD=3499 TUB=5876 DEP=4126 TARGET - A3 TVD=3645 TMD=6031 DEP=4179 ~ B/ W SAK SNDS TVD=3913 TMD=6316 DEP=4277 ~,,~, TD - CSG PT TVD=410I TMD=6516 DEP=4345 i I i i i i iI i ii I i i i i i i 900 1200 1500 1800 21 O0 2400 2700 3000 3300 5600 Vertical Section (feet) -> Azimuth 228.88 with reference 0.00 N, 0.00 E from slot #128 I I I I I I 3900 4200 4500 A I V c~eot¢~ ~,i~ For: BROCKWAY Oste plotted: 1-Jun-g8 Pl~t Reference [s C~ord;notes ore in ~eet reference slot ~128. r~e Vertical Depths ore reliance ~8 (P~rk~ ~245). aska, ][nc. r Pad Well : 128 J Field : Kuparuk River Unit Location : North Slope, AlaskaJ <- West (feet) 560 520 480 440 400 360 520 280 240 200 160 120 80 40 0 40 80 I I I I I I I I I I I I I I I I I I I I I I I t I I 80 1100 1100 ....... ~ 1200 4o 1500 4O 1400 1500 0 1600 .... .~500 0 900 .. ....... ' .---" .~'8 500 1100 1700 ..... . ....'~00 -/' ~ ........... .......... ...ff40C '/ 1200 40 ..... 700 ..'~00 1800 1000 ......... . .... ~o .,' 13oo 1900 /' 1100~.--"'" ..-"" 800./'/ ..-' ///' 1 80 80 2000 .-"~1000 . 900~" / 1200 .." ..-" ~2o -~' ..--' /' 1200#/ )0 8 20 '"" ////-/' ...//,.-" 160 --'" -'"" " /' 160 -'' ......-" ~ ,/ 1500 ~ ..-' 100~"1300#.,' 500 .,' 1100 '" /800 1100 200 ~'' -'" 900 ~0/ 200 '"'"'" 0 2800,,,, '"' 800 / (~" ~ 500 '"-. /- /' ~"900 ~ ,.,~ 6OO 110~,,' 1400..' j 2000 280 /,' "/' 1000 /' , ", 1400 ~ 900 '~ 700 // ../' j~ \\, ', 320 ~2o .,-" ." .," ~oo lOOO 800~ .,,.,,,,.,.' ¢1ooo ~6o i 360 ~5oo /'"/ /i" 1100 ~oo i ~ 400 400 "./"//' / ,, 160 i 2000 1200~'" // 1100 i 1100 j~ 600 ! 440 440 ./ ~, oo 1800 480 2 O0 ~ 480 1 4700 170 1200 520 [ 520 ,' ,, ¢ 1200 '" I ¢ 2200 560 560 ,, / ! ,' / 180' / / ,' " / / 600 600 ,, /'1200 / ., / 15oo I / ! / ,' / ~ 2300 / ! ,' ~'1300 ,' 190C 680 (~ ¢ 680 I I I I I I I I II I I I I I I I ~10 I 560 520 480 440 400 360 520 280 240 200 160 120 80 40 0 80 <- West (feet) 240 0 280 ~ c~ot¢o w ~inch For: BROCKWAY Date Catted : 1-Jun-g8 Plot Reference ~$ WS 10-128/K2 Vets. ~3. Ca~Uinotes are ~n feet reference slot ~128. ~rue Verdcol Depths are reference ~e (ParKer ~245 ARCO Alaska, Inc. Structure : Pad 10 Well: 128 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feel) 2000 1900 1800 1700 1600 1500 1400 1300 1200 11 O0 1000 900 800 700 600 .500 400 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 t I I I o lO0 200 300 400 500 600 700 800 (- 900 -I-- 0 Lf~ 10oo I v 1100 1200 1300 1400 1500 1600 1700 1800 1 400 .......... '~ 1500 .............. 1600 .................. 1700 ......... - ...... onnn _..L%~5 1800 ......... - ....... ~ /.~ 100 1900 .......... - ........ 2000 ......... - ...... ....--"-_...--'1'ioo 2so ....... 260 270~,.C).~' -'"'"' .-""' 300 280/ 1 500,,--'"'" ....,.--' 1300 330Q.~- ~Oq.~~ ~q400 1200/ / 40o 1700.~--" ..'"" /';// 500 ...... . .... ~5oo .,-'?~6oo 1800..../._.- ..... 1300/'./ ...... .~.-"1'~-0____ 1300 600 ..... . ...;....-.;5-'" 1900.--'"" '" ..';.'~i 700 ..... ~""i'-~O0 1 400/./:/'/ 1 400 700 2000~--" .-' ... ,..,:;.-' -'" ' . /'1300 2100.-'" . ..... i'800 1500 .... "' .... .--..-'"1'9 O0 .?/" 1600 ,," .,'-"¥900 ]500/1400 1 600,~¢¢' ,' 1700 ?600," / / O0 >_700/' 11 O0 1800 ~800 ,'/' ..,! -,'" 1200 2100.~;"""' Z@ 00,," .,,4;~ 800 19 O0 000 ," ,,;:;;.,;.,;.'-' "trW 13oo 100'"1600 I0,? / 2200,~51;;" 2000 5500,/' / 1 ,,-~,~"(900 ]800 ,/ 1400 ~200,,,,' .,,.'.'.-' 21 O0 ~/1700 1500 2300 .,','," ," ~ 900 .,':.-2ooo ," ,' '"?' 2200 ,/ 1600 2400/'?" 330( /"1800 / 2000 / / 1700 4;00 2300 ,,' , 3400 ,,/ ,, · / · '" ! 21 O0 1800 2400 3500 1900 , | I ' ' ' ~ ' ' ' ' I I I I I I ' I ' ' ' I I I ' ' ' I I ' 1900 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 900 800 700 600 500 400 <- West (feet) 800 0 .-t-- 900 1000 I v cr¢ote~ ~y fi.o~ For: BROCKWAY Dote p~otted : 1-Jun-98 Plot Reference ;s W5 1D-128/K2 Vets. ~5. Ceordlnates (3re in feet reference slot ~128. True Verticet Depths ara reference RKB (Parker t~243 x gco k ' it as Structure: Pod 1D Well: 128 Field : Kuparuk River Unit Locafion : Norfh Slope, Alask ~ ~ <- West (feet) 3400 3300 3200 .7,1 O0 3000 2900 2800 2700 2600 2500 2400 2300 2200 21 O0 2000 1900 1800 1300 ~ 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 r I ~ 400 --J~]" 2400.,. ./ 1500 2500.-'"' 1600 2600.,,-" ~ .... 2¢oo#.,-::;'" ,.'~.'~ 100 2500./'..-' ./"/-'2200 .. 2600#////' ./' ./2500 2700//// 2800#// /./ 290y ..,' .,-' 3000/ /' #/ /3100 ,.....-'....,.- .. .-/ /4300 5100#-/' .-'/ / /- // /4400 320,0,~,'"' ..//"2700 3300/./" ....'/ /4-500 3400g" .," 3500#/ .'/ /4600 3600/' '#"'800 3700/' .,.. z 3800,-/ /" /4-700 5900,," ./' / 4000../ /-' , _ ,.... /' 2900 / ,/ ..//" /4900 /,/' 2500 ~,,.,'"' /~ooo ,/ 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 3400 3500 5200 5100 ,3000 2900 2800 2700 2600 2500 2400 2500 2200 21 O0 2000 1900 1800 <- West (feet) 1700 1800 1900 2000 2100 '+- 2200 2300 J 2400 2500 2600 270O 2800 2900 3OOO 3100 3200 1300 1400 1500 16o0 1700 1800 1900 2OOO 2100 2200 2300 2400 I V 2500 26OO 27OO 28O0 2900 3000 3100 3200 Alaska, -t Well : 128 Location : North Slope, Alask ARCO Structure : Pad 1D Field : Kuparuk River Unit WELL PROFILE DATA ..... Point ..... MD lie on 0.00 KOP 600.00 BegM Turn to Torget 683.33 End <~f 8uild,frum 1691.74 End cf Hold 4972.62 End cf Orep/Furn5875.53 Tar§et ¥,~ 1D-K2 Rvsd I 80;50.90 End of Hold 8316.10 T.O. &' End of Ho~d 8516.10 Inc Oir ~ North1 East 0.00 0.00 0.00 0.00 0.00 0.00 250.00600.000.00 0.00 5.00 250.00683.23-1.24 -3.41 65.15 228.621472.15 -351,92-428.22 65.15 228.622851,15 -2319,89 -2661,96 20.00 228.623499.00 -2713.34 -3108.5,t 20.00 225.62364.5.00 -2748.47 -314~,.40 20.00 228,623913.00 -2812.95 -3221.59 20.00 228.624100.94 -2858.17 -3272.91 V. Sect Oe§/lO0 0.00 0.00 0.00 0.00 3.39 6.00 554.036.00 3530.99 0.00 4-126.15 5.00 4-179.29 O.OO 4276.83 0.00 4345.2¢ 0.00 320 % 35O 340 ~ 1100 \ 500 330 TRUE NORTH 0 10 510 500 290 1,300 1 aa Cmo'md by finch For: BROCKWAY Dote plotted : 1--Jun-§8 Pk~t Reference is WS 1D-128/K2 VeTs. Coordinotes ore ;n fe~ reference slol ~12~. F~e V{d~o[ Dep~s ore ref~ence RK8 (Porker 5O 280 270 500 t- 8O 7OO go 1700 260 O0 250 110 500 240 ,"' //1500 · ~k?5oo 3~oo'-. 220 57oo'-... ,, 4-300 '-. / 4900,? ~ ,' '51oo 1 0 / ; % % 190 180 Normal Plane Travelling C inder- Feet -~ 500 "---. 140 ......... .~_'f~ All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Pad 1D 128 slot #128 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT Baker Hughes INTEQ Your ref: WS 1D-128/K2 Vets. #3 Our ref: prop2197 License : Date printed : 1-Jun-98 Date created : 16-Apr-97 Last revised : 1-Jun-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 17 58.060,w149 30 36.370 Slot Grid coordinates are N 5959333.704, E 560490.651 Slot local coordinates are 331.00 S S99.00 W Projection ty~e= alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCBS of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path Closest approach with 3-D Minimum Distance method Last revised Distance PMSS <0 - 7340'>,,10,Pad 1D PMSS <556-7024'>,,9,Pad 1D MSS <3311-8200'>,,7,Pad 1D PGMS <0-8610~>,,6,Pad 1D PGMS <0-8930m>,,5,Pad 1D PGMS <O-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <O-9783'>,,2,Pad 1D PGMS <0-8365'>,,1,Pad 1D 1D-D Version #2,,1D-D,Pad 1D 1D-F Version #2,,1DoF,Pad 1D 1DoB Version #3,,1D-B,Pad 1D TOTCO Sur~ey,,WS-8,Pad 1D PMSS <0-5462'>,,J3,Pad 1D WS 1D-127 WS 1D-110 WS 1D-125 WS 1D-123 WS 1D-122 WS 1D-116 WS 1D-114 WS 1D-113 WS 1D-112 WS 1D-111 WS 1D-13 /L1 Vers. #3,,127,Pad 1D /C3 Vets. #3,,110,Pad 1D /H2 Vets, #3,,125,Pad 1D /Gl Vets. #3,,123,Pad 1D /F2 Vets. #3,,122,Pad 1D /El Vets. #3,,116,Pad 1D rD2 Vets. #3,,ll4,Pad 1D ICl Vets. #3,,113,Pad 1D IA1 Vets. #3,,112,Pad 1D ~B2 Vets. #3,,111,Pad 1D ~J7 Vets. #l,,136,Pad 1D M.D. Diverging from M.D. 28-Apr-98 225.0 100.0 100.0 29-Apr-98 195.0 100.0 100.0 6-Nov-97 138.4 1340.0 6516.1 13-Nov-97 28.6 800.0 800.0 13-Nov-97 87.5 300.0 300.0 4-Aug-92 207.2 600.0 600.0 4-Aug-92 328.1 0.0 600.0 4-Aug-92 447.8 400.0 400.0 10-Dec-97 567.6 600.0 600.0 24-Nov-97 15.0 740.0 740.0 24-Nov-97 133.7 760.0 760.0 24-Nov-97 46.3 720.0 720.0 21-May-98 212.0 12'00.0 1200.0 1-Dec-97 59.3 300.0 2320.0 2T-May-98 15.0 200.0 ~972.6 27-May-98 373.0 200.0 200.0 27-May-98 43.0 200.0 200.0 27-May-98 117.0 500.0 500.0 27-May-98 133.0 300.0 300.0 27-May-98 253.0 300.0 300.0 27-May-98 283.0 200.0 200.0 27-May-98 298.0 200.0 200.0 27-May-98 313.0 200.0 200.0 27-May-98 358.0 300.0 300.0 27-May-98 211.5 683.3 683.3 ws iD- 139 WS 1D- 143 W-q 1D-144 WR 1D-145 WS 1D-146 WS 1D-147 WS 1D-148 WS 1D-149 WS 1D-152 WS 1D-150 WS 1D- 153 WS 1D- 154 WS 1D-155 WS 1D- 156 WS 1D-157 WS 1D-159 WS 1D- 160 WS 1D-161 WS 1D-138 PMSS <0-4414'>,,GS,Pad .... , PMSS <0-4530'>,,F6,Pad 1D PMSS <0-4515'>,,F4,Pad 1D PMSS <0-4590'>,,E5,Pad 1D PMSS <0-5142'>,,E3,Pad 1D PMSS <0-5205'>,,ET,Pad 1D PMSS <0-5047'>,,G3,Pad 1D PMSS <0-4850'>,,D4,Pad 1D PMSS <0-5126'>,,D6,Pad 1D PMSS <381-6092'>,,CT,Pad 1D WS 1D-158/L11 Vets. #1,,158,Pad 1D WS 1D-141/All Vets. #1,,141,Pad 1D WS 1D-142/B10 Vets. #1,,142,Pad 1D WS 1D-140/A9 Vets. #1,,140,Pad 1D ~B8 Vers. #1,,139,Pad 1D IC9 Vets. #1,,143,Pad 1D ~D8 Vets. #1,,144,Pad 1D 'Cll Vers. #1,,145,Pad 1D 'D10 Vets. #1,,146,Pad 1D 'E9 Vets. #1,,147,Pad 1D /Ell Vets. #1,,148,Pad 1D /F8 Vers. #1,,149,Pad 1D /~9 Vets. #1,,152,Pad 1D /Fl0 Vets. #1,,150,Pad 1D /H10 Vets. #1,,153,Pad 1D /Jll Vets. #1,,154,Pad 1D /H8 Vets. #1,,155,Pa~ 1D /J9 Vets. #1,,156,Pad 1D IK10 Vets. #1,,157,Pad 1D ~L9 Vets. #1,,159,Pad 1D ~K8 Vets. #1,,160,Pad 1D '~7 Vets. #1,,161,Pad 1D 'K6 Vets. #1,,138,Pad 1D WS 1D-151/Gll Vets. #1,,151,Pad 1D WS 1D-107/B4 Vets. #1,,107,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-103/B6 Vets. #3,,103,Pad 1D WS 1D-104/A7 Vets. #3,,104,Pad 1D WS 1D-108/A3 Vets. #3,,108,Pa~ 1D PMSS <1957-5265'>,,JS,Pad 1D WS 1D-101/C5 Vets. #3,,101,Pad 1D PMSS <O-5015'>,,GT,Pad 1D PMSS <0-4778'>,,H4,Pad 1D WS 1D-131/~3 Vers. #3,,131,Pad 1D WS 1D-132/K4 Vets. #3,,132,Pad 1D WS 1D-134/~5 Vers. #3,,134,Pa~ 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D 8-Dec-97 19-Dec-97 16oDec-97 22-Dec-97 30-Dec-9? 7-Ja~-98 6-Jan-98 12-Jan- 98 19-Ja~-98 27-Jan-98 27-May-98 27-May-98 27-May-98 27-May-98 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-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 27-May-98 27-May-98 27-May-98 27-~ay-98 27-May-98 24-Nov-97 27-May-98 13-Nov-97 9-Nov-97 27-May-98 27-May-98 27-May-98 27-May-98 150.0 165.0 180.0 224.4 270.0 240.0 60.0 390.0 435.0 464.5 296.4 178.9 178.0 181.0 184.4 178.4 180.0 182.9 186.9 192.0 198.1 205.2 230.9 213.0 240.7 251.0 261.8 273.0 284.5 308.5 320.9 333.5 242.0 221.6 418.0 508.0 493.0 478.0 403.0 113.2 523.0 175.5 53.3 90.0 105.0 180.0 30.0 100.0 '~--~ 100.0 100.0 500.0 100.0 100.0 100.0 100.0 100.0 300.0 200.0 200.0 300.0 300.O 200.0 400.0 500.0 300.0 400.0 500.0 300.0 500.0 400.0 300.0 300.0 300.0 400.0 300.0 300.0 200.0 300.0 300.0 300.0 300.0 300.0 200.0 200.0 200.0 200.0 1060.0 200.0 980.0 1080.0 200.0 200.0 300.0 300.0 100.0 100.0 100.0 500.0 100.0 100.0 100.0 100.0 100.0 300.0 200.0 200.0 300.0 300.0 200.0 400.0 5402.6 300.0 400.0 SO0.O 300.0 500.0 400.0 6516.1 300.0 300.0 400.0 300.0 300.0 200.0 300.0 300.0 300.0 300.0 300.0 200.0 200.0 200.0 200.0 1060.0 200.0 980.0 1080.0 200.0 200.0 300.0 300.0 West ' ak 1 D-128 (K2)Injector comPiTetion 5-1/2" x 3-1/2" Tapered String 16" Conductor @ 80' Weatherford Gemoco 5-1/2" DV Stage Collar Stnd. Grade BTC Threads set +/- 200 -FVD below permafrost (+/- 2541' MD / 1829' TVD) Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 5776' MD / 3407' TVD) Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 5776' MD / 3407'-rVD) to (+/- 6516' MD / 4101' TVD) G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down F. 3-1/2" L-80 9.3~ EUE 8RD-Mod tubing to surface E. 3-1/2" x 1" Camco 'KBG-2-9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin x EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3ff EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3~ EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Eiaker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands TAB, 6/11/98, v.1 ,'~ "DIVERTER SCHEM~ .... ,'lC Kuparuk River Unit West Sak Operations 6 4 3 DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES Maintenance & Operation 1. Upon initial installation: - Close valve and fill preventer with water to ensure no leaks - Close preventer to verify operation and that the valve opens immediately 2. Close annular preventer in the event that an 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-on Weld Starting Head 3. Diverter Assembly With One 2-1/16" 2000 psi 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 TAB, 06/12/98, v.2 t 5000 psi BOP St. ;k . Kuparuk River Unit West Sak Operations -Injector Wells El 5 4 3 2 I 1. 16" Starting Head 2. 7-1/16" 5000 psi Tubing Head 3. 7-1/16" 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 Drilling Spool with Choke and Kill Lines 7. 13-5/8" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 8. 13-5/8" 5000 psi Annular Preventer Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi 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 the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. Fill BOP stack and manifold with water. 2. Check that all hold-down screws 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, 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 back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow 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 bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi 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 BOPE test once per week and functionally operate BOPE daily. ** VBRS will accomodate 3-1/2" to 6" or 4-1/2" to 7" pipe OD's as appropriate ** TAB, 06/15/98, v.2 OE$CRIPTION PER K.~i/f KGB017ACS DESCRIPTION Rood C D.S. 1-0 108 · ~o,e 112 114 116 9 120 122 lO9 111 11;3 ~) 115 I117 4 119 · 121 125 1251 1271 126 Q 6 129 132 ® 7 134~ 135 (~ ~0 14 15 25 24 ~oO~o~ WEST SAK-1 THIS SURVEY VICINITY MAP SCALE: 1" = I MILE N NO SCALE LEGEND 0 EXISTING CONDUCTORS 'AS-BUlL T' CONDUCTOR LOCATION ARCO Alaska, Inc · '4? CADD FILE NO. DRAW1NG NO: LK6104D15 SEE SHEET # 2 FOR NOTES AND LOCATION INFORMATION LOUNSBURY &: ASSOCIATES, INC. I~,~NEEI~ PLANNImRS SURVEYOP~ AREA: 10 MODULE XX ORILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-BUILT LOCATIONS SHEET: REV: CEA-D1DX-6104-D15 ~ OF 2 1 UNIT' 01 DESCRIPTION PER A~_~# K98017A C$ DESCRIPllON NO TEE 1. COORDINATES SHOIMV ARE A.S,P. ZONE 4, N,A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWN ARE TRUE, 2.' BASIS OF LOCATIONS AND' ELEVATIONS ARE D.S. I-D MONUMENTS PER LHD AND ASSOCIATES. J, CONDUCTORS ARE L OCA TED W! THIN PRO TRA C TED SEC TION 25. TOWNSHIP 11 NORTH. RANGE 10 EAST, U.M. 4. DATES OF SURVEY: 6/9/98, FIELD BK. L98-45, PGE. 21-25; AND 6/12/98, FIELD BK. L98-45, PGS. 47-48. 5. DRILL SITE I-D GRID NORTH IS ROTATED 00' F~ST FROM A.S.P. ZONE 4 GRID NORTH. 6. SEE DRAWING NSK-J. 5'I FOR AS-BUILT LOCATIONS OF CONDUCTORS I-8; CEA-DIDX-6104D10 FOR CONDUCTORS 105, I06,109. I15,117-121,124,129,1.~0,135 & 135; AND CEA-DIDX-6104OI$ FOR CONDUCTORS 9 & I0. WEST SAK-1 THIS SURVEY VIC/N/TY MA P SCALE: 1" = I MILE 125 5,959,.379.35 126 ! 5,959,363.92 '27 I 5.959,`348.96 128 I 5,959.`334. I4 151 I 5,959,244,05 132 I 5,959,229.25 ,.~4 I 5.959.15.~.a4 Sec. 23, T. 11 N., R.!.0 E. Y X Lot. Long. 560,490.59 560, 490. 68 560, 490. 67 560, 490. 58 560, 490. 74 5EO, 490. 64 560. 490. 83 70' 17' 58. 509' 70' 17' 58. 358' 70' 17' 58.210'" 70' 17' 58. 065' 70" 17' 57. I79'" 70" 17" 57.0JJ'" 70" 17' 56.291" 149' 30' 36.361' 149' ,,TO'36.362' 149' 30' ,36.366' 149' JO' 36.,572' 149' `30' .36.389' 149' ,TO' $6..395' 149' ,,TO'J6.407' SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PR~ICTICE LAND SURVEYING IN THE STATE OF AL.ASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS 4ND OTHER DETAILS ARE CORRECT AS OF JUNE I$. 1998. ARCO Alaska, Inc. .~ LOUNSBURY & ASSOCIATES, INC. NIgERS PLANNERS SURVEYORS AREA' 1D MODULE' XX DRILL SITE 1-D WEST SAK PHASE lB - WELL CONDUCTORS AS-BUILT LOCATIONS CEA-D1DX-6104D15 ISHEET:20~ 2 {REV: UNIT- D1 ARCO Alaska, Inc. - .... Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 26, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-128 West Sak Phase lB 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 1D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. 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-128, such as shallow gas. There have been ten (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 AtlanticRichfieldCornpany 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 July 21, 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. Thomas A. Brockway Operations Drilling Engineer Attachments: cc: West Sak 1D-128 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 · WELL PERMIT CHECKLIST WELL NAME/¢,~U1. ~ ~1(. '~D-l,X~ PROGRAM: exp [] dev [] redrll [] servJ~wellbore seg I'l ann. disposal para req II COMPANY FIELD & POOL INIT CLASS .~ / UL/[ AJ ,~ GEOL AREA ¢ c~ ~ UNIT# / / / ~ 0 ON/OFF SHORE 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 ........... ENGINEERING DATE r, 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY I A,~_PR DATE ANNULAR DISPOSAL 35. APPR DATE 30. Permit can be issued w/o hydrogen sulfide mea~.:.. 31. Data presented on potential overpr?~ones ....... 32. Seismic analysis of shall~~zones ............. 33. Seabed condi~b;m~'d~rvey (if off-shore) ............. 34. Co~kly progress reports ....... exploratory on~yj With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... (B) will not contaminate freshwater; or cause drilling waste... to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. .N N N N N "i~v~ N Annular disposal has not been requested as part of the Permit to Dr/I/application for Kuparuk River Unit Well No. 1D-128. P/ease note that any disposal of fluids generated from this drilling .operation which are pumped down u~['-~,, annu. lus ora permitted existi o ~,, ^_ 1-,., ..... th/e surface/productio · n~ ,,,~u uu L~rlll 51re 1-1~./ ....... n casing reqmrements and limitations of 20 AAC 25.080. Approval ofC°mplYthis permitWith theto drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or for a.period longer than one year. , Y N GEOI]Op/: ENGINEERING: UIC/Annular COMMISSION: ,,c .w, /¢/~~ JDH .~-2'''~- RNC '-~ co Cc> M:che~list rev 05/29/98 dtf: C:\msoffice\wordian\diana\checklist Please note that with your Permit to Drill a service well you have requested an exception to the requirements detailed in 20 AAC 25.005(c)( ex~ator¥~,.,_,. & stratlgraphlc wells. test 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. ~ I 'f 8 --133 Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe 1 Use: ConocoPhillips Alaska, Inc. July 28,2005 6509 1 3.5" 9.3Ib. L-80 Tubing Well: 1 D-128 Field: Kuparuk State: Alaska API No.: 50-029-2290-00 Top Log IntvI1.: Surface Bot. Log IntvI1.: 5,863 Ft. (MD) Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into the DS Nipple @ 5,745' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The condition of the 3.5" tubing ranges from good to poor with respect to corrosive damage, with a maximum wall penetration of 71 % in joint 146 (4,662'). The deeper penetrations are recorded in the interval between joints 89 and 182 (2,850' - 5,863'). Wall penetrations ranging from 20% to 71 % are recorded in 108 of the 191 joints logged. The damage appears in the forms of isolated pitting and lines of pits. Deposits are recorded in joint 1, with a minimum 1.0. of 2.70" (53'). No significant areas of cross- sectional wall loss are recorded throughout the tubing logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WAll PENETRATIONS: Line of Pits ( 71%) Jt. 146 @ 4,662 Ft. (MD) Line of Pits ( 68%) Jt. 139 @ 4,426 Ft. (MD) Line of Pits ( 67%) Jt. 145 @ 4,618 Ft. (MD) Line of Pits ( 61%) Jt. 127 @ 4,064 Ft. (MD) Line of Pits ( 61 %) Jt. 129 @ 4,119 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 11 %) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: Deposits Minimum 1.0. = 2.70" Jt. @ 53 Ft. (MD) No other significant 1.0. restrictions are recorded throughout the tubing interval logged. ..,,, , Ì!\'i'",uE"~""" nU'G c~~ '1 ?fln¡:; .:';)t;A.a'\~h~ t,' H :') (') .i. C. ,"".!J I Field Engineer: N.Kesseru Analyst: M. Tahtouh Witness: C. Fitzpatrick I ProActive Diagnostic Services, Inc. I P.O. Box 1369, Stafford, TX 77497 Pllone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2.307 Fax: (907) 659-2314 ck3s, Well: Field: Company: Country: 10-128 Kuparuk ConocoPhillips (Alaska), Inc. USA I Tubing: Nom.OD 3.5 ins Weight 9.3 ppf Grade & Thread L-80 Penetration and Metal Loss (% wall) _ penetration body 200 \DR metal loss body 150 100 50 O · o to 1 to 1% 10% 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 191) pene. 0 0 83 37 71 0 loss 21 169 1 0 0 0 . Damage Configuration ( body) 100 80 60 40 20 o isolated general line ring hole / poss pitting corrosion corrosion corrosion ible hole Number of joints damaged (total = 189) 42 66 81 0 0 PDS Report Overview Body Region Analysis _ penetration body o o~ I 48. .. S' ,;Ii;" t;~,: \ 98 ..J\~,,' ~;'-\\" ~. 'i'! \ ì1:~1 . .. \. .~¡"~.';:'" I\d'/¡,'-:p'\·¡ ¡f:,':~" ,t." \',' ~1~~, \ tf<\.X'·.···~ Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.ID 2.992 ins GLM 1 July 28,2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Nom. Upset 3.5 ins Upper len. 1.2 ins Lower len. 1.2 ins Damage Profile (% wall) II!!IiiIi metal loss body 50 100 148 Bottom of Survey = 182 Analysis Overview page 2 { PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-128 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. Nominal 1.0.: 2.992 in Country: USA SUlVey Date: July 28, 2005 Joint Jt. Depth Pen. Pen. Pen. Meté11 Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) (}() (Ins.) 0 50 100 .1 49 0 0.03 12 0 2.82 PUP Shallow pitting. Lt. Deposits. 1 51 0.04 0.05 21 2 2.70 Corrosion. Deposits. 1.1 83 D.05 0.04 15 5 2.93 PUP Shallow corrosion. 1.2 93 0 0.04 15 2 2.91 PUP Shallow corrosion. 2 95 0 0.04 14 1 2.92 Shallow pitting. Lt. Deposits. 3 127 0 0.04 14 2 2.93 Shallow corrosion. Lt. Deposits. 4 158 0 0.04 17 1 2.90 Shallow corrosion. Lt. Deposits. 5 190 0 0.04 16 1 2.92 Shallow corrosion. Lt. Deposits. 6 221 0 0.04 16 2 2.94 Shallow corrosion. Lt. Deposits. 7 253 0 0.04 15 2 2.92 Shallow corrosion. Lt. Deposits. 8 284 0 0.04 17 2 2.92 Shallow corrosion. Lt. Deposits. 9 316 0 0.04 14 2 2.92 Shallow pitting. 10 348 0 0.04 17 2 2.90 Shallow corrosion. Lt. Deposits. 11 379 0 0.04 17 1 2.92 Shallow pitting. Lt. Deposits. 12 411 0 0.04 17 :3 2.92 Shallow corrosion. Lt. Deposits. 13 443 0 0.03 13 :3 2.91 Shallow pitting. Lt. Deposits. 14 474 0 0.04 17 2 2.93 Shallow corrosion. Lt. Deposits. 15 506 0 0.04 17 2 2.93 Shallow corrosion. Lt. Deposits. 16 537 0 0.04 17 :3 2.93 Shallow corrosion. Lt. Deposits. 17 569 0 0.04 15 2 2.93 Shallow corrosion. Lt. Deposits. 18 600 0 0.04 17 2 2.92 Shallow corrosion. Lt. Deposits. 19 632 0 0.05 20 2 2.92 Shallow corrosion. Lt. Deposits. 20 664 0 0.05 18 2 2.93 Shallow corrosion. Lt. Deposits. 21 695 0 0.04 17 2 2.93 Shallow pitting. Lt. Deposits. 22 727 0 0.04 16 2 2.93 Shallow corrosion. Lt. Deposits. 23 758 0 0.04 17 1 2.93 Shallow corrosion. Lt. Deposits. 24 790 0 0.05 19 2 2.93 Shallow corrosion. Lt. Deposits. 25 822 0 0.04 14 2 2.92 Shallow pitting. Lt. Deposits. 26 853 0 0.04 17 2 2.92 Shallow corrosion. Lt. Deposits. 27 885 0 0.04 14 1 2.92 Shallow corrosion. Lt. Deposits. 28 916 0 0.04 16 2 2.92 Shallow corrosion. 29 948 0 0.04 16 2 2.93 Shallow corrosion. Lt. Deposits. 30 980 0 0.05 19 2 2.93 Shallow corrosion. Lt. Deposits. 31 1011 0 0.03 13 2 2.93 Shallow pitting. 32 1043 0 0.04 15 1 2.93 Shallow corrosion. Lt. Deposits. 33 1074 0 0.05 19 2 2.92 Shallow corrosion. Lt. Deposits. 34 1106 0 0.04 17 2 2.92 Shallow corrosion. Lt. Deposits. 35 1137 () 0.04 16 1 2.92 Shallow corrosion. Lt. Deposits. 36 1169 0 0.04 18 2 2.91 Shallow corrosion. 37 1201 0 0.04 17 1 2.91 Shallow corrosion. Lt. Deposits. 38 1232 0 0.03 13 1 2.91 Shallow pitting. 39 1264 0 0.03 12 2 2.91 Lt. Deposits. 40 1295 0 0.03 13 2 2.91 Shallow pitting. Lt. Deposits. 41 1326 0 0.04 15 2 2.90 Shallow corrosion. Lt. Deposits. 42 1358 0 0.04 16 2 2.89 Shallow corrosion. Lt. Deposits. 43 1390 0 0.04 15 1 2.88 Shallow corrosion. 44 1421 () 0.04 17 2 2.86 Shallow corrosion. Lt. Deposits. 45 1453 0 0.04 16 1 2.88 Shallow corrosion. Lt. Deposits. 46 1484 0 0.04 16 2 2.89 Shallow pitting. Lt. Deposits. 47 1516 0 0.03 13 1 2.89 Shallow corrosion. I Penetration Body Metal Loss Body Page 1 '( PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 Well: 10-128 Body Wall: 0.254 in Field: Kuparu k Upset Wall: 0.254 in Company: ConocoPhillips (Alaska), Inc. NominaII.D.: 2.992 in Country: USA Survey Date: July 28, 2005 Joint Jt. Depth Pen. Pen. Pen. MC'tal Min. Damage Profile No. (Ft.) Upset Body 0/0 Loss 1.0. Comments (% wall) (Ins.) (Ins.) Oi (Ins.) 0 50 100 10 48 1548 0 0.04 14 1 2.88 Shallow corrosion. Lt. Deposits. 49 1579 0 0.04 15 2 2.87 Shallow corrosion. 50 1611 0 0.04 14 1 2.89 Shallow pittin~. Lt. Deposits. 51 1642 0 0.04 17 2 2.89 Shallow corrosion. Lt. Deposits. 52 1674 0 0.05 19 2 2.90 Shallow corrosion. Lt. Deposits. 53 1706 0 0.04 16 2 2.88 Shallow corrosion. 54 1737 0 0.04 17 2 2.88 Shallow corrosion. 55 1769 0 0.04 16 2 2.82 Shallow corrosion. 56 1800 0 0.04 15 2 2.83 Shallow pittin~. 57 1832 0 0.04 17 2 2.85 Shallow corrosion. Lt. Deposits. 58 1863 0 0.03 11 1 2.85 Lt. Deposits. 59 1895 0 0.05 19 2 2.84 Shallow pittin~. 60 1927 0 0.04 17 2 2.86 Shallow pittin~. Lt. Deposits. 61 1958 0 0.04 15 5 2.81 Shallow pitting. Lt. Deposits. 62 1989 0 0.04 17 ') 2.85 Shallow corrosion. ,) 63 2021 0.11 0.07 28 2 2.84 Corrosion. Lt. Deposits. 64 2053 0 0.04 14 2 2.85 Shallow corrosion. Lt. Deposits. 65 2084 0 0.05 20 2 2.85 Isolated pittin~. Lt. Deposits. 66 2116 0 0.05 19 2 2.84 Shallow pitting. Lt. Deposits. 67 2146 0 0.05 20 2 2.84 Shallow pits. Lt. Deposits. 68 2177 0 0.07 26 2 2.84 Line of pits. 69 2209 0 0.11 42 5 2.84 Line of pits. Lt. Deposits. 70 2240 0 0.07 28 4 2.87 Line of pits. Lt. Deposits. 71 2272 0 0.04 17 4 2.88 Shallow pittin~. Lt. Deposits. 72 2303 0 0.06 24 2 2.87 Isolated Pitting. 73 2335 0 0.06 23 2 2.88 Isolated pittin~. Lt. Deposits. 74 2365 0 0.07 26 2 2.86 Isolated pitting. 75 2395 0 0.06 22 2 2.86 Isolated pittin~. Lt. Deposits. 76 2427 0 0.04 17 2 2.86 Shallow corrosion. Lt. Deposits. 77 2459 0 0.05 18 1 2.87 Shallow corrosion. 78 2490 0 0.04 17 2 2.87 Shallow corrosion. 79 2521 0 0.04 15 2 2.88 Shallow corrosion. Lt. Deposits. 80 2553 0 0.04 15 2 2.84 Shallow pittin~. Lt. Deposits. 81 2584 0 0.04 17 3 2.84 Shallow corrosion. Lt. Deposits. 82 2616 0 0.11 42 3 2.85 Isolated pitting. Lt. Deposits. 83 2648 0 0.04 17 1 2.81 Shallow pitting. Lt. Deposits. 84 2679 0 0.04 16 1 2.84 Shallow corrosion. Lt. Deposits. 85 2711 () 0.04 15 'I 2.85 Shallow corrosion. Lt. Deposits. 86 2742 () 0.04 17 2 2.86 Shallow corrosion. Lt. Deposits. 87 2774 0 0.04 17 3 2.82 Shallow pitting. 88 2806 0 0.08 30 2 2.83 Isolated pitting. 89 2837 0 0.14 54 3 2.86 Isolated pitting. 90 2869 0.10 0.12 47 3 2.85 Line of pits. Lt. Deposits. 91 2900 0 0.05 20 2 2.83 Shallow pittin~. Lt. Deposits. 92 2932 0 0.09 36 4 2.84 Isolated pitting. Lt. Deposits. 93 2964 () 0.07 29 2 2.86 Isolated pitting. Lt. Deposits. 94 2995 0 0.10 41 4 2.88 Isolated pitting. 95 3027 0 0.08 33 4 2.86 Isolated pitting. 96 3058 0 0.07 27 2 2.85 Isolated pitting. Lt. Deposits. 97 3090 0 0.09 37 5 2.86 Isolated pitting. I Penetration Body Metal Loss Body Page 2 Ii ;,!\ <,\ PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. Melal Min. No. (Ft.) Upspt Body 0/0 Loss 1.0. (Ins.) (Ins.) (.¡~) (Ins.) 98 3122 0 0.09 36 5 2.86 99 3153 0 0.07 27 2 2.86 100 3185 0 0.10 38 4 2.85 101 3216 0 0.08 31 3 2.83 102 3247 0 0.04 17 3 2.84 103 3279 0 0.08 32 2 2.86 104 3311 0 0.10 39 4 2.85 105 3342 0 0.09 34 6 2.83 106 3372 0 0.10 39 :3 2.85 107 3403 0 0.13 53 7 2.84 108 3435 0 0.07 26 2 2.85 109 3466 0 0.09 34 5 2.86 110 3498 0 0.10 38 4 2.89 111 3530 0 0.09 36 4 2.88 112 3561 0 0.11 42 4 2.86 113 3593 0 0.08 33 :3 2.86 114 3624 0 0.12 46 :3 2.87 115 3656 0 0.11 44 6 2.88 116 3688 0 0.09 35 3 2..88 117 3719 0 0.12 47 5 2.87 118 3751 0 0.09 37 :3 2.84 119 3782 0 0.08 30 :3 2.85 120 3814 0.14 0.11 44 7 2.86 121 3845 0 0.13 50 5 2.86 122 3877 0 0.09 37 4 2.85 123 3909 0 0.12 46 7 2.87 124 3940 0 0.09 37 4 2.86 125 3972 0 0.08 31 :3 2.84 126 4003 0 0.11 44 6 2.82 127 4033 0 0.15 61 4 2.80 128 4064 0 0.13 51 7 2.83 129 4096 0 0.15 61 7 2.86 130 4128 0 0.14 57 7 2.87 131 4159 0 0.11 42 4 2.86 132 4191 0 0.12 48 5 2.87 133 4222 0 0.11 43 4 2.86 134 4254 0 0.12 48 4 2.88 135 4286 0 0.12 48 :3 2.82 136 4317 0 0.12 47 5 2.81 137 4349 0 0.14 53 4 2.87 138 4380 0 0.11 42 4 2.84 139 4412 0 0.17 68 6 2.83 140 4444 0 0.14 53 4 2.90 141 4475 0 0.14 54 5 2.90 142 4507 0 0.14 54 5 2.88 143 4538 0 0.11 43 5 2.87 144 4570 0 0.14 55 6 2.85 145 4602 0 0.17 67 6 2.88 146 4633 0 0.18 71 9 2.89 147 4665 0 0.14 54 5 2.87 Well: Field: Company: Country: Survey Date: 10-128 Kuparuk ConocoPhillips (Alaska), Inc. USA July 28,2005 Comments Isolated pittin~. Lt. Deposits. Isolated pittin~. Lt. Deposits. Line of pits. Lt. Deposits. Isolated pittin~. Shallow pittin~. Isolated pittin~. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Page 3 Damage Profile (% wall) o 50 100 .. .. _.. .. .. II.. .. ... .. .. ... i. .. I.. .... II. .. _. .. .. .. ... ... .. .. .. _.. II. .. .. .. II.. I ._- .. .. Ii I Penetration Body ¡e;ii;: Metal Loss Body !( ~. PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt. Depth Pen. Pen. Pen. MC'léll Min. No. (Ft.) Upset Body % Loss 1.0. (Ins.) (I ns. ) ('l~ (Ins.) 148 4697 () 0.12 46 5 2.83 149 4728 0.08 0.11 44 11 2.85 150 4760 0 0.14 57 5 2.87 151 4791 0 0.12 46 7 2.87 152 4822 0 0.13 52 7 2.91 153 4853 0 0.10 39 4 2.89 154 4885 0 0.12 48 4 2.89 155 4916 0 0.11 45 6 2.88 156 4948 0 0.12 48 6 2.89 157 4980 0 0.11 44 7 2.85 158 5011 () 0.12 46 7 2.88 159 5043 0 0.14 54 6 2.88 160 5074 0 0.11 43 7 2.89 161 5106 0 0.12 47 6 2.91 162 5137 () 0.15 59 7 2.87 163 5169 0 0.14 55 7 2.88 164 5200 0 0.09 34 :3 2.92 165 5232 0 0.13 52 4 2.88 166 5263 0 0.13 50 6 2.85 167 5295 0 0.13 50 6 2.88 168 5326 0 0.14 56 5 2.92 169 5358 0 0.14 55 6 2.91 170 5389 0 0.13 51 5 2.91 171 5421 0 0.14 55 5 2.90 172 5452 0 0.14 55 4 2.90 173 5484 0 0.14 54 4 2.92 174 5515 0.11 0.15 59 6 2.91 175 5547 0 0.12 47 6 2.93 176 5578 0 0.12 45 5 2.92 177 5610 0 0.13 50 5 2.88 178 5641 0 0.13 50 6 2.88 178.1 5672 0 0.13 53 9 2.88 178.2 5687 0 0 0 0 N/A 178.3 5694 0 0.11 42 6 2.92 179 5708 0 0.13 50 6 2.93 179.1 5739 0 0.06 25 4 2.91 179.2 5745 0 0 0 0 2.81 179.3 5746 0 0.06 22 7 2.91 180 5752 0 0.12 46 6 2.92 180.1 5783 () 0.04 15 4 2.90 180.1 5789 0 0 0 0 N/A 180.3 5808 0.15 0.13 51 6 2.92 181 5818 0.07 0.14 57 6 2.91 182 5850 0 0.15 61 5 2.95 Well: Field: Company: Country: Survey Date: 1 D-128 Kuparuk ConocoPhillips (Alaska), Inc. USA July 28,2005 Comments Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line Qf pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Line of pits. Lt. Deposits. Line of pits. Lt. Deposits. Line of pits. Lt. DepQsits. PUP Line of pits. GLM (Latch @ 8:30) PUP Line of pits. Line of pits. Lt. Deposits. PUP Line of pits. Lt. Deposits. DS Nipple PUP Line of pits. Lt. Deposits. Corrosion. Lt. Deposits. Pup Shallow corrosion. Seal Assembly PUP Corrosion. Corrosion. Lt. Deposits. Line corrosion. Page 4 Damage Profile (% wall) o 50 100 ... .." I ,. .. ... .. .. I I fill I I I I I Penetration Body ;\]¡n Metal Loss Body ~·~~lS ~ .' PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-128 Kuparuk ConocoPhillips (Alaska), Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28, 2005 MFC 24 No. 00387 1.69 24 M. T ahtouh Cross Section for Joint 146 at depth 4662.03 ft Tool speed = 53 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 91 % Tool deviation = 78 0 Finger 13 Penetration = 0.181 ins Line of Pits 0.18 ins = 71 % Wall Penetration HIGH SIDE = UP Cross Sections page 1 ··-~lS ~ a, PDS Report Cross Sections Well: Field: Company: Country: Tubing: 1 0-128 Kaparu k ConocoPhillips (Alaska), Inc. USA 3.5 ins 9.3 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh Cross Section for Joint 139 at depth 4425.7 ft Tool speed = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 94 % Tool deviation = 84 0 Finger 13 Penetration = 0.172 ins Line of pits 0.17 ins = 68% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ·~-->s ~ g, Well: Field: Company: Country: Tubing: 1 0-128 Ku paru k ConocoPhillips (Alaska), Inc. USA 3.5 ins 9.3 ppf L-80 Cross Section for Joint 1 at depth 52.51 ft Tool speed = 50 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 100 % Tool deviation = 1 0 PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: July 28, 2005 MFC 24 No. 00387 1.69 24 M. Tahtouh ø...:;--. Finger 16 Projection = -0.311 ins Deposits Minimum 1.0. = 2.7 ins HIGH SIDE = UP Cross Sections page 3 ARca Alaska, Inc.A TUBING (0-5790, OD:3.500, ID:2.992) GasUfl lanctellDummy Valve 1 (5687-5688, OD:4.725) PRODUCTION (0-5793, OD:5.500, Wt:15.(0) ]J NIP (5745-5746, OD:4.550) II Perf (5866-5895) SBE (5790-5991, OD:4.000) Perf (5929-5951) III Perf (5974-5982) Perf (6020-6028) Perf (6038-6056) Perf (6062-6070) PRODUCTION (5794-6568, OD:3.500, Wt:9.30) Perf (6091·6103) PLUG (6450-6451, OD:2.750) ~ 1 D-128 GKA Well Type: INJ Orig Completion: 8/6/98 Last W/O: Ref Log Date: TD: 6580 ftKB Max Hole Angle: 68 deg <æ 1843 1 D-128 Angle ~ TS: deg @ Angle (éì! TD: 19 deg (éì! 6580 Rev Reason: TAG BY VG Last Update: 1f7/oo TVD Wt Grade Thread 121 62.58 H-4O WELDED 3455 15.00 L-80 BTCM 4179 9.30 L-80 EUE TVD Wt Grade Thread 3452 9.30 L-80 EUE Bottom 121 5793 6568 Bottom 5790 status Feet SPF Date Type 29 4 3/18/99 IPERF 22 43/18/99 IPERF 8 4 3/18/99 IPERF 8 4 3/18/99 ¡PERF 18 4 3/18/99 IPERF 8 4 3/18/99 IPERF 12 4 3/18/99 IPERF 19 4 3/18/99 ¡PERF 2.25" HCBH 2.25" HCBH 2.25" HCBH 2.25" HCBH 2.25" HCBH 2.25" HCBH 2.25" HCBH 2.25" HCBH Comment 1.0 V OD Latch Port TRO Date Run o 3/23/99 VMfr V Type API: 500292290000 SSSV Type: NONE Annular Fluid: 3% KC18.7 ppg Reference Log: LastTag: 6385 Last Tag Date: 1/5/00 Casing String - ALL Size Top 16.000 0 5.500 0 3.500 5794 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD Zone 5866 - 5895 3522 - 3549 WS D 5929 - 5951 3581 - 3601 WS B 5974- 5982 3623 - 3630 WS A4 6020 - 6028 3665 - 3673 WS A3 6038 - 6056 3682 - 3699 WS A3 6062 - 6070 3705 - 3712 WS A3 6091 - 6103 3732 - 3743 WS A2 6117 - 6136 3756 - 3774 WS A2 Gas Lift MandrelsNalves Stn MD TVD Man Man Mfr Type 1 5687 3359 CAMCO KBG CAMCO DMY Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 5745'3411 NIP 'DS' NOGO. 5790 3452 SBE BAKER GBH-22 LSA W/12' SEALS 6450 4068 PLUG Set Baker bridge plug for a PBTD. Description BTM 0.000 Vlv Comment ID 2.812 3.000 0.000 Sperry-Sun Drillir Services LIS Scan Uti-~y Mon Oct 12 14:32:40 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/12 Origin ................... STS Reel Name ................ IINKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/12 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-80306 S. BURKHARDT M. CUNNINGHA 1ST STRING 1D-128 500292290000 · ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 12-0CT-98 MWD RUN 2 AK-MM- 80306 S. BURKHARDT M. CUNNINGHA 23 lin 10E 331 599 .O0 111.80 70.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) RECEIVED OCT 22 1998 Oil & ons. ommissior An orage 2ND STRING '3RD S~RING PRODUCTION STRING REMARKS: 8.50O 658O.O 1. AJ~L DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. 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. MWD IS PDC. 3. MWD RUNS 1 & 2 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. ROP AND FE DATA FROM 3980-4073'MD, 2401-2441'TVD WAS ACQUIRED WHILE REAMING TO BOTTOM DUE TO OPERATIONAL PROBLEMS. 5. WELL 1D-128 REACHED A TOTAL DEPTH (TD) OF 6580'MD, 4191'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. 001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPD 82 5 6541.0 RPM 82 5 6541.0 RPS 82 5 6541.0 RPX 82 5 6541.0 GR 91 0 6548.5 FET 120 5 6541.0 ROP 122 5 6580.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH .$ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 121.0 3980.0 2 3980.0 6580.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD API 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 ROP MWD FT/H 4 1 FET MWD HOUR 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 82.5 11 3337 0 1227 0 2316 0 2905 0 2053 10 2373 0 0412 Max 6580 143.849 2000 2000 2000 2000 3879.49 14.8316 Mean Nsam 3331.25 12996 71.6013 12916 46.0244 12918 51.4425 12918 70.9524 12918 67.1644 12918 300.993 12916 0.38516 12842 First Reading 82.5 91 82.5 82.5 82.5 82.5 122.5 120.5 Last Reading 6580 6548.5 6541 6541 6541 6541 6580 6541 First Reading For Entire File .......... 82.5 Last Reading For Entire File ........... 6580 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/12 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 ....... 98/10/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NLTMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NI/MBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 82 5 RPM 82 5 RPS 82 5 RPX 82 5 GR 91 0 FET 120 5 ROP 122 5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : STOP DEPTH 3941.5 3941.5 3941.5 3941.5 3949.0 3941.5 3980.5 31-JUL-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 3980.0 121.0 3980.0 .0 68.4 TOOL NUMBER P1036CRG6 P1036CRG6 8.500 8.5 LSND 9.00 314.0 10.2 400 8.2 RESISTIVITY (OHMM) AT TEMP--~ATURE (DEGF) MUD AT MEASURED TEMPERA .RE (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 6.000 4.230 8.000 3.500 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 Name DEPT GR RPX RPS RPM RPD ROP FET 0 0 27 0 Min 82.5 11 3337 0 1227 0 2316 2905 2053 4148 0821 First Max Mean Nsam Reading 3980.5 2031.5 7797 82.5 132.724 67.6348 7717 91 2000 70.3305 7719 82.5 2000 79.0508 7719 82.5 2000 111.873 7719 82.5 2000 105.769 7719 82.5 1809.28 311.733 7717 122.5 3.6085 0.2988 7643 120.5 Last Reading 3980.5 3949 3941.5 3941.5 3941.5 3941.5 3980.5 3941.5 First Reading For Entire File .......... 82.5 Last Reading For Entire File ........... 3980.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/12 Maximum Physical Record..655? '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 ....... 98/10/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 R3kW 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 FET 3942.0 6541 0 RPD 3942 0 6541 0 RPM 3942 0 6541 0 RPS 3942 0 6541 0 RPX 3942 0 6541 0 GR 3949 5 6548 5 ROP 3981 0 6580 0 $ LOG HEADER DATA DATE LOGGED: 02-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46/EWP4 1.38 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 6580.0 TOP LOG INTERVAL (FT) : 3980.0 BOTTOM LOG INTERVAL (FT) : 6580.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 19.4 MAXIMUM ANGLE: 64.6 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: TOOL NUMBER P1036CRG6 P1036CRG6 8.500 8.5 LSND 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 9.80 300.0 8.6 400 3.8 5.500 3.900 5.100 3.100 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 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 38.4 First Name Min Max Mean Nsam Reading DEPT 3942 6580 5261 5277 3942 GR 26.0314 143.849 77.4887 5199 3949.5 RPX 0.4689 73.7432 9.93687 5199 3942 RPS 0.506 66.4618 10.4523 5199 3942 RPM 0.5622 67.6103 10.1969 5199 3942 RPD 0.5964 58.9359 9.84827 5199 3942 ROP 10.2373 3879.49 285.051 5199 3981 FET 0.0412 14.8316 0.512116 5199 3942 Last Reading 6580 6548.5 6541 6541 6541 6541 6580 6541 First Reading For Entire File .......... 3942 Last Reading For Entire File ........... 6580 File Trailer Service name ............. STSL~ ~.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/10/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Technical Services Services Physical EOF Physical EOF End Of LIS File