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195-029
Originated: Delivered to:10-Apr-25 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET# 1 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 1-Apr-25 0 1 2 1Y-27 50-029-22379-00 909915690 Kuparuk River Packer Setting Record Field- Final 20-Mar-25 0 1 3 1Y-27 50-029-22379-00 909953476 Kuparuk River Packer Setting Record Field- Final 31-Mar-25 0 1 4 1Y-29 50-103-21852-00 909915382 Kuparuk River Multi Finger Caliper Field & Processed 23-Mar-25 0 1 5 2A-04 50-103-20026-00 909976821 Kuparuk River Multi Finger Caliper Field & Processed 31-Mar-25 0 1 6 2K-20 50-103-20120-00 909966603 Kuparuk River Multi Finger Caliper Field & Processed 26-Mar-25 0 1 7 2T-20 50-103-20215-00 909915691 Kuparuk River Multi Finger Caliper Field & Processed 13-Mar-25 0 1 8 2V-10 50-029-21310-00 909915383 Kuparuk River Packer Setting Record Field- Final 17-Mar-25 0 1 9 3T-731 50-103-20905-00 909991288 Kuparuk River Cement Evaluation with CAST Field & Processed 2-Apr-25 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 193-088 188-091 184-053 189-118 195-029 185-048 224-156 T40310 T40310 T40310 T40311 T40312 T40313 T40314 T40315 T40316 4/10/2025 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2025.04.10 14:23:59 -08'00' 72T-20 50-103-20215-00 909915691 Kuparuk River Multi Finger Caliper Field & Processed 13-Mar-25 0 1 95-029 • 19 5029 WELL LOG TRANSMITTAL #904542703 2 9 3 8 8 To: Alaska Oil and Gas Conservation Comm. June 14, 2018 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVEr JUN 202018 RE: Leak Detect Log and Packer Set Record: 2T-20 ACSG C C Run Date: 1/3/2018 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2T-20 Digital Data in LAS format, Digital Log file 1 CD Rom 50-103-20215-00 Leak Detect Logand Packer Set Record 1 Color Log-each 50-103-20215-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. SSCANNEDE0 JUN z�' 5 LU l5 Anchorage, Alaska 99518 Office: 907-275-2605 FRS ANC@halliburton.com Date: da?y0/2a Signed: , f i r A RECishiLI STATE OF ALAS` ALASKA OIL AND GAS CON ERVATION COMMISSION MAR 0 8 2018 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations LJ Fracture Stimulate H Pull TubingLi❑ Operations shutdown Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well ❑ Other: tbg patch_ ❑., 2.Operator ConocoPhillips Alaska,Inc 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑., Exploratory ❑ 195-0Xt 3.Address: P.O.Box 100360 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage AK 99510 50-1032021500 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25548 KRU 2T-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field I Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10225 feet Plugs measured n/a feet true vertical 6071 feet Junk measured n/a feet Effective Depth measured 9526' feet Packer measured 9764 feet true vertical 5946' feet true vertical 5715 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 81' 16" 121' 121' Surface 4337' 9-5/8" 4376' 2958' Intermediate Production 10194' 7" 10225' 6071' Liner Perforation depth Measured depth 9878_9967 feet SES True Vertical depth 5801-5869 feet Tubing(size,grade,measured and true vertical depth) 3.5 L-80 9788'MD 5732'TVD Packers and SSSV(type,measured and true vertical depth) Packer Baker SAB-3 Pkr 9764'MD 5715'TVD No SSSV Nipple CAMCO DS 506'MD 506'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): n/a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: n/a n/a n/a n/a n/a Subsequent to operation: n/a n/a n/a n/a n/a 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil Li Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ H WAG ❑ GINJ ❑ SUSP H SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: n/a Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: n1617(acop.com Authorized Signature: 7 ',------- Date:3-6-18 Contact Phone: 659-7224 vn. 3/1 G J S 11`'A rq Form 10-404 Revised 4/2017 ����� RBDMS L v t'I tlf " cC 18 Submit Original Only • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 March 6, 2018 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. Development KRU well 2T-20 (PTD 195-029). The report is for a tubing patch that was set to repair a leak above the packer. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, Kelly Lyons Well Integrity Supervisor Attachments • • Date Event Summary 11/19/17 (SUB) MIT-OA (PASS TO 1800 PSI) TIFL (FAIL) Initial T/I/O = 260/1150/740. IA FL @ 8089' (1463' below the OV @ 6626'). OA FL @ NS Bled OA to 450 psi in 3 min (gas). SI multiple times to allow gas to break out. Pressured up OA to 1800 psi with 0.8 bbl of diesel. Start T/I/O = 260/1150/1800 15 min T/I/O = 260/1150/1745 (-55) 30 min T/I/O = 260/1150/1740 (-5) Pass Bled OA to 480 psi (diesel). End T/I/O = 260/1150/480 Double blocked AL line and stacked T x IA in 60 min to T/I/O = 1160/1160/450. IA FL @ Same Location. Bled AL line. Bled IA to 740 psi in 60 min. IA FL @ 6098' (1991' inflow). T FL @ 7924'. Continued bleeding to 660 psi in an additional 16 min. Start T/I/O = SI 1140/660/440 15 min T/I/O = SI 1150/710/440 (+10/+50/0) IA FL @ 5797 (inflow 301'). TFL @ 8078 (outflow 154') 30 min T/I/O = SI 1150/720/440 (0/+10/0) IA FL @ 5994' (outflow 197' ). T FL @ 8230' (outflow 143') Final T/I/O = SI 1150/720/440 01/04/18 PERFORM LDL f/9778' RKB TO SURFACE. IDENTIFIED TBG LEAK @ 9728' RKB. CMIT TBG x IA 2500 PSI (( PASS )) READY FOR E/L. BEGIN CMIT. INITIAL T/I/O/FL= 1700/1775/420/300 LRS PT TBG/IA TO 2500 PSI W/ . START = 2600/2675/420/300 15 MIN = 2560/2650/420/300 30 MIN =2560/2654/420/300 01/05/18 24-ARM CALIPER LOG: LOG REPEAT PASS OVER INTERVAL 9774' - 9575', LOG MAIN PASS OVER INTERVAL 9774' - SURFACE 02/28/18 BRUSH N FLUSH PATCH INTERVAL W/HOT SEAWATER. SET LOWER 2.72" PIIP MID ELEMENT @ 9735' RKB. SET UPPER 2.72" PIIP PATCH ASSEMBLY MID ELEMENT 9706' RKB. IN PROGRESS. 03/01/18 SET 3" TEST TOOL IN UPPER PACKER @ 9706' RKB. MITT TBG 2700 PSI ( PASS ) CMIT TBG x IA TO 2700 PSI ( PASS) PULLED TEST TOOL. JOB COMPLETE. LRS, BEGIN MIT TBG 2700 PSI, BEGIN MIT TBG 2700 PSI. INITIAL T/I/O = 2500/2025/460/200 LRS PT TBG. TAKES TWO TESTS, TOTAL OF 4.8 BBLS. START = 2700/2025/460/200 15 MINS = 2610/2025/460/200 30 MINS = 2580/2025/460/200 PASS. RU LRS TO IA. BEGIN CMIT. INITIAL T/I/O/FL =2550/2050/460/200 LRS PT TBG IA TO 2700 PSI W/31 BBLS DSL. START= 2850/2690/500/200 15 MINS = 2780/2625/500/200 30 MINS = 2720/2610/500/200 45 MIN = 2690/2600/600/200 CONFER W/CWG. RETEST 3 TIMES TO OBTAIN PASSING CMIT. START= 2760/2700/480/200 15 MINS = 2750/2660/480/200 30 MINS = 2750/2650/480/200 PASS. Executive A 29' TTS retrievable packer was installed to cover a leak at 9728'. Integrity of the patch was Summary confirmed with MITT/CMIT pressure tests. • KUP PROD • 2T-20 ConocoPhillips ® \\ Well Attributes IMax Angle&MD TD � Wellbore API/UWI Field Name Wellbore Status hIrn cl I°) MD(ftKB) Act Btm(RKB) Alaska.Inc. 501032021500 KUPARUK RIVER UNIT PROD Il 69.88 4,925.00 10 235.0 crrocAttfilBps Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ... SSSV:NIPPLE 70 12/5/2016 Last WO: 47.89 5/25/1995 2T-20,3/5/201811.11:11 AM Last Tag Vertical schematic(actual) Annotation Depth(ftKB) End Date Last Mod By Last Tag:RKB 9,951.0 2/17/2018 famaj .........................................................................................................._........ Last Rev Reason Annotation End Date Last Mod By it: r _ Rev Reason:Patch installation 3/5/2018 famaj HANGER;36.8 i.11-. Casing Strings Casing Description 00(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 CONDUCTOR 16 15.062 40.0 121.0 121.0 62.58 H-40 WELDED 1U Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread • ' .,,,1iiik SURFACE 9 5/8 8.679 39.5 4,376.0 2,958.0 40.00 L-80 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(RKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �'✓CONDUCTOR;40.0.121.0 III 111 .nz✓�PRODUCTION 7 6.276 30.4 10,224.7 6,071.2 26.00 L-80 BTC-mod Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(R..'Set Depth(ND)(...Wt(Ib/1't) Grade Top Connection IM NIPPLE;508.4 s TUBING 31/2 2.992 36.8 9,787.7 5,732.2 9.30 L-80 EUE-abm lb ■ Completion Details Top(TVD) Top Incl Nominal Top(RKB) (ftKB) (°) Item Des Com ID(in) GAS LIFT;2,099.6 36.8 36.8 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 506.4 506.3 3.38 NIPPLE CAMCO DS NIPPLE w/2.856"NO GO 2.812 9,755.4 5,707.7 40.78 NIPPLE CAMCO W-1 NIPPLE 2.812 9,763.5 5,713.9 40.76 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 9,764.4 5,714.6 40.75 PACKER BAKER SAB-3 PACKER 4.000 9,777.7 5,724.6 40.72 NIPPLE CAMCO D NIPPLE w/2.795"NO GO 2.750 SURFACE;39.5-4,376.0- 9,786.8 5,731.5 40.71 SOS BAKER SHEAR OUT ELMD©9783'PER SWS GR/CCL LOG 2.992 6/2/1995 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) GAS LIFT;1012.4 Top(ND) Top Incl I Top(RKB) (ftKB) (°) Des Com Run Date ID(in) 9,706.0 5,670.4 41.12 PATCH 2.72"P2P#CPP35021,24.5'Spacer Pipe,Latch 2/28/2018 1.625 �I Assembly#CPAL35076.29'OAL,1.625"ID GAS LIFT;6.625.5 tY 9,735.0 5,692.3 40.88 PATCH 2.72"P2P#CPP35058 4'OAL 1.625"ID 2/28/2018 1.625 alPerforations&Slots Shot GAS LIFT;8101 4 Dens Top(ND) Btm(ND) (shots#t Top(RKB) Btm(RKB) (ftKB) (RKB) Zone Date ) Type Com 9,878.0 9,916.0 5,800.7 5,829.7 A-4,A-3,2T-20 6/2/1995 6.0 IPERF 2 1/8"Enerjet;90 deg.ph; GAS LIFT;9,167.7 (+/-)45 deg from lowside 9,892.0 9,912.0 5,811.4 5,826.7 A-3,2T-20 6/9/1995 4.0 RPERF 21/8"Enfreo ;Odented(+/-) 90 deg.from lowside 9,943.0 9,967.0 5,850.5 5,869.0 A-2,2T-20 '9/2/2002 6.0 APERF 2.5"PJ,60 Deg phase Mandrel Inserts at ti on Tap(ND) Valve Latch Port Size TRO Run GAS LIFT;8,710.1 N Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com PATCH;9,706.0- 1 2,099.6- 1,902.4 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,268.0 12/14/2015 2 5,012.4 3,211.2 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,290.0 12/15/2015 3 6,625.5 4,012.8 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 12/25/2017 PATCH;9,735.0 4 8,101.4 4,736.5 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 12/17/2015 5 9,167.7 5,287.4 CAMCO KBUG 1 GAS LIFT DMY BKS 0.000 0.0 12/21/2008 NIPPLE;9755.4 6 9,7)0.1 5,673.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 12/21/2008 SEAL ASSY;9,763.5 Notes:General&Safety End Date Annotation PACKER;9.764.a 12/8/2010 NOTE:VIEW SCHEMATIC wlAlaska Schematic9.0 12/25/2017 NOTE:W/HOLEFINDER DETERMINE TBG LEAK BETWEEN 9755'-9724'RKB NIPPLE;9,777.7 SOS;9,786.8ni IPERF;9,878.0-9,916.0 RPERF;9,892.0.9,912.0 APERF;9,943.0.9,987.0 PRODUCTION;30.4-10,224.7 0 • PI 10 a) p 6- co - X' • > c " CrID al CU 0 " waw ° „, coo Y coY O v E v C > (Q N 0 a a C C -' o II sQ CO + o 0 J w co co co co co ,_ .1-, a) c O0- s7 m 41 N L a) u J Q C C C C C C +, L -O ,..,- t N _..� G @ .1--, L �" 7 7 7 7et ea to co cc; ? 4-• C L n5 N M 1°°• V N to co coo O +•' L cu 0 C Zu gO f0 O u z v -0 a) N 0 0 0 0 0 0 C L. v N L LIJa J J J J J J 00 C w. 0 y W W W W W W 0a) •L I- LL LL LL LL LL LL }. a) a) a) -O Q .Q > L ) a t O N C 4_ w Oc Q z Q Q z Q u co ) 0 v o tw ., r0 +u) > +OC -� a) - N _c O .a u O z` a C u j ...� U O!! C O 4- c0 F-'1 ,_ a) Y u L c 0 " a���,,,„„„� 1.... C r0 a 4-, O t0 _ 1 Q a) a N C a LL LL rCZI is " L+ C" P 00 1 OO, 2 •LL LL a • 0. O 2 N m ko V w - m a a V V a d *-t a > �i E. o� r w wasr Z° u 01 `a o{ > > . z.� CAS co ,"' a J O J J O O `°w -i ra '� Z� › — EEE I G. 0.1 - ,a W j 0° CD EP cc cc cc cr cc cc �▪ - W W W W W W 4 3 0I L" > > > > > 2' /X W IX Ce CZ Ce U • Z Y Y Y Y Y Y > > > > > > Ot wQ Q Q Q Q Q 91 sl N > 0 41 a d LL d d a 7 ma W X in • U y. 0 0 0 0 0 0 =C N 0. o O o 0 0 o ar Y wIt' r• r D O 'O 0 0 • v w 0 0 0 0 0 0 Co Z O ) QW C W _' o O t0 O O O O M V O 5= Kf N 4 h I. .71trl 0• M N N M w I , O r, M M O O M C) 0 u N N N N N N N 10 N N M ce)O O O al N O N N O O N N L Q1 O O a- a- O O 7 0 0 0 0 0 0 y, O a) ro. w co C In In In In In In a U +' co L _ I1- r0 1 I I I 1 I 1 I _ U @ a)i Z d t a., d Op w 4 L u ~ a O W N et L.a) 3 C W E z N b0 Kt z ,- ti N � I= a! Z C a < O N -J 6J ' N N r m ro L ro !Z �110 r- Z N 1 �1� .-i L w r• C �.., '= v ''r @ .L al c6 0 COD a G Ot H a a Q Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: ~si ~ ~ • • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 o ~-~ August 1, 2010 ,a /,~ Commissioner Dan Seamount ~`~~~ Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 ~; ZO~~k Anchorage, AK 99501 ,:, :, ~ ~ a `~ ~ ~: ~; "~' ` ~ to~~ . ~ ~,, . . J - ~~~ ~ Cuss ~~~~~~~ ~~~c~-~r~ge Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 pct ~k ~r oen Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n!a 2.6 7!30!2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 ~~~~~~~~~~ I ~ ~ Schlumberger -DCS 2525 Gambell Street, Suite 400 _ Anchorage, AK 99503-2838 ATTN: Beth ~~~; ~(}~ ~ ~ 2~~~ Well Job # Log Description - , „ "_ ,; Date N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk BL Color CD 10/15/07 2N-343 (REDO) 16-14 1A-18 11745232 11837493 11839651 MEM INJECTION PROFILE ` 'S C - PRODUCTION PROFILE - ~ - PRODUCTION PROFILE (~ - 08108107 08/27/07 08/30/07 1 1 1 1Y-18 11837499 PRODUCTION PROFILE ~~ " 08130107 1 1G-14 11839652 INJECTION PROFILE ~~, "~~j- ~ 08131/07 1 1A-01 NIA USIT - 08/31/07 1 1Y-04 1Y-32 2T-TAB-01 11839653 11839655 11839656 INJECTION PROFILE f~ ~- PRODUCTION PROFILE '`S - INJECTION PROFILE C - - 09!01!07 09102/07 09/03/07 1 1 1 2K-25 11846439 INJECTION PROFILE („) = l 09/06/07 1 2K-18 11846440 INJECTION PROFILE / -~(j 09/07/07 1 1B-18 2T-20 2N-310 11846441 11848442 11850433 PRODUCTION PROFILE < - (p PRODUCTION PROFILE ,J - SONIC SCANNER 76'~-(~ 75 09108107 09/09/07 09!16!07 1 1 1 2N-310 11850433 SONIC SCANNER-FMI ~ - ~7`-j (~ 09/16/07 1 1J-176 11848443 USIT "3 -p 09/17/07 1 1E-29 NIA UCI ~ - ~ 09/19/07 1 3F-21 11837503 RST/ WFL - 09120107 1 2B-10 11839661 INJECTION PROFILE ~ - 09/22/07 1 1G-05 11837506 INJECTION PROFILE ~J=C - 09/23/07 1 2H-13 11839662 INJECTION PROFIL ~ - 09/23107 1 16-05 11837508 INJECTION PROFILE j.,.L. 09/24/07 1 3H-O8 11839663 PRODUCTION PROFILE - J 09/24/07 1 1Y-31 11839664 PRODUCTION PROFILE j ~` - 09/25/07 1 1G-06 11839665 INJECTION PROFILE 09126/07 1 2Z-01A 11837512 USIT - j ( 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER '~~(- 09/28/07 1 1G-11 11837513 PRODUGTION PROFILE - 09129107 1 1Y-22 11837515 PRODUCTION PROFILE (~ 09/30/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 1, 2002 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-20 (195-029) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the KRU well 2T-20. If there are any questions, please contact me at 263-4574. Sincerely, Wells Team Leader Phillips Drilling MM/skad NOV 0 5 ,?.002 RECEIVED OCT 0 ~ 2002 0~! & Ilm~ ~. ~mmi~mm A~ehomoe STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging_ Perforate _XX Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Conoco Phillips Alaska, Inc. Development __ X RKB 122 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service Kuparuk Unit 4. Location of well at surface 8. Well number 66' FNL, 4724' FEL, Sec. 12, T11 N, R8E , UM (asp's 498945, 5969913) 2T-20 At top of productive interval 9. Permit number / approval number 1450' FSL, 1873' FEL, Sec. 36, T12N, R8E, UM 195-029/ At effective depth 10. APl number 50-103-20215 At total depth 11. Field / Pool 3626' FNL, 1778' FEL, Sec. 36, T12N, R8E, UM (asp's 501886, 5976913) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 10235 feet Plugs (measured) true vertical 6044 feet Effective depth: measured 10056 feet Junk (measured) true vertical 5902 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 80' 16" 230 sxAS1 80' 121' SUP. CASING 4337' 9-5/8" 840 sx AS III, 670 sx Class G 4376' 2949' PROD. CASING 10186' 7" 284 sx Class G 10225' 6036' Perforation depth: measured 9878' - 9916', 9943' - 9967' true vertical 5765' - 5794', 5816' - 5835' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Tbg @ 9788' MD. OCT 0 Packers & SSSV (type & measured depth) Baker KBH-22 Anchor seal assy @ 9764' CAMCO 'DS' NIPPLE NO GO @ 506' MD. ~1~1, 0il ~ G{~I~ [~on~. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 679 1907 136 315 Subsequent to operation 1336 2705 731 369 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ X Gas __ Suspended __ Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Mike Mooney 263-4574 Signed ~.. j~ Title: W ellsTeamLeader Date Michael Mooney Prepared b~, Sharon AIIsup-Drake 263-4612 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Date Comment 2T-20 Event History 08/27/02 08/29/02 08/30/02 09/01/02 09/02/02 TAGGED HYDRATES @ 2073' WLM [HYDRATES-ICE] PERFORMED A FOO TO 10,104.2' CTMD. APROX. 188' BELOW PERF'S. RETURNS = SCALE, SOME CARBOLITE, PLENTY OF FINE FORMATION SAND. LEAVE WELL SHUT IN FOR ADD PERF'S. WELL FREEZE PROTECTED TO 4578' MD. [HYDRATES-ICE, FCO] DRIFT TBG W/23' X 2.63" HCDG, TAGGED FILL @ 10056' RKB EST. 144' RAT HOLE, COMPLETE [TAG] PERFORATED: 9953' - 9967', 6 SPF PJ, UNABLE TO GET DOWN PAST 9330' ON SECOND RUN, WILL PUMP DIESEL AND TRY AGAIN. [PERF] PERFORATED: 9943' - 9953', 6 SPF POWERJET. PUMPED 85 BBLS OF DIESEL THE NIGHT BEFORE DOWN TUBING TO HELP CLEAN UP TUBULARS. HAD TIGHT SPOT BETWEEN 6300' - 6600' MD. [PERF] Page 1 of I 9/30/2002 01' BEFORE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Ron Marquez Production Engineering Supervisor Kuparuk River Unit NSK 69 Phone 659-7226 Fax 659-7314 October 19, 1999 Mr. Robert N. Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Christenson: Attached in duplicate are Report of Sundry Approvals (Form 10-404) for the following Kuparuk and Tarn wells: Well Action Well Action 2T-20 Stimulate 3G-03 Stimulate 3A-17 Perforate 2M-15 Perforate 3N-11 Perforate 2M-21 Perforate 3J- 18 Perforate 1 E-36 Perforate 3G-03 Perforate If you have any questions, please call me at 276-1215, ext. 7226. Sincerely, ineering Supervisor ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__~X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well Other 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X__~. 41' RKB, 81' Pad 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK 99510-0360 Service _ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 68' FNL, 556' FWL, Sec 12, T11 N, R8E, UM 2T-20 At top of productive interval: 9. Permit number/approval number: 1450' FSL, 1873' FEL, Sec 36, T12N, R8E, UM 95-29 At effective depth: 10. APl number: 1630' FSL, 1874' FEL, Sec 36, T12N, R8E, UM 50-103-20215-00 At total depth: ! 1. Field/Pool: 1654' FSL, 1821' FEL, Sec 36, T12N, R8E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10235 feet Plugs (measured) None true vertical 6044 feet Effective Depfl measured 10141 feet Junk (measured) None true vertical 5970 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 230 Sx AS I 121' 121' Surface 4337' 9.625" 840 Sx AS III & 4376' 2949' 670 Sx Class G . Production 10186' 7" 284 Sx Class G 10225' 6036' Liner Perforation Depth measured 9878'-9916'; 9892'-9912' true vertical 5766'-5795'; 5777'-5792' -,'~ Tubing (size, grade, and measured depth) 3.5", 9.3 lb/fi, L-80 @ 9788' Packers and SSSV (type and measured depth) Pkr: Baker KBH-22 Anchor Seal Assy @ 9764'; SSSV: None, nipple @ 506' 13. Stimulation or cement squeeze summary ' ~.~, - Fracture stimulate 'A' sands on 7/3/98. Intervals treated (measured) ~!.~'l' ? '7 1000 9878'-9916'; 9892'-9912' Treatment description including volumes used and final pressure Pumped 213751 lbs of 16/20 and 12/18 ceramic proppant into formation, final pressure was 4000 ps~~$]('3~'~ 0il & fias 14. Representitive Doily Average Production or Injection Data OiI-Bbl Gas-Mot WQter-Bbl Casing Pressure Tubing Pressure Prior to well operation 1146 1097 118 1161 283 Subsequent to operation 1428 1295 168 968 273 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~X Oil X Gas Suspended Service 17. I here~0y certify that the foregoing is true and correct to the best of my knowledge. Signed 1 Title: Production Engineering Supervisor Date SUBMIT IN DUPLiCATF_%. ~ . aska, Inc. -- KUPARUK RIVER UNIT 4k, · SERVICE REPORT K1(2T-20(W4-6)) WELL JOB SCOPE JOB NUMBER 2T-20 FRAC, FRAC SUPPORT 0625981525.10 DATE DAILY WORK UNIT NUMBER 07/03/98 "A" SAND REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes ONeI (~Yes {~No DS-GA L LEG OS CH _~rt,Y~ FIELD AFC# CC# DAILY COST ACCUM COST Si ESTIMATE KD2468 230DS28TL $131,904 $134,600 ~-' Initial Tbg Pros$ Final Tbg Pro~ Initial Innor Ann Final Inner Ann ~ Initial uumr Ann I Final Outor A 25 PSI 500 PSI 500 PSI 500 PSI~ 0 PSI I ~PSl DALLY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 213751 LBS OF PROP IN THE FORM W/144f PPA OF #12/18 @ THE'PERF'S. MAXIMUM PRESSURE 4000 PSI & F.G. (.58) FREEZE PROTECTED TBG W/44 BBLS OF DIESEL DOWN TO 5000'. [Frac-Refrac] TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCK. HELD SAFETY MEETING (17 PEOPLE ON LOCATION). 09:30 PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI. RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9800 PSI. 10:30 11:15 12:15 14:30 PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. VOLUME PUMPED 442 BBLS. USED 6167 LBS OF #16/20 OF PROP FOR SCOURING. MAXIMUM PRESSURE 4100 PSI AND ENDING PRESSURE 2200 PSI. STEPPED RATE DOWN AND S/D. OBTAINED ISIP OF 774 PSi W/F.G. @ (.58). PULSED FOR CLOSURE AND MONITORED WHTP. CLOSURE TIME 8.46 MINS @ 440 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 225 BBLS. MAXIMUM PRESSURE 3200 PSI AND ENDING PRESSURE 2300 PSI. S/D AND OBTAINED ISIP OF 883 PSI W/F.G. @ (.59). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 10.8 MINS @ 604 PSI. PAD VOLUME = 680 BBLS. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. VOLUME PUMPED 1715 BBLS. MAXIMUM PRESSURE 4000 PSI AND ENDING PRESSURE 3000 PSI. PUMPED 214806 LBS OF PROP (12955 LBS OF #16/20 & 201851 LBS OF #12/18). INJECTED 213751 LBS OF PROP IN THE FORMATION W/14# PPA OF 12/18# @ THE PERF'S. LEFT 1051 LBS OF PROP IN THE WELLBORE, ESTIMATE FILL TO BE @ 9832' W/BHP OF 1750 PSI. FREEZE PROTECTED TBG W/44 BBLS OF DIESEL DOWN TO 5000'. STARTED R/D. DEPRESSURED THE 7" CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. 15:30 REMOVED TREESAVER (ALL CUPS RETURNED). 16:30 R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $420.00 APC $5,400.00 $5,400.00 DIESEL $300.00 $300.00 DOWELL $124,114.03 $124,114.03 HALLIBURTON $0.00 $1,866.00 LITTLE RED $2,090.00 $2,500.00 TOTAL FIELD ESTIMATE $131,904.03 $134,600.03 95--~029 CDR !.. a.a. oo-~.i0200 q a ..... 029 mD IR/F .I,H At,.,. I 0 ~t 0'7 iR COI~F'L.E'FION DATE .': /} ,: /~,, ,/ Ape dr'y b! a s t h e A r'e ,¢,/e l 1 We 'J 'l '~ s C 5.;, Iq 1~t E N T S DAIL. Y WEI....L OPS ,. iR ;/ ~,x- /'/', / , · ctq~tch sampl es F'equ~ i-"ed'? yes T O nd r'ece-i: ved2 \,,/e 'J I c o r" e ,:::t ? yes ~, no Aha y;'is &. c: : ..~ e S C F" 'i' p 'I}. 'i' () f"~ r' (-Y ~': (~} "i' v' ,? d '-;':, t e s '!: ::s r' ,.'-.s q u 'i r' e d ? y e s 'in c o mp 'i i a n c e i/- ~ Z n '¥ t 'f a 'l fib ~ e c e 'f v e d '? yEa. S DO /! n 0 i'l 0 STATE OF ALASKA AL~r,,A OIL AND GAS CONSERVATION COMi~,,...SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Clesslfk:ation of Servlca Well OIL [~] GAS [~1 SUSPENDED [] ABANDONED ~] SERVICE [---] ~ // '~ 2 Name of Operator :7 Permit Nu~l~r ~'/i/., ARCO Alaska, Inc 95-29 3 Address 8 APl Number P.O. 1003 0, Ancho ag,,, AK $10-03 0 50-103-20215 4 Location of well at surface i-~?. ~ ..........~~:~ ., 9 Unit or Lease Name ~ £,~ ~,: ~. ,- - ........ · - 68' FNL, 556' FWL, Sec. 12, T11N, R8E, UM i .,... D'VFE~ ~ Kuparuk River At Top Producing Interval~ ~'~ ~r ~ ~/~ /~/ ~ !:~~ 10 Well Number 1450' FSL, 1873' FEL, Sec. 36, T12N, RSE, UM ! '¥~I~!? I 2T-20 At Total Depth i ~-~-.~--~--~ ! ~" ' 11 Reid and Pool 1654' FSL, 1821' FEL, Sec. 36, T12N, RSE, UM KUPARUK RIVER 5 Elevation In feet (Indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER RKB 41', Pad 81' ADL 25548 ALK 2662 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. I 15 Water Deplh, If of/shorn J18 No. of Completions 1 5-Mar-95 22-Mar-95 6/2/95 (perf'd)I NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 DlrectionalSurvey 120 DeplhwhereSSSVset I 21 Thlcknessofperrnafrost 10235' MD & 6044"1'VD 10141' MD & 5970' TVD YES ~ NO UI NA f~et MDI 1380' ss APPROX 22 Type Electric or Other Logs Run GRJCDR 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM ~ SIZE CE]VENT FECORD 16" 62.5# H-,40 Surf. 121' 24" 230 sx AS I 9.625" 40.0# L-80 Surf. 4376' 12.25" 840 sx AS III Lead, 670 s~ Class G Tail 7" 26.0# L-80 Surf. 10225' 8.5" 284 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET (MD) 3-1/2' 9788' 9764' 9878'- 9892' MD 5765'- 5776' TVD 6 spf 9892' - 9912' MD 5776' - 5791' TVD 4 spf ~25 ACID, FRACTURE, CEMENT SQUEEZE, ETC 9912' - 99~6' MD 5791' - 5794' TVD 6 spf OEPTH INTERVAL (MD) AMOUNT & KIND O~ MATERIAL USED 9878' - 9916' 12MLbs 20/40, 175 MLbs 12/18, 16MLbs 10/14 27 PRODUCTION TEST Date First Production .. IMethod of Of~eration (Flowing, gas lift, etc.) I 6J12/95 I FLOWING , Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO 7/23/95 11 TEST PERIOD I~ 1450 1166 0 124I 805 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl ((:orr) Press 351 1396 24-HOUR RATE I~ 3163 2545 0 24.0~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparont dips and presence of oil, gas or water. Submit core chips. · 1 0 1995 Alaska 0ii & Gas Cons, C0mmissio, Anchorage -- Form 10-407 Submit In duplicate Rev. 7-1-80 ~ ON REVERSE SIDE 30. (~-OL~ ~RS FORM'nON TESTS N/~E Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRtJE VERT. DEPTH GOR, and time of each phase. Top Kuparuk A 9860' 5752' Bottom Kuparuk A 10028' 5882' 31. LIST OF ATTACHMENTS Directional Survey, Daih/Drillin~ Histor7 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. INSTRUCTIONS GeneraE 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- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date:05/01/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-20 RIG:PARKER 245 WELLID: AK8125 AFE: *AK8125 TYPE:DEV AREA/CNTY:NORTH SLOPE FIELD: KUPARUKRIVER SPUD:03/15/95 START COMP: FINAL: AUG 1 0 1995 ~tm Di[ & Gas CoDs. CommissioD AFE EST:$ 1477M/ 1920M STATE:AK API NUMBER: 50-103-20215 03/16/95 (1) TD: 802'(802) SUPV:RLM 03/17/95 ( 2) TD: 4233' (3431) SUPV: RLM 03/18/95 (3) TD: 4391' (158) SUPV: RLM 03/19/95 (4) TD: 4391'( 0) SUPV:RLM 03/20/95 (5) TD:. 4947' (556) SUPV: RLM 03/21/95 ( ~ TD: 8198' (3251) SUPV: PJ24 03/22/95 (7) TD: 9275' (1077) SUPV: JT 03/23/95 (8) TD:10235' (960) SUPV: JT MW: 10.0 PV/YP: 19/20 APIWL: 12.4 DRILLING Move rig from 2T-19 to 2T-20. Accept rig at 1430 hrs, 3/15/95. Spud at 2230 hfs 3/15/95. Directional drill 12.25" hole from 121' to 802'. DAILY:S77,887 CUM:$77,887 ETD:SO EFC:$1,554,987 MW: 10.0 PV/YP: 28/32 APIWL: 11.6 DRILLING Directional drill 12.25" hole from 802' to 4233' -- DAILY:S81,460 CUM:$159,347 ETD:SO EFC:$1,636,447 MW: 10.1 PV/YP: 28/33 APIWL: 11.6 CEMENTING Directional drill 12.25" hole from 4233' to 4391'. Rig up to run 9.625" casing. Ran 9.625" casing to 4376'. Cement casing. CIP at 634 hrs 3/18/95. DAILY:S159,707 CUM:$319,054 ETD:SO EFC:$1,796,154 MW: 9.1 PV/YP: 8/ 6 APIWL: 14.8 POOH Finish cement job. Do top job on 16" x 9.625" annulus. Nipple up 13 5/8" BOPE. Test all rams, valves. The IBOP did not test and is being rebuilt. DAILY: $131,626 CUM: $450,680 ETD:SO EFC: $1,927,780 MW: 9.2 PV/YP: 13/11 APIWL: 9.8 @'2500' PUMPING OUT OF CSG. Drill float collar at 4298' cement float shoe at 4376' and 10 feet new hole to 4401'. Perform PIT. Rotary drill from 4401' to 4947' . DAILY:S75,574 CUM:$526,254 ETD:SO EFC:$2,003,354 MW: 9.4 PV/YP: 15/11 APIWL: 7.2 DRILLING Pump and ream out of casing. Came from at 2270'. RIH to 4947'. Directional drill 8.5" hole from 4947' to 8198'. DAILY:S97,545 CUM:$623,799 ETD:SO EFC:$2,100,899 MW: 10.9 PV/YP: 18/12 APIWL: 4.8 DRILLING Directional drill 8.5" hole from 8198' to 9275'. DAILY:S87,149 CUM:$710,948 ETD:SO EFC $2,188,048 MW: 11.0 PV/YP: 19/11 APIWL: 4.0 POOH Directional drill 8.5" hole from 9275' to 10235'. POOH to run casing. DAILY: $92,972 CUM: $803,920 ETD:SO EFC: $2,281,020 Date:05/01/95 Page: 2 ARCO Alaska Inc. DAILY DRILLING REPORT 03/24/95 (9) TD:10235' ( 0) SUPV: JT MW: 10.9 PV/YP: 20/12 APIWL: 4.6 LD DP Run 7" casing. CIP @ 2330 hrs. ND BOPE. Install tbg hanger. DAILY:S92,972 CUM:$896,892 ETD:SO EFC:$2,373,992 03/25/95 (10) TD:10235' ( 0) SUPV: JT MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RDMO Freeze protect 2T-20. LD HWDP & DP. Rig released 3/24/95. DAILY: $19,151 CUM: $916,043 ETD:SO EFC: $2,393,143 6/2/95 MIRU SWS. Held safety meeting - caution in heavily congested/high activity area. RIH w/ GR/CCL to make tie-in log. Tie into CDR dated Marl8-Mar 23, 1995. Log 10131' to 9690' ELM. Complete tie-in log; POH. At surf/tool string. Held safety mtg prior to arming gun-radio silence and need for basket to get on top of BOP during rig up while working on temporary set-ups. Made design and spoke w/welder to build needed safety device. Safety seat has been ordered. PT lub to 4800#; test OK. RIH w/gun #1 2-1/8" bh enerjet, 6 spf, 90 deg 'V' ph gun oriented +45/-45 deg from lowside to shoot 9896'-9916'. RIH to 2654' cannot get any deeper; POH to PU add'l wgt. bar. Due to cementing job that is occurring on rig and their need for radio communication, we have parked the gun @ 295' to wait until we can resume radio silence. SWS will load guns while we standby. At surf w/live gun; will add second wgt bar. RIH w/gun #1 with added wgt bar to shoot 9896'-9916'. Tied-in to GR/CCL run earlier; position at 9892' to shoot 9896'-9916'. Pressure tubing to 4700# to shoot overbalanced..Wellhead pressure dropped from 4700# to 600# following gun firing. POH. At surf w/tool string. All shots fired. PT lub to 3000#, test OK. RIH w/gun #2 2-1/8" bh enerjet, 6 spf, 90 deg 'V' ph gun oriented +45/-45 deg from lowside to shoot 9878'-9896'. Had trouble getting down; had to pump gun #2 down due to hole deviation (69 deg @ 4800'). Tied-in to GR/CCL run earlier; position at 9874' to shoot 9878'-9896'. Fire guns; POH. At surf w/tool string. All shots fired. Complete RD. 6/9/95 RU SWS. Held safety meeting - caution around simultaneous operations. PT lub to 3000#; test OK. RIH w/gun #1 2-1/8" enerjet, bh charges, 2 spf, oriented 90 deg CCW from lowside to shoot 9892'-9912'. Not able to get below 2800', POH to PU additional wgt. bar. At surf w/gun #1; PU wgt bar. RIH w/gun #1 and add'l wgt bar; still unable to get down. Called for downhole pump to assist. Downhole pump on loc; attempt to pump gun down. On bottom to tie-in and perf 9892'-9912'. In position @ 9887' to perf 9892'-9912'; fire gun. POH. At surf w/gun #1; all shots fired. PT lub to 3000#; test OK. RIH w/gun #2 2-1/8" enerjet, bh charges, 2 spf, oriented 90 deg CW from lowside to shoot 9892'- 9912'. In poaition @ 9887' to perf 9892'-9912'; fire gun. POH. At surf w/gun #2; all shots fired. RDMO. - End of WellSummary for Well:AK8125 F'A[,'~ NO, MICI OFILME W:LL bLAME 2?-20 L_-tCA?i~ i KLP~:UK LGCATIC~4 2 A~SKA ~,~ D~L!NATiON 28+51 ~-~,~ ~ ~r=~. ~. . W~L F~.~ L.~AT!~q~: LAT(~L/-S) 0.~ D~.P(E/-W) 0.00 ~IP~TH FR~ ROTARY TABLE. 70 TA.R~ET IS 22,~4 D:E:::~:H ft' ft 121,00 256,00 ....... ~x.o A,'-', "5.' I, :'".' . -- 530,00 9'i, O 620,00 90.0 6!9,53 746,00 60~0 2'~4,5G ~01+00 55,0 798+53 92i,30 !20~3 v15,33 !0i2,40 9i,! ii03,70 i196,09 92,4 1289,07 73,0 1383+56 94,5 i477,51 94,0 1570,03 92,5 !758,21 94,3 2T~20 ~ ~. A F,~I , A~lM~n Dgr~URg D!SPLAC~MBh~ a~ '~' ft ft O, O0 O: O.D O, CO ,:.: 0 ='" 13A,,",;' . (, ._) :r _ .~,a !,!0 i,14 !05,74 2,31 2, o,_,.':-'j~,=', oc).. 4,42 /,55 o_,,_,:. 1945,'~ .. ..... ~ 9A~O 2i30+47 9i,8 2224,07 93,6, 2316,09 ?2,0 }-r-. 10 ,:, f t' O, 00 ki + 3/' O,'P9 l :. 73- !,'.:.'3 4578,18 91,5 4669,''~ 9i,2 4752,0! 82,6 4855,'''' I __ £~ 4989,90 i34+7 o Jo_.', IY _, ,.,,', ~: ~D6/+o_q · _-_..,, ,J_, ,_.~,.:-~ 2."'.'93,6[ 4003,3:0' t85,8 LIu:J,0;J ~79,,.-', 4486+71 !83,7 25'78+62' 2503,~0 !87,7 26,92137 !8,516 22,:0,01 2:.::79,4A .....~,.,~ ~.''' + _i ~61,0,:_. 3 ~-,-, z ~ .-. r~ ,~ .... .,_...?, e.~ 2~41,, r' ~':'~?.,~-,., ,~.,,_,~'~ 188,2 2-'!65,2,'_', 2!%,97 63, !3 !9,77 262,70 ~2,4t. 23,09 .... 43 63,78 24,57 '-'..' --'2 ! 02 4-~+-'0 Q: ,'.*, J.: ,; ,.. ** O,.5,g, 0,2 ~.'~, Off /-, -.-: --. bT... +ow o-"+ ,'~ Lb,O:'"" ..... 7_"' i'-'- 7A,5 ~ 769,37 =' ""' ,--.,4., :~- '~'': .~ ... .~O+O'i, ';~* ~ ,.~-/+'--"': au~_-, ,o, 847,' ..... z£ ..-'7 +VO £0,2J / .:~,, !,~ ?~, +..~[ --', ........... '-~-'5 + 4 ?" · ".:' -~+ i'-.--' Y'~, t'7 KEg'-: ;'--- !5,3;-'133 3!8,30 131,71 21,4'i 272.3:} :=6-" {" ~,"n133.., ... :._,,oo :_~ ,~r-' ccc, ~.,, 1652,27 ~-, , ........... c:,:~ /,? 15 ,~,-,, _., ...,.~ ££,0d 0.." .......~ 7510,711 487: _...v=" 42,75 '~2,';";' -,z.?,,.-:"""' '-" i-:-';';'.. 5, SS ........ __ ~ ~,., 2:., '..,_.' ir, .5/~ ii74,34 :q4,2g '"'-' :'- 2-", ~,'~ .... L~., '.,.'£ ~'a ~. './.i ~t-: .. i:..:: ,c-, IWJ,Z4 ....... 3! '"' t'.~. + "iD 13,-~5,63 229,41 26,0,6 P';..,A9 :o:, ~,, ..... -:' ,- ....... ,';,:; n7,22 2, :,~' " ..... i59,>3 36,85 ~ ~= ~,10 1+21 £12*DD £7~t~w . in~,~? ..... ~= 15 2,87 !74,3~ 323,3? 3£~,62 4,6i ~.~ ~.. i- .~, z:4,A~.._ 413! ,o-;"" 29,6-< 4,07. 227 '= ~9C, ~n ~ n? q~:.,(:, ~.. ,~ 289,61 318,i7 6?5,76 27,2! 4,?~ 3D,02 77!,78 -i ,,, . 816,88 1939,94 909,69 2!92,4i 24,51 1+15 ';'AS, 78 o-%? --.., · . I-.~'_/ t/ ~. --'.' 1070,91 oAos.-a 24,09 /_ o/_._,, / ~ . v ..__- !!37,n'~, 2787,'~''.:., 24,07.. 1,04 .,.,.-',58 28.69,97 24,1>' 2~17 -~?n:q.7~ 2'?:-;2,A'? 24 1,4 i ~.~... ,._, ._: ,.. ., .; _i24i,9A. ..,...,_,,,on'--,: v:_. ..'4, :., !2,36,='''..,..- '""24e., ,4.s.. 24,32 2,52 ....... -' 324'4',":.'" 24,44 2:2~ / 3~";' * ," 7 .... i A ..... ~ ,.-'",,", ......... A.,7A ..... 1.~ ,67, .,_..97,.,-" .~, .,I D + ,"Z:* iD+V.: ~.O t k-':: ..... .':-'i ,A3 7,00 .... '~" ~' ?-"": ~" ..... A,: ~',~,7~ .~,77 __ . ---'.'.J , t:"...': ~. .,'--' ,~+7£ .ti~. ."m .,..; - ~ · . . -- ~ ~- ~ , ..-,~-, ~ ,- ad, ~".-, [-<'[-": 3~- ¥,./5 r ~, :1%,'-~ fy', z.,*"-' .-' 7'..." ...... ii, ? ,'-"-' :~0, .'..','~. r.2., --' o ;,.. u ? 4L--', -:--.' o.:, 40,47 ........ ' ..... ': ~'-' '": ' .... /' _.'-, .... .u:,,..-,' 40,00 36 ~::'. i., ,.:,._'. 7,64 · . . ,'"',~, ~t' ,--, -'r, ". F,7 +44 1,6 +05 ~/,/..' 57,3';' 37,70 AA,,A7 ...... , o'..: ..5 ~ ;' '..,' PA~ NO~ 3 .~. ~ ~. : - 7255,90_~.,, 7475,4? ':-.'-SA4.-$: ""-:-- ::-, fi'_ __._-, -W-'i ,5~i' '?,.%0,3& ,,- ,-, :" r~ ~ 7 ...',:'-_'_, 63 5'75.4,43 -' 567 ¥4.1 -" ,-, ,.-, .... ;;- 7q~O 1o~ '.?,,4', 5976 uxb... 301,1 mN. 1 iU:: i~,C.., .?~ , ~:[,,. _z; ft dee de.~ ft ..~O~..".d~£/ ,_,./~.~.: :.._,.-...,., .. . . 3623,= ....... ~ .............. vz. v'-;.o£ LU~/ i ':.,aL,.'.' 9r: r..C, 7~ .'- ~/: .O,q::.-., · _,,.,u'~. ~ --'-t, -~ ..' */~' ].'."' + '%' -~-' ~'~-': '- ~- .'",-.' l r, r,-, ~ 4 ,", ~- -;07'i. 5 ~-.-' fi:V/ ,~-5 --'7 ) ~.'/ 17 + J..~- ~,/ ,.,.~ ,.- 4350,~A 60,01 ~c, a~ ooo:, o: 47qA,s~, %.hz ,51 4374 ~;', _~ ~7 ....... 21 ,,- 54i3,63 Al . ,_.v ;:.z,' ,,~.~. 5] Ja; / +Y~ _ 59_::2'i, ?4 .................... ,., ......... ~,~ z0,76 6065.40 OOC~,~L ~/ ...... 674i,73 ='-',~ ~,' -' ute . - - - ~.' '' ,~1n Oj~/~ 7289,17 ~1,07 24 ~ ...... "~ ,J~V,o6 0/. ~,.~ Z4 __ ..._.0£ 7se?.76 37.63 24,_,% 7(K.0,74 2T-20 E/-W ft ft dec lOC'ft ......... 3242 .... 24,44 * ~" iO~;L,/0 . _ =,c: -,o ...... 23,75 ' ~<' i64'?,41 410A,i3 mc- &= . _ =o~_,~ =.. 13' ,~,.-, r. q'~ =' '-'-' "-' ' 2! :/~J,0:,, 4::.,! £0, '-i---'. ~.J]'i i'~'A ,-,,-, Z-'~ -..: .,_;t-a , ."OFF.) i&73~01 '"-=;' "'"' '-":' '" 0 ?; 4/JO+ 77 ~.,,~ !,2' { - 193i,67 4919,21 2."-':,!2 0:48 l'k?O,?5 ~,'.,oc. ~.r, ~5~ "' 2117.7g = ....',, 90 n'v ~'%~ O~ 5822,13 22.90 n ~,.~,%,.. _itl' ??SA,Al A069,37 ...... n.qr, ......... ££.~D ~., 2451+4~ 6316,01 22,&q 0,4~ 25!9,59 6499,03 22,&i ~c~ ~ i=a,.?6 £~,7o 0.~ ~0 ~"' ' / '~ -~ -? .--.v,,~? 000o,64 ZZ,78 2610,47 z .....· o~ ~ nc. --. ' AO!7 5' '-~' 9,437+46 .......... /,:,/o 4 +0'...' /-'.'Lt L. ~ _'-..' ,., ~_I ,_, L* ~ '.' / 2658,23 695'?,39 22,72 I.'15 2714.i-_='° 7027,6? 22,72 ~', ,.,.,L~ ~.r.. -T~, -7~ .-, 4 ~,,', £/ P...'+/O /()74,QK <,C, ~m 2766.0S 7i,61,21 22,7£ 2,,f, 4 ...... ",~,7 722.5,,f.,0 7'~,71 L/07 . --~- 7~.._:..-., :_, ," . 2&i4,0,5 ._,~ .......... ,:,- ,,,., .., 47 2839,43 ,' ..... c. Ju ,77 ...,,.z,7,.-" 0,43 2'.;'18,00 7540,78 22,77 ~ ,0~ 293%67 75';'2,89. ,.,:,/e, ...... 0,02 · - 07 1995 Naska Oil & Gas Cons. Commission ;:;,..::wY,' .' ARCO Alaska, Inc. Date' May 4, 1995 Transmittal#: 9235 RETURN ~--~ -' --- ARCO Alaska, Inc. Attn: Brian Hebert _ "~ ~ Kuparuk Operations File Clerk ~ ~_ ATe-1119 B P.O. Box 100360 Anchorage, AK 9951 0-0360 Transmitted below are the following open hole items. Please receipt and return one signed copy of this transmittal. ~' 5" "' ,~(~ 2T-20 CDR Final Print 3/18-23/95 Ref# 50-123-20215 CNTG Depth Corrected 9/9/93 Ref#93423 2T-19 CDR Final Print 3/6-1 2/95 Acknowledged: ~~~/~~ Date' DISTRIBUTION' f# - )- 1 MAY 9 995 Alaska Oil & Gas Cons. Commission Anchorage Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development AT0-1205 Clilton Pose'/ Geology ATe 1251 Erickson/Zuspan NSK Central Files NSK 69 Larry Gran! (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lumke AT(;) 1336 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9438 Company: 5/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T-19 95105 CDR 031295 I I 1 2T-20 951 1 3 CDR ~32395 I 1 1 " 1Y-18 93423 REDO CNT-G 090993 1 1 I D F. i\L ~..,I... I V I..I./ :~,;Pi'"EASE NOTE:' MA ~' ~ 5' "~!i~'~'~"~!REpRoCESSED TO INCLUDE'AVERAGE: . · SIGNED: Alaaka 011 & t~as Cons. Commission Anchorage DATE: ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 10, 1995 Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 . Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-20 ARCO Alaska, Inc. Permit No: 95-29 Sur. Loc. 68'FNL, 556'FWL, Sec. 12, TllN, R8E, UM Btmhole Loc. 1769'FSL, 1785'FEL, Sec. 36, T12N, R8E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. · Chairman ~ BY ORDER OF THE COMMISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF N_ASKA AL ._,,~& OIL AND C-.-.-~S CONSERVATION COMMIt. ON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill E] 1 b Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Entry E] Deepen r~ Service [] Development Gas E] Single Zone X Multiple Zone ~ 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation , Kuparuk River Oil Pool P. O. Box 100360, Anchored]e, AK 99510-0360 ADL 25548, ALK 2662 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 68' FNL, 556' FWL, Sec. 12, T11N, RCE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1505' FSL, 1893' FEL, Sec. 36, T12N, RCE, UM 2T-20 #U-630610 At total depth 9. Approximate spud date Amount 1769' FSL, 1785' FEL, Sec. 36, T12N, RCE, UM 3/1 3/95 $200,000 1 2. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2T-1 9 10337' MD 1769' ~ TD feet 9.5' ~ 672.2' MD feet 2560 6082' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 450' feet Maximum hole angle 62.3° Maximum surface 1740 psig At total depth (TVD) 3200 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casinc~ Wei~lht Grade Couplin~ Length MD '[VD MD TVD (include starve dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 4198' 41' 41' 4239' 2940' 760 Sx Arcticset III & HF-ERW 670 Sx Class G 8.5" 7" 26.0# L-80 BTCMOE 10296 41' 41' 10337' 6082' 270 Sx ClassG HF-ERW Top 500' above Kuparuk 1 9. 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 (~:nU;tu~;rt~lrR Ed E iV E O Surface Intermediate ProductionMAR -2 1995 Liner Perforation depth: measured Alaska, 0il & Gas Cons. Commission true verticalAnch0rape 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r~ Refraction analysis E] Seabed report E] 20 AAc 25.050 requirements X 21. I hereby certify t~at the f~,regolg is true and correct to the best of my knowledge~ Signed~!/~. ,-~__~._.~ T~tle' Drill Site Develop. Supv. Date ~ ; ,'~'- Commission Use Only Permit Number I AP.l~mber I Approval date . ' - /~ I See cover letter for ?,2- .¢ I --- o.2_ 15' I3'-*t ~" "y ,~Z.'--"I other recluirements Conditions of approval Samples required D Yes J~ No Mud logrequired F~ Yes ,~] No Hydrogen sulfide measures E] Yes J~ No Directional survey required ~ Yes E] No Required working pressure forBOPE E] 2M J~ 3M E~ 5M [-~ 10M [--~ 15M Other:Original Signed By David W. Johnston by order of j// '/~/.----- Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit, tri[~licate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 2T-20 o , . 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,239')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (10,337') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED .,,~.:¢~ Oil & 6as Cons. Commission Anchor.-'. ' DRILLING FLUID PROGRAM Well 2T-20 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing . 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +_10% Drill out to wei~lht up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.2 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,740 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2T-20 is 2T-19. As designed, the minimum distance between the two wells would be 9.5'@ 672' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will either be filled with diesel upon completion of fluid pumping. If isolation is reqired per regulations on significant hydrocarbons, the annulus will be sealed with cement from the top of hydrocarbons to the base of the permafrost, with Arctic pack or diesel above to the surface. Risks in the 2T-20 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill grave~:)~_.; E IV E D ,, Anchor; I I ¥ ARCO ALASKA, Inc. Structure : Pod 2T Well : 20 Field : Kuparuk River Unif Location : North Slope, Alaska Created by : jones For: D PET~ASH Dote plotted : 14--Feb-95 Plot Reference is 20 Version #8. Coordinates ore in feet reference slot #20. 'True Vertical Depths ore reference Estimated RKB. --- Baker Hughes INTEO --- N 22.44 DEG E 7415' (TO TARGET) ***PLANE OF PROPOSN_*** 400 .q 6400 400 KOP TVD=450 TMD=450 DEP=O 5.96 BEGIN TURN TO TARGET TVD=616 TMD=617 OEP=7 3 BEG / 100' DIS 29.78 B/ PERI~OST WD=1505 TMD-1564 DEP=312 35.77 T/ UGNU SNDS WD=1548 TMD=I618 0EP=342 41.77 47.76 55.76 59.75 EOC'i~-2150 TMDI2536 DEP-1024 T/W SAK SNDS W9=2229 TM0=2708 DEP=1176 B/ W SAK SNDS TV0=2701 TMD=3724 DEP=2076 9 5/8" CASING PT WD-2940TMD-4239 DEP-2532 K-lO 3~1)=3090 TMD-4662 0EP-2815 MAXIMUM ANGLE 62.34 DEG TARGET ANGLE 40 DEG 54.00 _ DROP 2 DEC / 100' ~0.00 ,~',,~,~i~a i~ij & Gas Co,is. TVD=574~ TM9=9893 DEP=?415_ TARGET - T/ ZONE C (EOD) r/ ZON[ A W0=5795 TM0=9962 - .-- ,.~,Anchnr: T/ ~ SNDS ~=5815 mD=ggSS 0EP=7474 -- B/ KUP SNDS ~-592g ~0-10137 DEP-7572 I I I I I I I I I I I I I I / I I I I I I 4000 4400 4800 5200 5600 6000 64006800 7200 7600 8000 Scale 1 : 175.00 350 0 550 700 I I I I I I Scale 1 : 200.00 Vertical Section on 22.44 azimuth with reference 0.00 N, 0.00 E from slot #20 Easf 1050 1400 75O I --> 2100 I I TD LOCATION: 1769' FSL, 1785' FEL SEC. 36, T12N, RSE TARGET LOCA~ON: 1505' FS~ 189Y FEL SEC. 36. T12N, R8E TARGET W0=5742 TM0-9893 DEP=7415 NORTH 6853 F.~ST 2851 ESTIMATED SURFACE LOCATION: 68' FNL, 556' FWL SEC. 12, TllN, RSE 2450 2800 I I I I 3150 I I _7350 _7000 _6650 5600 5250 .4900 _4200 _ _ _ .3150 _ _2800 2100 _ _1750 _ _ _1050 _ _ 700 _ _ 350 0 I I Z 0 K-5 TV0=4543 TMD=7692 OEP=5590 RECEIVED I I i I I I I I I I I I I I I I I I I I 0 400 800 1200 1600 2000 2400 2800 5200 3600 Created by : jones Date plotted : 14-Feb-g5 Plot Reference is 20 Version #8. Coordina[es are in feet reference slot #20. ,True Vertical Depths are reference Estimated RKB.I I --- Baker Hughes INTEQ --- ARCO ALASKA, Inc.'., Sfrucfure : Pad 2T Well : 20 i Field : Kuparuk River Unif Location : North Slope, Alaskai A I I Scale 1 : 10.00 12o lOO 80 400 I ~ ~ I I 380. · 360. _ 340_ _ 320_ _ 300_ _ 280_ _ 2ao~ _ 240. _ 220. 180_ - 14.0_ _ 120_ 40_ 80 120 100 80 Scale 1 : 10.00 I I East --> 40 20 0 20 40 60 80 100 120 140 160 1BO 200 220 I I I I I I I I I I I I I I I I I I I I I f I I I II 40 20 0 20 40 60 80 1 O0 120 140 160 180 200 220 East --> 240 I 260 I 4OO .380 - 340 320 - _SOO - _280 - _260 - _240 _120 20 260 RECEIVED Oil & Gas Cons. Commission ICreated by : jones IDote plot~ed : 14--Feb-95 iPIot Reference is 20 Version iCoordinotes ore in feet reference slot #20. ITrue Vertical Depths ore reference Estimated RKB. --- Baker Hughes INTEQ --- ARCO ALASKA, Inc. Structure : Pad 2T Well : 20 Field : Kuparuk River Unit Location : North Slope, Alaska - 1240_ Scale 1 : 20.00 o 40 80 East =~> 200 240 280 320 360 400 440 4~0 520 560 500 640 680 72O _1280 _ _1240 1 1 960 ~ 920 ~ ~o~ - 640 _ _ 600_ _ 560 _ 520 1900 480 440 400. _ 360 _ 0 4O 8O Scole 1 : 20.00 240 280 5ZO 360 400 440 480 520 560 600 640 680 East --> - - 920 ~ A _ 880 I I ~oo Z 0 760 ~ 72O ECEIVED MAR - 2 1995 Alaska Oil & Gas Cons. Commission Anchora ,~ Casing Design/Cement Calculations 27-Feb-95 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, C Sands, TVD: Estimated Pressure: Surface Casing Choice: Production Csg Choice: Production Casing Frac. Pressure 2T-20 O 4,239 ft 2,940 ft 10,337 ft 6,082 ft 2,708 ft 9,893 ft 5,742 ft 3200 psi ** See Page 4 i I For Casing Choices 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight =[ 2,940 ft 1,740 psi! 3,200.0 ppg 5,742 ft 150 psi 11.2 ppgJ Surface lead' Top West Sak, TMD = 2,708 ft Design lead bottom 500 ft above the Top of West Sak = 2,208 ft Annular area = 0.3132 cf/If Lead length * Annulus area -- 741 cf Excess factor = 100% Cement volume required = 1,482 cf Yield for Permafrost Cmt = 1.94 Cement volume required =1 760 sx! Surface tail' TM D shoe = 4,239 ft (surface TD - 500' above West Sak) * (Annulus area) = 636 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 670 cf Excess factor = 15% Cement volume required = 771 cf Yield for Class G cmt = 1.15 Cement volume required =[ 670 sxJ RECEIVED MAR -2 199,5 0il & Gas Cons. Commission Anchora, .~ Casing Design/Cement Calculations 27-Feb-95 Production tail' TMD = 10,337 ft Top of Target, TMD = 9,893 ft Want TOC 500' above top of target = 9,393 ft 5" casing tail top (100' above C sand) =[ 10,337 ftJ 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 165 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt = 182 cf Excess factor = 75% Cement volume required = 318 cf Yield for Class G cmt = 1.19 Cement volume required =[ 270 sxJ TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy -- Weight of displaced mud Length Casing Wt (Ib/ft) Dead Wt in Air Buoyancy Tension (Pipe Body) Design Factor Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (WVft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =1 Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud RECEIVED rv AR - 2 i995 A!~ska Oil & Gas Cons. Commission Anchor~ '~ Casing Rated For: Length = Casing Wt (Ib/ft)= Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =[ 916OO0 lb 4,239 ft 40.00 Ib/ft 169560.0 lb 28296.3 lb 141263.7 lb 6.51 979000 lb 4,239 ft 40.00 Ib/ft 169560.0 lb 28296.3 lb 141263.7 lb 6.9J 604000 lb 10,337 ft 26.00 Ib/ft 268762.0 lb 45478.7 lb 223283.3 lb 2.71 667000 lb 10,337 ft 26.00 Ib/ft 268762.0 lb 45478.7 lb 223283.3 lb Casing Design / Cement Calculations BUR,~T - Minimvm Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =[ Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure Outside Pressure Net Pressure Design Factor COLLAPSE- Minimum Design Factor = 1.0 Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 27-Feb-95 5750 psi 1740.5 psi 3.3J 7240 psi 7048 psi 2815 psi 4234 psi 1.7J 3090 psi 0.583 Ib/ft 779 psi 4.0J 5410 psi 0.583 Ib/ft 3548 psi 1 .Si RECEIVED MAR -2 1995 A!aska 0il & Gas Cons. Commission Anchor~. ~ Casing Design / Cement Calculations 27-Feb-95 Surface Casing Choices OD ID I b/ft Grade Metal X-Section Jt Strength Body Strength I 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb Collapse Burst 4750 psi 6870 psi 3090 psi 5750 psi 2020 psi 3520 psi 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section Jt Strength Body Strength I 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb I 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb Collapse Burst 5410 psi 7240 psi 10490 psi 10140 psi 4320 psi 4980 psi RECEIVED MAR -2 1995 Aiaska Oil .& Gas Cons. Commission Anchor~,. ',- LIPARUK RIVER UNI' 20" DIVERTER SCHEMATIC 6 I4 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE ~ OPERATION 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. 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. RECEIVED & Gas Cons. Commission Anchor;, ', DKP11~4 I 5 13 5/8" 5000 PS, 3OP STACK ACCUMULATOR CAPACITY TEST 1. CHECKAND 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 CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE 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 LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOl-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT 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 COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE DOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2_ 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSi DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR RECEIVED MAR -2 1995 A!aska Oil & Gas Cons. Commissior~ WELL PERMIT CHECKLIST COMPANY INIT CLASS PROGRAM: exp [] d~ redrll [] aery [] oN,oFF ADMINISTRATION ENGINEERING 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 drlg unit boundary.. 6. Well located proper distance from other wells ..... 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 ....... Conductor strin9 provided ............... ~ N Surface casing protects all known USDWs ........ .y N CMT vol adequate to circulate on conductor & surf os9. N CMT vol adequate to tie-in long string to surf csg . . . Y ~ CMT will cover all known productive horizons ....... Y Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............ ~ N 14. 18. If a re-drill, has a 10-403 for abndnmnt been approved. 21. Adequate wellbore separation proposed ......... 22. If diverter required, is it adequate .......... Drilling fluid program sch~atic & equip list adequate BOPEs adequate ..................... BOPE press rating adequate; test to ~ msig.~ Choke manifold complies w/~I ~-53 (May 84) ...... 23. 24. 25. 26. 27. 28. 29. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N 31. Data presented on potential overpressure zones ..... Y N 32. Seismic analysis 9f shallow gas zones .......... Y N 33. Seabed condition survey (if off-shore) ......... Y N 34. Contact name/phone for weekly progress reports ..... Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ Comments/Instructions: HOW/jo - A:lFORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. P~GE: P ~ G E ~ 439 l. c,. ,i.g~ g7. C 't g t :4 '7 .,i q7 , .." '", ,. . I ! ~ a 68 -999. 250 -99':) -999.250 -999.250 ,r' F T [, ~, ¢' ii,les .4 PAGE ,:; o 5 ¢; . '75.0 75. Cl . ~ , ',. % '.. -"1 i': '~' ~4 [~ ~fi sepay'e~t:'e .fi....l. es, 2'7,0 2.3 1. 0 65.59 75.ri -999,2S0 -999, ,':50 r LID f.5.1es. .1.., 0 (-i :}; ¥' 4. i) C i 0235. r :~ © 2,3 5. 2o31 ,.., 7~ 0 75.0 ll i999,250 PAGe: 12 -999. -999. ~-999.250
