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195-017
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-18 KUPARUK RIV UNIT 2T-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-18 50-103-20213-00-00 195-017-0 W SPT 5759 1950170 3000 2700 2700 2700 2700 660 880 860 860 REQVAR P Adam Earl 6/21/2025 MIT-IA tested as per AIO 2C.023 to max. ant. Inj. Psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-18 Inspection Date: Tubing OA Packer Depth 1350 3400 3350 3350IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625073549 BBL Pumped:2.5 BBL Returned:2.3 Tuesday, July 22, 2025 Page 1 of 1 ORIGINATED TRANSMITTAL DATE: 8/8/2024 ALASKA E-LINE SERVICES TRANSMITTAL #: 4955 42260 Kenai Spur Hwy PO BOX 1481 - Kenai, Alaska 99611 FIELD Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 DELIVERABLE DESCRIPTION TICKET # WELL # API # LOG DESCRIPTION DATE OF LOG 4955 2T-18 50103202130000 Injection Profile (IPROF) 26-Jul-2024 RECIPIENTS Conoco DIGITAL FILES PRINTS CD'S 1 FTP Transfer 0 0 USPS Attn: NSK-69 tom.osterkamp@conocophillips.com 700 G Street Anchorage, AK 99503 Received By: Received By: Signature Signature AOGCC DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resources Technician II abby.bell@alaska.gov Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501 Received By: Received By: Signature Signature 195-017 T39384 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.08 13:25:11 -08'00' DNR DIGITAL FILES PRINTS CD'S 1 SharePoint Link 0 0 USPS Attn: Natural Resource Tech II DOG.Redata@alaska.gov 550 West 7th Ave, Suite #802 - Anchorage, AK 99501 Delivery Method: USPS Received By: Received By: Signature Signature Please return via e-mail a copy to both: AR@ake- line.com tom.osterkamp@conocophillips.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-18 KUPARUK RIV UNIT 2T-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2T-18 50-103-20213-00-00 195-017-0 W SPT 5759 1950170 3000 2510 2510 2510 2510 400 620 620 615 REQVAR P Guy Cook 6/10/2023 MITIA to maximum anticipated injection pressure per AIO 2C.023. Testing was completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-18 Inspection Date: Tubing OA Packer Depth 970 3300 3230 3230IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC230609155140 BBL Pumped:2.7 BBL Returned:2.7 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor ( �`l%z(Z� FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 7, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-18 KUPARUK RIV UNIT 2T-18 Src: Inspector Reviewed Be�y-:� P.I. Suprv`JDFZ— Comm Well Name KUPARUK RIV UNIT 2T-18 API Well Number 50-103-20213-00-00 Inspector Name: Jeff Jones Permit Number: 195-017-0 Inspection Date: 6/5/2021 Insp Num: mitJJ210628155718 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-18 !Type Inj i W. TVD 5759 Tubing 2640 _ 2640 2640 2640 - PTD 1950170 ;Type Testi SPT TTest psi i 3000 IA 820 33403300 3290 BBL Pumped: 3.1 _LBBL Returned: 3 OA 560 810 _ 810 810 — - Interval -_. REQVAR P/F __- P >/ Notes: MITIA to max. injection pressure. AIO 2C.023; T x IA communication. 1 well inspected, no exceptions noted. Wednesday, July 7, 2021 Page I of I MEMORANDUM State of Alaska Packer Alaska Oil and Gas Conservation Commission TO:Jim DATE: Thursday, July 25, 2019 Re G /Q'��y� j 610'1, 1 P.I. Supervisor I SUBJECT: Mechanical Integrity Tests t C ConocoPhillips Alaska, Inc. w •TVDp 2T -I8 FROM: Jeff Jones KUPARUK R1V UNIT 2T-18 Petroleum Inspector 2670 Src: Inspector PTD 1950170 Reviewed By: SH SHsi TestType P.I. Supry ITGC— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-18 Insp Num: mitJ1190725101130 Rel Insp Num: API Well Number 50-103-20213-00-00 Inspector Name: Jeff Jones Permit Number: 195-017-0 Inspection Date: 6/2/2019 Notes: MIT4A to max, anticipated injection press. Per AIO 2C-023. I well inspected, no exceptions noted Thursday, July 25, 2019 . Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-18 YP e In'J w •TVDp -->`� Tuu in 2650 - I g z65o - 2670 PTD 1950170 _ T Test SH SHsi TestType '1100 _ IA 530 3300 - _zb7o 3250 - 3240 BBL Pumped: -35 ' BBL Returned: 3= OA 200 _ 430 • 460 - 460 Interval REQVAR P/F P Notes: MIT4A to max, anticipated injection press. Per AIO 2C-023. I well inspected, no exceptions noted Thursday, July 25, 2019 . Page 1 of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,June 15,2017 P.I.Supervisor /c &C'2"6/1 7 SUBJECT: Mechanical Integrity Tests 1. CONOCOPHILLIPS ALASKA INC 2T-18 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-18 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv '-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-18 API Well Number 50-103-20213-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-017-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607152405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-18 Type Inj W TVD 5759 - Tubing 2610 2600 . 2600 2600 • PTD 1950170 - Type Test SPT Test psi 3000 IA 1000 3300 - 3240 - 3230 BBL Pumped: 2.9 BBL Returned: 3.1 - OA 390 600 - 600 - 590 • Interval REQVAR P/F P Notes: MITIA per AOI 2C.023 to MAID SCANNED EP i 3 20 Thursday,June 15,2017 Page 1 of 1 • , MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: J Regg DATE: Thursday,March 16,2017 P.I.Supervisor M SUBJECT: Mechanical Integrity Tests I L1 11 CONOCOPHILLIPS ALASKA INC 2T-I 8 FROM: Adam Earl KUPARUK RIV UNIT 2T-18 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry WED- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-18API Well Number 50-103-20213-00-00 Inspector Name: Adam Earl .„.- Permit Number: 195-017-0 Inspection Date: 3/13/2017 Insp Num: mitAGE170313162716 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-18 Type Inj W TVD 5759 Tubing 2390 2400 2400 2400 PTD 1950170 Type Test SPT Test psi 3000 IA 960 3300 3265 3250 f BBL Pumped: 2.9 BBL Returned: 2.8 OA 180 400 400 400 Interval REQVAR P/F P Notes: MITIA per AIO 2C.023 SCANNED AUG 2 4 2017 Thursday,March 16,2017 Page 1 of 1 L. _ • 0 v N W V W do y r° >- r° o Y O -0 (0 v v O m O .` o c° 4 ' > L u a Q v o Q6 ,� C Q = M 77 x o .0 v C o m r Q Lo Lo CO 0 CO 0 N t a) u ` J 4 a) a) a) a) a) a) L * V _ w fn (n fn fn N fn CL C VI N un O CA O N O �U., -c aJ z a �- N N N OU -0 CO O .O-+ U cc v > -D v o C r° a -0 N u lit 0 0 0 0 0 0 C v p 0 LLI J J J J J J C • O >. 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February 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501I 3/1 /201C. M.K.BENDER FEB 2 3 2016 AOGCC RE: Multi Finger Caliper: 2T-18 Run Date: 1/17/2016 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-18 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20213-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20213-00 scpasiNED , F 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. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed • • 2(v55 WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 10, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 /C9/2016. K.BENDER RE: Static Bottom Hole Pressure Record: 2T-18 Run Date: 11/8/2015 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-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20213-00 Static Bottom Hole Pressure Record (Field Print) 1 Color Log 50-103-20213-00 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. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: m,d,....4.4) „✓��;,k"_""t Wallace, Chris D (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Monday, May 11, 2015 9:28 AM To: Wallace, Chris D (DOA) Cc: Senden, R. Tyler; NSK Problem Well Supv Subject: KRU 2T-18 (PTD 195-017) Report of IA pressure anomaly Attachments: Picture (Device Independent Bitmap) 1.jpg; 2T-18 90 day TIO plot.jpg; 2T-18 schematic.pdf; MIT KRU 2T-18 Surveillance MITIA 04-16-15.xls ,CANNED MAY 1 12015 Chris, Kuparuk injector 2T-18 (PTD 195-017) was reported with an IA pressure climbing. The original thought was thermally related between the injection temperature going up and later coupled with the increase in choke. With the increase in choke it allowed more heat transfer down hole and may have been a contributed to the rise in IA pressure. It appears the pressure continues to rise requiring bleeds that are no longer suspected to be thermally related. The well has been WAG'd to water and will remain on water injection for 30 days in preparation for an AA. A passing routine surveillance MITIA was performed on 04/16/15. The initial diagnostics will include tubing packoff testing, bleeding the IA down to have a substantial differential pressure and monitor the pressures during the test injection period. Please let me know if you disagree. Attached are a 90 day TIO plot,wellbore schematic, and a copy of the surveillance MITIA. CHOKE FTP FTT IAP T/I/O Plot - 2T-18 OAP _,- 3500 = 3000 2500 r—� N 2000 1500 ---- 1000 G 1000 I\ - rr 500 -; /\/\\ -/\/ 0 - I i I I 1---1--f- ,- -,— ( - , ! I I II 11-Feb-15 24-Feb-15 09-Mar-15 22-Mar-15 04-Apr-15 17-Apr-15 30-Apr-15 Date Brent Rogers/Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone(907)659-7224 Pager(907)659-7000 pgr. 909 WELLS TEAM 2 KUP INJ 2T-18 ConocoPhdbps /a Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UMField Name Wellbore Status ncl(°) MD OMB) Act Btm(ftKB) �, ryypc 501032021300 KUPARUK RIVER UNIT INJ 64.12 4,943.18 10,632.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2T-18,4/29/20143:41-59 PM SSSV:NIPPLE Last WO. 48.49 3/4/1995 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,347.0 4/19/2014 Rev Reason:TAG lehallf 4/29/2014 7::LqiIMW Casing Strings HANGER 36 8 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 41.0 4,293.5 2,8942 40.00 L-80 BTC Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WVLen p...Grade Top Thread PRODUCTION 7 6276 38.7 10,626.6 6,129.4 26.00 L-80 BTC-MOD I Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 31/2 2.992 36.8 10,179.9 5,778.1 9.30 L-80 ABM-EUE . , ._ ....Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(") Item Des Com (in) -A-A-,CONDUCTOR,42.0-121.0.-an-n-,.�' -^^-^-�^ 36.8 36.8 0.22 HANGER FMC GEN IV TUBING HANGER 3.500 514.9 513.0' 8.74 NIPPLE CAMCO DS LANDING NIPPLE 2.812 10,132.9 5,742.7 42.13 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 10,140.9 5,748.7 41.79 PBR BAKER PBR 3.000 NIPPLE:514.9 !1 10,154.6 5,759.0 41.21 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 10,169.9 5,770.5 40.56 NIPPLE CAMCO D NIPPLE NO GO 2.750 10,179.0 5,777.4 40.18 SOS BAKER SHEAR OUT SUB,ELMD TTL @ 10172'during 2.992 PERF RECORD-08/27/01 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shoteM Top(ftKB) Btm(ftKB) (NKB) (ftKB) Zone Date t) Type Com 10,285.0 10,298.0 5,859.5 5,869.7 C-4,2T-18 8/27/2001 4.0 APERF 2.5"HSD,2506 PJ,180 deg phase SURFACE,410-4.293.5 - 10,314.0 10,319.0 5,882.2 5,886.2 A-4,2T-18 9/1/1995 6.0 RPERF 2 1/8"Enerjet;0 deg.ph 10,323.010,324.0 5,889.3 5,890.1 A-3,2T-18 9/1/1995 2.0 RPERF 2 1/8"Enerjet;0 deg.ph 10,324.0 10,353.0 5,890.1 5,913.0 A-3,2T-18 9/1/1995 4.0 RPERF 2 1/8"Enerjet;0 deg.ph OAS LIFT,10,087.5- ` 10,353.0 10,354.0 5,913.0 5,913.8 A-3,2T-18 8/26/1995 2.0 IPERF 2 1/8"Enerjet;0 deg.ph; Oriented(+/-)deg.F/ lowside 10,378.0 10,388.0 5,932.7 5,940.6 A-2,2T-18 9/1/1995 4.0 RPERF 2 1/8"Enerjet;0 deg.ph NIPPLE;10,132.9 Mandrel Inserts ! 1 SI a ti on Top(TVD) Valve Latch Port Sias TRO Run N lop(ftKB) (ftKB) Make Model 00(10) Bern Type Type (in) (psi) Run Date Com PBR;10,140.9 ,, 10,087.5 5,709.6 CAMCO "MMG 1 112 GAS LIFT DMY TG 0.000" 0.0 5/30/1995 Notes:General&Safety PACKER;10,154.6 End Date Annotation 11/12/2010 NOTE.View Schematic w/Alaska Schematic9.0 10/24/2011 NOTE:Welded 3',2"long sleeve on surface pipe from bottom of starter head with X65 10 500 pipe. NIPPLE 10 169 9 SOS,10.1790 APERF,10,285.0-10,298 0--. r. RPERF;10.314.0.10.319.0-. RPERF;10,323.0.10,324.0---,_. RPERF;10,324.0-10,353.0 -- RPERF;10.353.0-10,354.0 -- RPERF;10,378.0-10,388.0 PRODUCTION;38.7-10,028.8 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reaa gnalaska.gov, AOGCC.Insoectorsi8 alaska.00v; phoebe.brooks@alaska.gov chris.wallace@alaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD I UNIT/PAD: Kuparuk/KRU/ 2T Pad DATE: 04/16/15 OPERATOR REP: Manjarrez AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-18 Type Inj. G TVD 5,759' Tubing 3,775 3,775 3,775 3,775 Interval 0 P T.D. 1950170 Type test P Test psi 1500-Casing 1,850 3,000 2,950 2,940 P/F P Notes: Non-witnessed surveillance testing OA 200 300 300 300 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type In). TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Dolling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=lndustnal Wastewater R=Internal Radioactive Tracer Survey V=Required by Vanance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2T-18 Surveillance MITIA 04-16-15.xis 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 ~~or 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~ianna TO RE-SCAN Notes: ~ ~.~ ~--'~(::~(~~.~ Vincent Nathan Lowell Date:¢~.~ Is~ Re-Scanned by: Beverly Dianna Vincent ~)Lowell Date: ~,/"_~ Is~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,June 03,2013 P.I.Supervisor I ( �Z 1 i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-18 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-18 Petroleum inspector Src: Inspector Reviewed By: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-18 API Well Number 50-103-20213-00-00 inspector Name: Lou Grimaldi Permit Number: 195-017-0 Inspection Date: 6/1/2013 Insp Num: mitLG130601140529 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 2T-18 W 5759 1044 2000 '7 1971 1962 " Well IType Inj ,TVD IA PTD 1950170 Type Test l SPT.Test psi! 1500 OA 740 840 850 850 ' Interval 4YRTST IP/F P Tubing 2650 2650 2640 2640 I Notes: 1.24 bbl's diesel pumped, 1.14 bbl's returned.Good solid test,crew well prepared. %MINW FEB '2 0 2014 Monday,June 03,2013 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(rDalaska.gov; AOGCC.Inspectorsnalaska.gov; phoebe.brooks(rDalaska.gov chris.wallace(rDalaska.gov OPERATOR: ConocoPhillips Alaska,Inc FIELD/UNIT/PAD: Kuparuk/KRU/2T Pad 2'Z 61i7--1(3 0 \ DATE: 06/01/13 OPERATOR REP: Freeborn/Hight/Phillips \91‘4. ' , AOGCC REP: Lou Grimaldi 3.4 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-15 Type Inj. W - TVD 5,437' Tubing 2,650 2,650 2,650 2,660 Interval 4 P.T.D. 1860450 _Type test P Test psi 1500 Casing 666 2,002 1,934 1,913 P/F P Notes: OA 80 80 90 90 Well 2T-18 Type Inj. W TVD _ 5,759' Tubing 2,650 2,650 2,640 2,640 Interval 4 P.T.D. 1950170 Type test P _ Test psi 1500 Casing 1,044 2,000 1,971 1,962 P/F P Notes: OA 740 840 850 850 Well 2T-26 Type Inj. W TVD 5,715' Tubing 2,600 2,600 2,620 2,620 Interval 4- P.T.D. 1950820 Type test P Test psi 1500 Casing 1,240 2,010 1,991 1,994 P/F P • Notes: OA 530 605 605 605 Well 2T-28 Type Inj., W TVD 5,706' Tubing 2,660 2,640 2,660, 2,675 Interval V P.T.D. 1950920 Type test P Test psi 3000 Casing 746 3,194 3,113 3,100 P/F P - Notes:AIO2B.66 MITIA to Max anticpated injection Press OA 68 69 69 69 Well 2T-28 Type Inj. W TVD 5,706' Tubing 2,675 2,675 2,680 2,620 Interval 0 P.T.D. 1950920 Type test M Test psi 3,000' Casing 3,100 2,015 2,074 2,079 P/F p Notes: OA 69 69 69 69 AOGCC Inspector requested second test Well 2T-32 ' Type Inj. W " TVD ' 5,731' Tubing 2,900 " 2,900 2,900 2,900 ' Interval 4 P.T.D. 1950490 ' Type test_ P Test psi '1500 Casing, 1,170 '1,950 "1,910 '1,900 P/F P Notes: Non-witnessed test OA 200 ' 200 200 200 ' AOGCC Inspector left location prior to test _ Well 2T-36 Type Inj. W TVD 5,767' Tubing 1,150 1,150 1,150 1,150 Interval 4 P.T.D. 1951020 Type test P _ Test psi 1500 Casing 610 2,000 1,940 1,931 P/F P Notes: OA 410 500 490 490 Well 2T-201 Type Inj. W TVD 2,762' Tubing 900 900 900 900 Interval 4 P.T.D. 1951220 Type test P Test psi_ 1500 Casing 957 3,000 2,986 2,986 P/F P Notes: Non-witnessed test OA 180 180 180 180 AOGCC Inspector left location prior to test Well 2T-217A Type Inj. W TVD 3,006' Tubing 1,170 1,170 1,170 1,170 Interval 4 P.T.D. 2000740 Type test P Test psi 1500 Casing 280 2,000 1,940 1,920 P/F P Notes: Non-witnessed test OA AOGCC Inspector left location prior to test TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test Form 10-426(Revised 11/2012) MIT KRU 2T 4 year 6-01-13Revised.xls Sr *�`. DEB20Z 4 A ve" Conoco Philips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 $c8Afii.) MAR 6 Z012 March 9, 2012 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 I q5- 0 '7 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. Sinceiel , t/rz/r,/,e MJ veland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips 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 2A,M,T,X PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API* PTD 5 cement pumped cement , date inhibitor sealant date ft bbls ft gal 2A-19A 50103201970100 2010830 12" NA 39" NA 153 2/11/2012 2M-02 50103201790000 1920830 10'5" 1.62 19" 11/22/11 5.1 2/11/2012 2M -29 50103201830000 1920970 SF NA 24" NA 3.4 2/11/2012 2T-18 50103202130000 1950170 42" 0.50 9" 11/22/11 2.55 ' 2/12/2012 2T -28 50103202250000 1950920 9" NA 16" NA 2T-207 5010 780000 1982310 223" 3.70 7" 11/21/11 2.98 2/122012 2T-215 50103202800000 1982420 18'6" - 2.40 10" 1122/11 4.25 2/122012 2X-06 50029209880000 1831100 SF NA 21" NA 2.13 2/12/2012 • • • ConocoPhi Ii ps P.O. BOX 100360 Alaska ECEIVED ANCHORAGE, ALASKA 99510 -0360 NOV 0 2 ? Alorbka Oil & Gas Corns. Commission October 27, 2011 Armors o Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 4)� s w 2,Ua Commissioner Seamount: Enclosed please find the 10 -404 Report of Sundry Operations for ConocoPhillips Alaska, Inc., well 2T -18, PTD 195 -017, Sundry 311 -164 surface casing repair. Please call MJ Loveland or Martin Walters at 659 -7043 if you have any questions. Sincerely, Martin Walters ConocoPhillips Well Integrity Projects Supervisor T E OF ALASKA • . ALASKA OIL AND CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r j Repair well ❑ Rug Perforations ❑ Stimulate ❑ Other SC Repair Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development in Exploratory ❑ ' 195 -017 3. Address: 6. API Number: P. 0. Box 100360, Anchorage, Alaska 99510 Stratigraphic ❑ Service (� , 50- 103 - 20213 -00 —00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025568 ' - 2T - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10632 feet Plugs (measured) None true vertical 6134 feet Junk (measured) None Effective Depth measured 10437 feet Packer (measured) 10155 true vertical 5979 feet (true vertucal) 5759 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 0 0 SURFACE (QC) 4252 12 4293 2894 0 0 PRODUCTION 10588 7 10622 6126 0 0 SC sleeve 32" 10 32" 32" 0 0 Perforation depth: Measured depth: 10285 - 10298, 10317 - 10319, 10323 - 10354' 10378 -10388 ECEt\/ Da True Vertical Depth: 5860 -5870, 5882 -5886, 5889 -5914, 5933 -5941 NOV 0 2 2011 & Gas Tubing (size, grade, MD, and TVD) 3.5, L -80, 10180 MD, 5778 TVD Alaska Oil Cans '� Anchor* Packers & SSSV (type, MD, and TVD) PACKER - BAKER 'FHL' RETR. @ 10155 MD and 5759 ND NIPPLE - Type Not Found (Manual Entry Required) @ 0 MD and 0 ND 11. Stimulation or cement squeeze summary: Intervals treated (measured): NA .k Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development ❑ Service g Stratigraphic ❑ x 15. Well Status after work: Oil ❑ Gas ❑ WDSPL Daily Report of Well Operations GSTOR ❑ WINJ C WAG m GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -164 Contact MJ Loveland /Martin Walters Printed Name Martin Walters Title WI Project Supervisor Signature j 7 Phone: 659 -7043 Date 10/27/11 RBDMS NOV 0 2 201 ') Form 10 -404 Revised 10/2010 Submit Original Only ...ode" • 2T -18 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/20/11 Removed 18" of conductor and dust ring for SC inspection. 10/09/11 Cut 3.5' more of conductor piping off wellhead, chip cement and inspect SC for further damage. 10/24/11 Pressure purged OA with 5 psi of nitrogen. Welded 3'2" long sleeve (10 "/ X65/.500) to existing SC to complete repair. 10/25/11 Initial T /I /O= si0/0/0. Post SC repair MITOA. (Passed) Pumped 1.3 bbls into OA to achieve 1800 psi for one hour test. Starting pressure =si0 /0/1800. 15 min= si0/0/1720. 30 min =si0 /0/1720. 45 min =si0 /0/1720. • 1 hr= si0/0/1720. Wellhead pressures bled back to 0 psi and normal up OA jewelry. Final T /I /O= siO /0/0. 10/27/11 Install 4'2" of conductor (16 "/ 62# / .375). 6 ,a Kt 4 . s mil 3 #q ., 44. d 4. ,i \ t ' ,,IA 9 ... •_ ty 4 -,- ._ 54 --ro-,‘`';-4,.. . • • I , , - ifo- , ,-, qye. . ' • +. iii a II I' Ity [ ^k i to 44' °i =u � i t V Yw.. ' 4". ,' .� t §as a fi ta t se-ii--sir*V- -"41 ' '''''- ; ' 1 t A . I ..," I , A .. ; ' ,,,,.....,,,,:,,,,,,,, ., . '64 ' 1 ,' a y r . � k r ri -.. r. -.: c£ s, — ,., "...n`', *a .:+ r ,� •' M � ;�,,: '$ LA, +I ,: ;4., 3 -.d x ' .. y , - IA a a w '�,. ,mix . fie ' � k- - _ . . d r f ._ „,...„,,,...„,,,. ,„...,;,:„t„.,,50,z4colii......,,,,,,,„,,,.., ,,,.,, Y k , r &, { ;x ..•- �fli ?% .. ,, m ? . . , : 4 . .. ' S:' ' . s , •, ' , ;,” -' <.#k.� u f "' r 1 . a �, `" , . �' ,,., , ' . mo .. e a . . E 3,,, . Hr r .. ' . , .` :- z e 4 ': W ,. . 'W '4v �' .x ti . .' '�. • t +,- , .,e"' �,fit O tt e z, r � • "4' y > ^2% -•w , .ate r rlf::.'ff.A#01.44':'ilb'''',,t'efati.!'i.44ig41,:ii.6-.'t",,',',.-0,Att..-;"4. , , ' "' � u�. +7 :4 + b .k - x r . "�....r�e9. . ; > ;; £ ,r' . 'gym • c p 4 5,::::tro.,.A.L.,'4PAP.;':''' :'-''''''''''.'ri.":'' ' ' ' ' . . . ,.., r mA .. 5 �' , ,, .4 y . ;$.. ., • __ „,,,,fi.,,.....:,,,,,,::„....:,..v.;.:,4,:;,74..),,,„4,.„,,,,,.w.:,1/4,4„.,,,,,.+:0.,:_,.. . it z E ?' ® 1 ,( as -`-r t p s v s ,,,„..,,••, ti ,,, S y r � : . A. 3 ' _. a i r .. ,. d • . • R oe � i . • TAII OF ALASLIA • SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. '� P.O. Box 100360 \✓ , Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2T -18 Sundry Number: 311 -164 Dear Ms. Loveland: t ""' Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. / Chair DATED this /P day of May, 2011. Encl. STATE OF ALASKA _ � � ALASK AND GAS CONSERVATION COMMISSI� S� ' L r APPLICATION FOR SUNDRY APPROVALS 5'1 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: SC Repair P 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195 -017 . 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20213 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 2T -18 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0025568 • Kuparuk River Field / Kuparuk River Oil Pool . 1 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10632 ' 6134 • 10437' 5979' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121' 121' SURFACE (QC) 4252 12 4293' 2894' PRODUCTION 10588 7 10622' 6126' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): )285 - 10298, 10317 - 10319, 10323 - 10354' 10378 -103 5860 -5870, 5882 -5886, 5889 -5914, 5933 -5941 3.5 L -80 10180 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'FHL' RETR. MD= 10155 TVD= 5759 NIPPLE - No SSSV MD= TVD= none 12. Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r' 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6 / 4 7// Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG P • Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct the best of my knowledge. Contact: MJ Loveland /Perry Klein Printed Name MJ Loveland Title: WI Project Supervisor signature f Phone: 6 S 9.70 c/ 3 Date S7 E /P Commission Use Only Sundry Number) I -- l (0 q Conditions of approval: Notify Commission so that a representative may witness ���/// Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED Other: 4e- ND . ,r 2::r. See_04>• Y ' d L X0'1• 4$ 4 ro r `i � 1 06 �/ �° mega ail : ���g �a��s. Commission Subsequent Form Required: /o j 6tl a6 APPROVED BY ! / / Approved by: p COMMISSIONER THE COMMISSION Date: 6 ` ( Form 10 -403 Revi a 172 I • I� S / (Sub mit in Dupl cate R I GI 1NAL ,CFAA • . Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 May 8, 2011 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2T-18, PTD 195 -017 surface casing inspection and possible repair. Please call Perry Klein or me at 659 -7043 if you have any questions. Sincerely, M oveland ConocoPhillips P Well Integrity Projects Supervisor Enclosures ♦ • • • ConocoPhillips Alaska, Inc. Kuparuk Well 2T -18 (PTD 195 -017) SUNDRY NOTICE 10 -403 APPROVAL REQUEST May 8, 2011 This application for Sundry approval for Kuparuk well 2T -18 is for the proactive inspection and possible repair of the surface casing near surface. Currently part of the surface casing on this well is exposed to the atmosphere and it appears there is corrosion taking place. 2T -18 has shown no signs or indications of surface casing corrosion issues however, ConocoPhillips requests approval to proactively inspect the surface casing and repair it if damage is present. With approval, inspection and possible repair of the production casing will require the following general steps: 1. Safe -out the well as needed with a tubing tail plug. 2. Remove the floor grate, well house, flow lines, and other equipment from around the wellhead. 3. Remove gravel around well head and build —9' working cellar. 4. Install nitrogen purge equipment for the conductor (and OA if needed) so that hot work may be conducted in a safe manner. 5. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove all of then exposed of conductor if needed. Notify AOGCC Inspector for opportunity to inspect. 6. CPAI Mechanical Engineers will determine if patch or repair is needed to return the casing to operational integrity. 7. If a patch is required, QA/QC will verify the repair for a final integrity check. 8. Install anti- corrosion coating as specified by CPAI Corrosion Engineer. 9. Replace the conductor and fill the void with cement and top off with sealant. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well production. 12. File 10 -404 with the AOGCC post repair. Well Integrity Project Supervisor 5/8/2011 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 2T-18 Run Date: 8/6/2010 • August 24, 2010 `lC1i -a _ The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2T-18 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20213-00 Injection Profile Log 1 Color Log 50-103-20213-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 l~~'=UO~ 0?~~6~- klinton.w .' ,~~ -a _~ ~ _ ~/ Date: ~' '' Signed: ~~,i~?C'a ,Y~~ s MEMORANDUM To: Jim Regg P.I. Supervisor ~~~ ~~14'~~~ FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA 1NC 2T-I 8 KUPARtJK RIV iJNIT 2T-18 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~i2 Comm Well Name: KUPARUK RIV UNIT 2T-18 API Well Number: 50-103-20213-00-00 Inspector Name: Jeff Jones Insp Num: mitJ7090608124737 Permit Number: 195-017-0 Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-18 Type Inj. w TVD szs9 ~ IA laoo zo2o - P.T.D 1950U0 TypeTest sPT Test psi i lsoo pA I, Ins zao ~ L-- zooo 2000 zooo zso zso i zso - Interval axxTST p~ P ' Tubing zsso I _ zsso zsso zsso zsso _` NOteS: 1.2 BBLS diesel pumped, I well inspected; no exceptions noted. a. Y-. ~. . . .i Fr ~ ~ ~; Wednesday, June 10, 2009 Page 1 of 1 i7~r~~~~~i~1~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # /.\ ~ ~// ;i i Y / , ._ A 1~ ~s / Y NO. 5005 Company: Alaska Oil & Gas Cons Comm ;~ ~ ~ j~~, ,1,;~_~. Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Log Description Date BL Color CD 12/17/08 2X-10 11978476 PRODUCTION PROFILE / - f 08/17/08 1 1 2V-09 12100460 PRODUCTION PROFILE (p 11/16/08 1 1 1Y-06A 12100461 PRODUCTION PROFILE 11/17/08 1 1 2X-12A 12100464 PRODUCTION PROFILE (9 '^- 11/21/08 1 1 2U-OS 12096574 PRODUCTION PROFILE ~ 11/28/08 1 1 3K-108 12100466 USIT 11/23/08 1 1 3K-30 12097433 LDL / 11/28/08 1 1 30-01 12097434 LDL -Q 11/29/08 1 1 1 E-04 12097436 LDL 11/30/08 1 1 3A-04 12097432 INJECTION PROFILE L - 11/27/08 1 1 1H-16 12096581 PRODUCTION PROFILE ~ 12/05/08 1 1 3A-06 12114994 BAKER LOWER STRADDLE PACKER 11/26/08 1 1 2U-14 12096578 INJECTION PROFILE L - 12/02/08 1 1 1G-06 12096580 INJECTION PROFILE 12/04/08 1 1 2V-10 12096582 PRODUCTION PROFILE 12/06/08 1 1 3F-01 12086694 PRODUCTION PROFILE ~- "` 12/07/08 1 1 2W-14 12086695 INJECTION PROFILE ~-+ 12/08/08 1 1 1J-102 12086701 INJECTION PROFILE - 12/14/08 1 1 i D-07 12114999 USIT _ ~ 12/15/08 1 1 3C-02 12114997 INJECTION PROFILE _ ~ 3 12/13/08 1 1 2T-18 12086703 INJECTION PROFILE (~ 12/17/08 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. MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Refr ,¡ 7 ([) 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILUPS ALASKA fNC 2T-]8 KUPARUK RIV UN]T 2T-]8 ü\1 Š/ \0\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. supr~/2- Comm Well Name: KUPARUK RIV UNIT 2T-18 API Well Number: 50-103-20213-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603144535 Permit Number: 195-017-0 Inspection Date: 6/2/2007 /' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T·]8 Type Inj. w TVD 5760 IA ]]25 2580 2550 2550 I P.T.D ]950170 TypeTest SPT Test psi 1500 OA 560 780 780 780 I Interval 4YRTST P/F P ./ Tubing 2350 2350 2350 2350 I I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. ,/ NON-CONFIDENTIAL sCAl'lNEC JUN 2 1 Z007 Wednesday, June 06, 2007 Page 1 of 1 SCb'UDlberger 12/06106 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4061 '~'<~ b, IJ!.~~J"~~ '"' ')Vj"t, ¡Ì; \:t:~ .J l, , \.' 0 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job# Urc- ~ L~ 0- oil- Field: Kuparuk 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1R-20 11486085 LDL 11/28/06 1 10-05 11486086 INJECTION PROFILE 11/29/06 1 10-03 N/A SBHP 11/25/06 1 10-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1E-04 11477639 INJECTION PROFILE 12/04/06 1 . log Description Date Bl Color . CD . Please sign and return one COpy of this lransmittal to Beth at the above address or fax to (907) 561-8317. Thank you. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 06/14/03 Sauvageau/Brake - APC John Crisp Well 12T-10 P.T.D. I1860960 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. ITypo'nj I i I I Tu ing I ss°l 2ss°l 2s °l 25s°1 Interval Type Test Test psiI 1500 I Casing I 11501 30801 30501 30401 P/F Well 12T-18 P.T.D: I1950170 Notes: Type Test Test psil 1500 I Casing I 18001 29701 29501 29401 P/F ' Well 12%26 P.T.D.11950820 Notes: Type Test Test psil 1500 I Casing I 10201 30101 30001 30001 P/F Well 12T-28 P.T.D.11950920 Notes: Type Test Test psiI 1500 I Casing I 13401 30501 30001 29801 P/F P.T.D. I1950750 TypeTest Test psiI 1500 I Casing I 2401 29501 29251 29101 P/F Notes: P.T:D. I1951020 Type Test Test psiI 1500 I Casingl 13001 30501 30OOI 30001 P/F _ Notes: P.T.D, I1951220 TypeTest Test psiI 1500 I Casing I 13501 29501 29201 28751 P/F . Notes: Carried MIT out for one hour Pressure at 45 min 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0614_M IT_K RU_2T-10_-18_-26_-28_-29_-36_-201 .xls 8/25/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23-0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein@admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617@conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) ~MIT KRU 2T 06-14-03.xls MIT KRU 2T 06-14-03.xls '1~ Name:Type: EXCEL File (application/msexcel) 11' Encoding: base64 [~ MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel) I 1 of I 6/25/2003 1:45 PM MEMORANDUM TO: Randy Ruedrich Commissioner THRU- Jim Regg P.I. Supervisor FROM- State of Alaska Alaska Oil and Gas Conservation Commission /~ DATE: June 14, 2003 ~1'~o~, , ~ ~;, ~o ~ SUBJECT: Mechanical Integrity Tests ~L,~/~;.( Conoco/Phillips Kuparuk River Field 2T Pad John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. I w~,,I2T-lO IType,nj.I S I~.v.D. I~ I Tubingl 2550 I~o I~o I~o I,ntervall 4I P.T.D.I 1860960IType testI P I Testpsil 3000 I Casingl 1150 I 3O8O I 3O5O I 3O4O I P/F I ~ I Notes: OA 160 psi. pretest & 170 psi. during test. 3.5 BBL. Pumped. I vve,I ~.,~ IT~,e,.i.I s I T.v.~. i~o i Tu~,n~l ~4oo I~oo I ~°° I~°° I'n'e~'l 4 P.T.D.I 1950170ITypetestl P ITestpsiI 3000 I Casingl 1800 I 2970 I 2950 I 294O I P/F I _P Notes: OA 760 psi. pretest & 900 psi. during test. 2 BBL. Pumped. We,,I ~-~ IT~,~,ni.I ~ I T.V.~. I~ I T.~,,,I ~30 12330 12330 12330 I,,~e,v~,l 4 P.T.D.I 1950820ITypetestl P ITestpsil 3000 I Casingl 1020 I 3010 I 3OOO I 3000 I P/F I E Notes: OA 0 psi. during test. 2 BBL. Pumped. We,,I2T-28IT~,e,ni.I s I ~.v.~. I~o I T,~,,~I ~o I~o I~o I~0 I,.~e~,l 4 P.T.D.I 1950920ITypetestl P ITestpsiI 3OOO I Casingl 1340 I 3050 I 3O0O I 2980 I P/F I P Notes: OA 0 psi. during test. 3 BBL. Pumped. We,,I ~-~, IT~,e,,i.I ~ I T.,,.~. I~ I Tu~,n,I ~0 I~0 I~0 I~0 I,n,e~a,I 4 P.T.D.I 1950750ITypetestl P ITestpsil 3000 I Casingl 240 I 29501 29251 29101 P/F I g Notes: OA 0 psi. during test. 5.4 BBL. Pumped. , Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. 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 Test's Details I traveled to C/P's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: _5 Number of Failures: O Attachments: Total Time during tests: 4 hrs. CC: MIT report form 5/12/00 L.G. 2003-0614_M IT_KR U_2T-29_jc.xls 6/24/2003 ¡;HI~LlPS\ - J..(t ¡:~4 PH\....LIPS Alaska, Inc. .. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 October 1,2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 2T-18 (195-017) Dear Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the perforations on the KRU we1l2T-18. If there are any questions, please contact me at 263-4574 or 659-7348. Sincerely, 4~ M.Mooney Wells Team Leader Phillips Drilling MM/skad RECEIVED OCT 0 2 2001 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ( (- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown- Pull tubing - Stimulate - Alter casing - 5. Type of Well: Development - Exploratory - Stratigraphic - 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 9951 0-0360 4. Location of well at surface Service_X 36' FNL, 4724' FEL, Sec. 12, T11 N, R8E , UM At top of productive interval 1591' FNL, 2517' FEL, Sec. 10, T11N, R8E, UM At effective depth (asp's 498945, 5969943) At total depth 1630' FNL, 2124' FEL, Sec. 10, T11 N, R8E , UM 12. Present well condition summary Total depth: measured true vertical (asp's 490986, 5968353) 1 0632 feet 6134 feet Plugs (measured) Plugging - Perforate _X Repair well - Other - 6. Datum elevation (DF or KB feet) RKB 123 feet 7. Unit or Property name. Kuparuk Unit 8. Well number 2T -1 8 9. Permit number 1 approval number 1 95-01 7 / 10. API number 50-1 03-20213 11. Field 1 Pool Kuparuk Oil Pool Effective depth: measured 1 0437 feet Junk (measured) true vertical 5979 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 315 sxASI 121' 121' SUR. CASING 4170' 9-5/811 930 sx AS III, 610 sx Class G 4293' 2894' PROD. CASING 1 0499' 7" 250 sx Class G 1 0622' 6126' Perforation depth: measured 10285'-10298',10314'-10319', 10323'-10354',10378'-10388' Packers & SSSV (type & measured depth) BAKER 'FHL' RETR. @ 10155' MD. CAMCO 'OS' NIPPLE NO GO @ 515' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl NIA true vertical 5860'-5870', 5882'-5886', 5889'-5914', 5933'-5941' Tubing (size, grade, and measured depth) 3-1/2",9.3#, L-80 Tbg @ 10180' MD. N/A Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations _X Oil - Gas - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed j I hi M,,"~ Mooney 1~ P{ ~ Title Staff Engineer Form 10-404 Rev 06/15/88 . ORIG\NAL RECEIVED OCT 0 2 2001 Alaska Oit & Gas Cons. commissiOn . Anchorage Casing Pressure Tubing Pressure Suspended - Service _Water Injector_X Questions? Call Mike Mooney 263-4574 Date /rZßI Prepared by Sharon Allsup-Drake 263-46 t 2 ~ SUBMIT IN DUPLICATE Date 08/15/01 08/27/01 ( 2T -18 Event H ¡story Comment TAGGED FILL @ 10437' RKB, EST. 45' RATHOLE. DRIFT TBG W/ 15' X 2.63" HCDG TO 10333' RKB. [TAG] PERFORATED 10285'-10298', 2-1/2" HSD, PJ, 4 SPF, 180 PHASING. LOGGED JEWELRY FROM 10390'- 10000', POOH, LEFT WELL SI DUE TO DIFFICULTY OPERATING TREE VALVES. 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A kL Ir Date: June 26, 1995 Transmittal #: 9264 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert , / Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-18 CNT-G Depth Corrected 6/21/95 API #50-103-20213-00 /6 .,....,--- Acknowledged ,, _i -- Date: _ DISTRIBUTION: Mr. Vernon E Pringle, Jr. Sharon Allsup-Drake Clifton Posey (Geology) DS Development Geology e Cr�t ,ED DeGloyer and MacNaughton ATO-1205 ATO 1251 [ �/ One Energy Square J Dallas, TX 75206 was UN 2 6 1995 Erickson/Zuspan Larry Grant (+Sepia) ka til&Gas NSK Central Files AOGCC Anchor •g� C0mmission NSK 69 3001 Porcupine Drive Anchorage, AK 99501 /Lc) Ilk . / 4. = E $ \ _ = E 1- 2 / a C $ § �r. % I W � � 13 CI) >7 _ o ■ us 0 c. %2 3 O - « O K c m 7 ® = k a 5 _J o @ §5. o .x " \ c $ - 2 • c o cn J < COk J CC Lr) / « a ffJ _o Tu \ • E z v U 2 $ e as 0 2§ 0 2 -o -o C) .0 § us W $ ƒ > c...) 7•••715 W k CII o k _ VIli W o u Cl) oe -D G .2 co J ƒ n 2 o / Q % 7 ® 3 / $ I C § j . c 7, g 0 i 2 R 7 $ f = ■ - a cu % = cn — c = k ■ £ as co c % J ■ k z CO Z 0 2 q 0 I- o § O « « Cl)1 q E — \w S ARCO Alaska, Inc. k&, Date: June 12, 1995 Transmittal #: 9254 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge / receipt and return one signed copy of this transmittal. Z5( -18 CDR Depth Shifted 3/3/95 Ref#20-103-20213-00 2T-18 TDT Therm. Decay Time Log 5/8/95 9800-10521 Acknowledged: Date: RECEIVED DISTRIBUTION: JUN 16 1995 Gas Cans.Commission Mr. Vernon E Pringle, Jr. Sharon Allsup-Drake Cliff �� `Anchorage (Geology) DS Development Geology DeGloyer and MacNaughton ATO-1205 ATO 1251 One Energy Square Dallas, TX 75206 Erickson/Zuspan Larry Grant(+Sepia) Sandy Lemke NSK Central Files AOGCC ATO 1336 NSK 69 3001 Porcupine Drive Anchorage, AK 99501 • S ARCO Alaska, Inc. JAL Date: June 5, 1995 Transmittal #: 9246 RETURN TO: ARCO Alaska, Inc. ATTN: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. ' Please acknowledge receipt and return one signed copy of this transmittal. 751- l 2T-18 USIT-GR log 5/9/95 8175-10505 2T-18 Cement Bond Log CBT-GR 5/9/95 8175-10475 Receipt Acknowledge: , Date: RECEIVED JUN 1 6 1995 DISTRIBUTION: Alaska Oil&Gas Cons.Commission Sharon Allsup-Drake Larry Grant(+sepia) Ericks8fi4$@19pe�n DS Development AOGCC NSK Central Files ATO-1205 3001 Porcupine Drive NSK-box 69 Anchorage, AK 99501 O. 4111 to rn co co m E U) a J T r E E- 0 V7=-, O) c > rn= p C IA a) Y a cc 007 cQ O aS i c ai II,.. U C) O Jo m - co H cc a O i a co C r v r- r 0 (13 aaMa Y c 0 >` LID C O a r r 0 0 • E :) Z 0 U c as UC) LC) 2 m a) a) i- •.••• co c.) O O N C tC) M N o -- O O d as Lc) j..j..1C.o7 j I ro m N U) Q a) o a o O p 70 CC c m N a 4h, D Z O a 0 COpo z �\ coy cc .Q r r (/) d a1 c T rn CI) I— c Lco W I a T CI ,6 , in L. C rn Z :) OL Ya) cO < d _ i G1 s 8 Q C 7 t�A C p) L Z - O) m U) W C Cl) OD CO Cn• QO 3 U Z COw d0 1 0 r r Z O7 e a ix) Q Q N N a. U) -61.- 1'N .1 \ 1 t� • lb AOGCC Indi v i dua l Well P a ge = 1 .7-0 16 632Geologica1 Materials Inventory Date : 06/02/97 PERMIT DATA T DATA_PLUU`w. RUN DATE ,RECVD 95-017 6705 ...=f-v9787 - 10521 CNTG o14. 1 06/23/95 (. 4, -27 ,,,r ieo, -- I05Ai C. 1-1, 6//6/4i 95-017 C6T/GR -t8175" 10505 1 06/ 16/95 G (, 7S7 T J�rWA ' I440 - )0 631 GOA. 0 (4 . U/!G/9l� -9-5---0-1• u1 .., vk.. '4300- 10600 // u / yam_.... 1 ( } �NY 114;IC t✓,ii Y�... 1 ..: ..06/. . ..I.tJ/�J.r'1 95- 017 CDR/DS r,L-4300-.. 10600 1 06/ 16/95 95--017 CNT- i:; 9790•- 10505 1 06/23/95 •(", �94 - _...r I@ 1 '3 ..._.._.............. _ 12.,.._'9 7_8 f I0"5-2- _. .._.._.L\.-It LlL TiLY17-� ..__.._..,.,. ...� _..... .._...0-61-2-6;/-9-5-- 95-0 1 7 TCT L L 9800- 10521 (f 1 06/ 16/95 95.- 017 TDT--P/CIE, " 98,00- 10521 1 06/ 16/95 95-017 Ut I.T/GR c "8175~- 10475 1 06/ 16/95 10 - 407 R COMPLETION DATE g/A6 /'%/'/ /0/30/qr/ DAILY WELL OPS R' 02/At//'91"1' TO of/A6 /yr / / / / i3;, svVJL 'R R.Av,t1 Id.i - )0(,), 10 A d I9'ir Are dry ditch samples required? yes ® And received? e, Was the well cored? yes Analysis & description received? y +----trcr Are well tests required.` WO_ r"& Received? y...._ Wel 1 is in comp ] :i a n c e ., ", In"rti,a1 COMMENTS if-\\\ 8\ ‘\„\- 1 ,( //\\ ry� 1 . (( I# �i ?,)) ,1 TONY KNOWLES, GOVERNOR ALASKA OIL AND GAS 3001 PORCUPINE DRIVE CONSERVATION COMMISSIOAT ANCHORAGE,ALASKA 99501-3192 PHONE: (907)279-1433 FAX: (907)276-7542 February 22, 1995 Mike Zanghi, Drill Site Dev Supv ARCO Alaska Inc P O Box 100350 Anchorage, AK 99510-0360 Re: Well # Kuparuk River Unit 2T-18 Company ARCO Alaska Inc Permit# 95-17 Surf Loc 38'FNL, 556'FWL, Sec 12, T11N, R8E, UM Btmhole Loc 1630'FNL, 3073'FWL, Sec 10, T11N, 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. .urs.very truly, 4111 David W nston Chairman BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section -w/o enol Dept of Environmental Conservation -w/o enol iii 111. STATE OF ALASKAfli ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill 0 1 b Type of Well Exploratory 0 Stratigraphic Test 0 Development Oil x Re-Entry 0 Deepen ❑ Service ❑ Development Gas 0 Single Zone X Multiple Zone 0 2.. Name of Operator 5. Datum Elevation(DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 82' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25568, ALK 2666 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond(see 20 AAC 25.025) 38' FNL, 556' FWL, Sec. 12, T11N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 1582' FNL, 3318' FWL, Sec. 10, T11N, R8E, UM 2T-18 #U-630610 At total depth 9. Approximate spud date Amount 1630' FNL, 3073' FWL, Sec. 10, T11N, R8E, UM 2/21 /95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and ND) property line 2T-1 7 10735' MD 1630' @ TD feet 15' @ 280' MD feet 2560 6180' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 62.2° Maximum surface 1 704 prig At total depth (TVD) 3100 pslg 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 80' 41 ' 41 ' 121' 121' ±200 CF 12.25" 9.625" 36.0# J-55 BTC 4240' 41 ' 41 ' 4281' 2879' 840 Sx Arcticset III & HF-ERW 610 Sx Class G 8.5" 7" 26.0# L-80 BTCMOD 10694 41 ' 41 ' 10735' 6180' 250 Sx Class G HF-ERW Top 500' above Kuparuk 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 R E C E I V ED Conductor Surface Intermediate Production FEB 13 1995 Liner Alaska Oil&Gas C Perforation depth: measured ons.Commission true vertical Anchom •, 20. Attachments Filing fee X Property plat 0 BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements X 21. I hereby certify that t e foregoing i true and correct to the best of my knowledge //'-- Signed .. Signed - Title Drill Site Dev. Supervisor Date Z' I [, Commission Use Only Permit Number API ber Approval date �}:: 9 See cover letter for cam-/7 50-/03 - .2. O.Z/3 (�(o//7S other requirements Conditions of approval Samples required 0 Yes a No Mud log required 0 Yes 131 No Hydrogen sulfide measures 0 Yes JEINo Directional survey required 131 Yes 0 No Required working pressure for ROPE 0 2M M. 3M 0 5M 0 10M 0 1 5M Other: Original Signed By by order of /���� Approved by David W. Johnston Commissioner the commission Date �,/ Form 10-401 Rev. 7-24-89 Submit in triplicate a.mow UOISSIWWOO 1UO3 09 V110 oIse1l 5661 2 I 83i a3A13D3I •O!i asealaa pue uo!leool ue810 '8 'Mann anion pue u! 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GJOy3UV °OS m - r UO%SS!WWOO'suo3 no'8110 sgmvalv 000, 0% 0041- e �r 5661 2 OBJ 0,‘„ £t ao 0 OOZ G3AI3)3 DOss t oox 6l onS O0 00 - DOJ 2S °Os, °%000 L- oO`s �' °O�. o D O oo oon �d Q3�Od0an oos 006 r 009- Dor oos =!�agSOdOfld OOL rr 0 61. 1 r 009 0% e1, r 000- 000- 00£- 000- 001- 0 - 0 0 p 001- u-) 00Z 0 U 00£ 1111 II I I I I I I II II I I I I I I 1111 III fill I I II I I I I II I I I I I I 0060 0000 00L£ 00Z£ 0000 0040 0000 0090 OOL£ 0080 0060 0004 00 Lb 0009 0004 0077 0007 0097 00L4 0084 0064 0005 00 LS 0005 000S 00'0S L alooS .�S e M — — > Dmsow 'edoiS : uol}000i pun aenia lnaodnN Ple!J 6 / 8l :II8M iz Pod : aJn}onJ}S • 311I V}ISVnI� y • • • • Casing Design / Cement Calculations 11-Feb-95 UT WELL iINFORMTICN<. Well Number: Surface Csg MD: 4,281 ft Surface Csg TVD: 2,879 ft Production Csg MD: 10,735 ft Production Csg TVD: 6,180 ft Top of West Sak,TMD: 2,956 ft Top of Kuparuk,TMD: 10,347 ft Top of Target, C Sands, TVD: 5,883 ft Estimated Pressure: 3100 psi ............................................................ Surface CasingChoice : ** See Page 4 Production CsgChoice : 'E '< > `:> >;; > > > >..... For CasingChoices Production Casing Frac. Pressure 3,500 psi Maximum anticipated surface pressure TVD surface shoe = 2,879 ft {(13.5*0.052)-0.11}*TVDshoe = 1,704 psi Estimated BH pressure at top of target zone Estimated Pressure= 3,100.0 ppg Top of Target, TVD = 5,883 ft Overbalance, psi= 150 psi Anticipated Mud Weight = 10.6 ppg L ; LATI N Surface lead: Tap West Sak, tivlb 2,956 It Design lead bottom 500 ft above the Top of West Sak= 2,456 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 819 cf Excess factor = 100% Cement volume required = 1,638 cf Yield for Permafrost Cmt = 1.94 Cement volume required = 840 sx Surface tail: TMD shoe = 4,281 ft (surface TD - 500' above West Sak) * (Annulus area) = 572 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 606 cf Excess factor = 15% Cement volume required = 696 cf Yield for Class G cmt = 1.15 Cement volume required = 610 sx RECEIVED FEB 1 3 1995 Alaska Oil&Gas Cons.Commission Anchora ! • Casing Design / Cement Calculations 11-Feb-95 Production tail: TMD = 10,735 ft Top of Target, TMD = 10,347 ft Want TOC 500' above top of target= 9,847 ft 5"casing tail top (100' above C sand) = 10,735 ft 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 = 155 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.2148 Cmt required in casing = 17 cf Total cmt= 172 cf Excess factor= 75% Cement volume required = 301 cf Yield for Class G cmt= 1.19 Cement volume required = 250 sx TENSION - Minimum Design Factors are:T(pb)=1.5 and T(js)=1.8 Surface (Pipe Body): Casing Rated For: 916000 lb Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = 4,281 ft Dead Wt in Air= Length * (Wt/ft) Casing Wt (Ib/ft) = 40.00 lb/ft Buoyancy = Weight of displaced mud Dead Wt in Air = 171240.0 lb Buoyancy = 27059.2 lb Tension (Pipe Body) = 144180.8 lb Design Factor = 6.4 Surface (Joint Strength): Casing Rated For: 979000 lb Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = 4,281 ft Dead Wt in Air= Length * (Wt/ft) Casing Wt (lb/ft) = 40.00 lb/ft Buoyancy = Weight of displaced mud Dead Wt in Air = 171240.0 lb Buoyancy = 27059.2 lb Tension (Joint Strength) = 144180.8 lb Design Factor = 6.8 Production (Pipe Body): Casing Rated For: 604000 lb Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = 10,735 ft Dead Wt in Air= Length * (Wt/ft) Casing Wt (Ib/ft) = 26.00 lb/ft Buoyancy =Weight of displaced mud Dead Wt in Air = 279110.0 lb Buoyancy = 44721.7 lb Tension (Pipe Body) = 234388.3 lb Design Factor = 2.6 Production (Joint Strength): Casing Rated For: 667000 lb Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Length = 10,735 ft Dead Wt in Air= Length * (Wt/ft) Casing Wt (Ib/ft) = 26.00 lb/ft Buoyancy = Weight of displaced mud Dead Wt in Air = 279110.0 lb Buoyancy = 44721.7 lb RECEIVED Tension (Joint Strength) = 234388.3 lb Design Factor = 2.8 FEB 1 3 1995 Alaska Oil&Gas Cons.Commission Anchora • • Casing Design / Cement Calculations 11-Feb-95 BURST- Minimum Design Factor = 1.1 Surface Casing: Casing Rated For: 5750 psi Burst = Maximum surface pressure Max Shut-in Pres = 1704.4 psi Design Factor = 3.4 Production Csg: Casing Rated For: 7240 psi 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Inside pressure = 6914 psi Outside Pres=Backup Gradient (8.9ppg *0.052`TVD) Outside Pressure = 2860 psi Net Pressure = Pressure inside-Pressure outside Net Pressure = 4054 psi Design Factor = Rating / Net Pressure Design Factor = 1.8 COLLAPSE - Minimum Design Factor = 1.0 Surface Casing Casing Rated For: 3090 psi 1. Design Case - Lost circulation and Fluid level drops Mud Gradient = 0.552 lb/ft to 2000' TVD with 9.0 # Mud Ext. Pres. @ Bottom = 654 psi 2. Ext. Pres=Mud Wt*0.052`TVD-(2000'TVD of 9# Mud) Design Factor = 4.7 Production Csg Casing Rated For: 5410 psi 1. Worst Case - Full evacuation of casing Mud Gradient= 0.552 lb/ft 2. Mud weight on outside = Mud Wt * 0.052 * TVD Ext. Pres. @ Bottom = 3414 psi Design Factor = 1.6 RECEIVED FEB 13 1995 kkaska Oil&Gas Cons.Commission Anchora S Casing Design / Cement Calculations 11-Feb-95 Surface Casing Choices OD ID lb/ft Grade Metal X-Section Jt Strength Body Strength Collapse Burst 1 9.625 8.681 47 L-80 13.5724 sq. in. 1161000 lb 1086000 lb 4750 psi 6870 psi 2 9.625 8.835 40 L-80 11.4538 sq. in. 979000 lb 916000 lb 3090 psi 5750 psi 3 9.625 8.921 36 J-55 10.2545 sq. in. 639000 lb 564000 lb 2020 psi 3520 psi 4 10.750 9.950 45.5 J-55 13.0062 sq. in. 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID I b/f t Grade Metal X-Section Jt Strength Body Strength Collapse Burst 1 7.000 6.276 26 L-80 7.5491 sq. in. 667000 lb 604000 lb 5410 psi 7240 psi 1 5.000 4.276 18 L-80 5.2746 sq. in. 376000 lb 422000 lb 10490 psi 10140 psi 2 7.000 6.276 26 J-55 7.5491 sq. in. 490000 lb 415000 lb 4320 psi 4980 psi RECEIVED FEB 13 1995 Alaska 011&Gas Cons.Commission Anchora KOPARUK RIVER UNIT 20" DIVERTER SCHEMATIC L 6 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 5 4 HCR MAINTENANCE &OPERATION 1. UPON INITIAL INSTALLATION: • CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. • CLOSE PREVENTER TO VERIFY OPERATION AND 3 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. 2 ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1 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 DKP11/9/94 FEB 1 3 1995 Alaska Oil&Gas Cons.Commission Anchor 1 I 13 5/8" 5000 PSI libP STACK 7 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 j I C ARE CLOSED WITH CHARGING PUMP OFF. V L 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I5 BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. 4 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. 3 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 BOTTOM PIPE RAMS. TEST BOTTOM 2 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 1 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 BODE 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 FEB 1 3 1995 Alaska OU&Gas Cons.Commission Anchora V , di 4 1 D 0 N 0 T WRITE I N T H I S SPACE D N a) al H H N O a) a) ma N n W W 0 N O V a x a U °a a z H • I N as 0 O •.) 0 0 H z t ) a a a' 0) • w . A. o U `/z z z z z z z z z z z z z z z z e. z z z z t/zz zz�'a/y z�'�(/zy�'\ z O z z z z \; '» N >., >, » >1 >. >4 >4 >. >4 >. 4 442 >, 4 4 •ON v v �>. >4 >4 >. N • • • • • • � a • • • • a) N ro • • . ro. . . > u o,o 0` • N . . . • •b • • 0 • • w a) • a • al a) • • • C N • N 0 1 • 0 . • •bN . •• • • o • . a) a • m w • O • ro • • •ro N 0 • . N • A a! +4 • • 'b ro . • N . 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Noao 0 4 u ._,, 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. 1 • • CJ z c fit- * * ***d!-** 0 * * 1 * * * * * a r, 41 * * :c n. N C* i- * * LI) C C * z. * * +1 .-3 * Lit * * ..'t :L C!] 1 * U * * 2 a"tn * * C.. * [�OCCGMSGCi* * :i * ts3 * 0.-F+cZ G.r F/). OD * * U * 0 1 CG CC 4 1 •-+ • t-, * C.0 * XE-t.. 0.-10-i.0 * E+ * (a3 * +C ?< ()Cn * .D * 4t * * a_ * ,c.L * •s••..•••••••• * * 1 * * C * .-- * * J * I * :sa 0 * * GJ * x- ic. * . * 'I) * < X * S< * * c 41.3 is3 ix? * ✓J * * :z.t a)V * 4 * * - x zz * * * Z Z S3 =al * .1 * * .G. 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ZZ EE-0 •• 2 UC- X UUU a ^ ,.-4.-4 .-CW 27W WW. <a ta'-3 MO F4E-4 <0•0. C>4Z Z C W'1 CtF s2 ?: '. 04 M› •• ,ra-4••C91-1 U'Zhi 4-4a_aan C: 4-4$-$1-1-4 E* •r W4 r-+CY. C< F-!E- WHti' ••Cr CE-a .=? CCX•• E-^.=`aO Z. MMME. ts. -2S-1 ?s_. 1A-s E-+?_' WE- CX.-1 W Fa3••U,Q W tst .. .F-t U)i': r W W a '-! E-c E.£-i U i-4 WW Z<L0 W_dLO. G C 2Q: ta`M a E-'Z1-. **”...•.>!CCU W a WW= 7 > U, i. <=.'.i e-, W <7.7,7-7H 'z?' T._ <a O ?X s C?'? W'.17rtom' 4 0 U) L4 *'C..? .c'.?.e:.0 *U 2':? C X Z' E-•ZUi1+e-' UtiC4:ZU) . .- U HC.CC. W W *4-i 1.4 )-4.!-41 ; *1-4 !-I ).-U,-4W1 a? ) Z<.0-4 u?'H 4 ,S U 3,,Y,is W ti:ts.:zd VSs a'cr z CLC * W..i..`.'►.-E->r *>WUL•'E-> W4W •.t aLC7tx ea is •.:' .-•NMa- > ME *X a--1 H ts1.c_'i , * t-+N aL, :tai a a.cq .:r-4 tai:9'-1,`Si ?W X a E- tx:.aaWCarG W<ar<OaC, <=< wO aCaCCa:. 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