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Home My WebLink About198-121MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, August 18, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-132 KUPARUK RIV U WSAK 1D-132 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/18/2022 1D-132 50-029-22895-00-00 198-121-0 W SPT 3490 1981210 1500 910 910 910 910 4YRTST P Austin McLeod 7/13/2022 Monobore. MITIA 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 U WSAK 1D-132 Inspection Date: Tubing OA Packer Depth 250 1800 1690 1685IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220714084150 BBL Pumped:0.6 BBL Returned:0.5 Thursday, August 18, 2022 Page 1 of 1 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date: 2022.08.18 15:15:37 -08'00' cad- k-24 2._cpc,„‘ WELL LOG TRANSMITTAL#902926373 To: Alaska Oil and Gas Conservation Comm. December 30, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED JAN 0 5 2016 RE: Multi Finger Caliper: 1D-132 AOGCC Run Date: 11/23/2015 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 1D-132 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22895-00 SCANNED , n 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 Si ned:(1 12) 6 Date: g "eA"-"'-C • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 To: Jim Regg P.I. Supervisor i~~ ? ~~~ o SUBJECT: Mechanical Integrity Tests 1. ~ CONOCOPHILLIPS ALASKA INC ID-132 FROM: Bob Noble KUPARUK RIV U WSAK 1D-132 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ' ' _ Comm Well Name: KUPARUK RIV U WSAK 1D-132 Insp Num: mitRCN100718144004 Rel Insp Num: API Well Number: 50-029-22895-00-0o permit Number: 198-121-0 Inspector Name: Bob Noble Inspection Date: 7/16/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ID-I3z ~ Type Inj. N- TVD 3490 IA 20 1740 1600 1s80 P.T.D I9sI2IO TypeTest SPT Test psi vao OA Interval aYRTST p/p' P /rubing 67s 675 67s 67s Notes: (JUI~. !~q~r~-~S~- 1, Thursday, July 22, 2010 Page 1 of 1 ~ ~~~ _,.%!~ ~~-? ~~ MAR 1 ~ 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alss~ O~ ~ Gad ~AIi~, CAfrtrnii REPORT OF SUNDRY WELL OPERATIONS Anc~rarr 1. Operations Performed: Abandon ^ Repair Well Q Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ~ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-121 ! ~ 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22895 00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' ~ 1 D-132 " 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 5802' ` feet true vertical 4203' - feet Plugs (measured) 5646' Effective Depth measured 5086' feet Junk (measured) true vertical 3528' feet , Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' PRODUCTION 5015' 5-1/2" 5056' 3500' PRODUCTION 734' 3-1/2" 5790' 4191' Perforation depth: Measured depth: 5122'-5154', 5188'-5224', 5238'-5244', 5284'-5290', 5300'-5320', 5326'-5332', 5352'-5364', 5378'-5396' true vertical depth: 3562'-3591', 3623'-3657', 3670'-3676', 3714'-3719', 3729'-3748', 3753'-3759', 3778'-3789', 3802'-3819' Tubing (size, grade, and measured depth) 2-7/8", L-80, 5056' MD . p,~~ff~~`{ ~*~ pppp /~ ~y ~ ~ 2od~ :~~~B~6E~l~L.l tVtftll Packers & SSSV (type & measured depth) sealbore at 5oaa' MD Camco nipple @ 490' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation - - 505 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NlA if C.O. Exempt: 307-375 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Group Engineer Signature Phone 4 ^7 a~ Date ~ / I1 lr~ Z~3-" ~ ~''v v Pr red SharonAllsu -Or k 263-4612 Form 10-404 Revised 04/2006 ~~ ~r r~ 3~~~ Submit ng Only ~~~ I ~ • • ~_ ~- -~ ~' KRU 1 D-132 ( ~ +~c ~n~cc~Phi(li~s ~tl~~k~~ ~~~~, .. . , 1 D-132 _ _~ -_ AF'I: 500292289500 WeIIT e: INJ An le TS: de a7 TusING SSSV Type: NONE Orig 7/30/1998 Angle Qa TD: 18 deg @ 5802 (0-5056, OD:2.875, _ Com letion: ID:2.441) Annular Fluid: 8.7 brine - Last W/O: 12/29/2007 Rev Reason: WORKOVER Reference L Ref L Date: Last U date: 1 /4/2008 'RODUCTION Last Ta : 5086 TD: 5802 ftK6 (o-5o5s, Last Taq Date: 12/15/2007 HIP Angle: Max 59 deb n 1 Q'~7 oD:5.5o0, _ _ _ _ _ _ Casin Strin ALL NIP (490.491, - Descri Ion Slze To Bottom TVD Wt Grade Thread oD:3.7o3) µ CONDUCTOR 16.000 0 121 121 62.58 H-40 WELDED ----- PRODUCTION 5.500 0 5056 3500 15.00 L-80 BTCM PRODUCTION 3.500 5056 5790 4191 9.30 L-80 EUE Tubin Strin ' ~uBiNG ~ _ ttom TVD ~_ Wt Orade Thread~~ Bo 2 875 ~F,li 3500 , 6.50~88~ EUE8RMOD I 0 _ Gasuft ----- _ __ Perforations Summary MandrelNawe ,. T ,., ~ Interval TVD Zone Status Ft SPF Date T _ _ Comment 1 (4955-4956, ~`~ 5122 - 5154 3562 - 3591 WS D 32 4 3/20/1999 IPERF 2.5" HCBH 5188 - 5224 3623 - 3657 WS B 36 4 3/20/1999 IPERF 2.5" HCBH - 5238 - 5244 3670 - 3676 WS A4 6 4 3/20/1999 IPERF 2.5" HCBH 5284 - 5290 3714 - 3719 WS A3 6 4 3/20/1999 IPERF 2.5" HCBH 4' 5300 - 5320 3729 - 3748 WS A3 20 4 3/20/1999 IPERF 2.5" HCBH 5326 - 5332 3753 - 3759 WS A3 6 4 3/20/1999 IPERF 2.5" HCBH y " 5352 - 5364 3778 - 3789 WS A2 12 4 3/20/1999 IPERF 2.5" HCBH 5378 - 5396 -- 3802 - 3819 - WS A2 18 4 3120!1999 - IPERF 2.5" HCBH NIP Gas Lift Mandrels/Valves (50035004, oD:3sso) -...,.. _ -- -- _. ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv St ; ', 4 55~ 3408 ~ CAMCO I, KBMG CAMCO Sr ~~~ 1.0 BEK o r~~ ~~) 0 '12/28/2007 -- - 'Othe_r__(plu s e uip., etc..-_COMPLETION - Da th TVl) T Descrl tlon ID 1 1 PATCH SURFACE CASING PATCH 9' 3" Ion .SET 10/5/2006 5.500 38 38 HANGER VETCO GRAY TUBING HANGER & DOUBLE PIN PUP 3.500 41 41 XO CROSSOVER 3.5" TO 2.875" 2.875 xo (5oa35oaa, - 490 487 NIP CAMCO 2.875" NIPPLE w/2.312" DS PROFILE 2.312 OD:2.875) 5003 3452 NIP CAMCO'D'NIPPLE 2.250 5043 3488 XO CROSSOVER 2.875" TO 3.5" 3.500 seal --``° 5044 3489 SEAL BAKER LOCATOR SEAL ASSEMBLY 3.000 (5044-5056, OD:4 000 `' ~ 5646 4055 PLUG Set Baker Bridqe Pluq for PBTD. 0.000 . ) ~'' Perf (5122-5154) Perf (5188-5224) Pert (5238-5244) Perf (5284-5290) Perf (5300-5320) 'RODUCTION (50565790, OD:3.500, Wt:9.30) PLUG (5646-5647, OD:3.500) r~ 1 D-132 Summary DATE Summary 1/4/08 PULLED BPV, SET 2.25" CAT SV @ 5002' RKB, PULLED SOV @ 4955' RKB, REPLACED w/DV, MITT TO 3500 PSI, PASSED, MITxIA TO 3000 PSIG, PASSED, PULLED CAT SV @ 5002' RKB, COMPLETE. 1/5/08 Removed solids from 5,133' - 5,643.4' RKB (TOP OF BAKER CIBP SET MARCH 1999). Well freeze protected to 5,643.4' RKB with slick diesel. Hand over to production for injection. 2/11/08 MITIA (PRE- STATE WITNESSED) -PASSED 2/12/08 STATE WITNESSED MITIA (BOB NOBLE) -PASSED MEMORANDUM To~ Jim Regg P.I. Supervisor ~~ ~i~2"Zi~t~7j FROM: Bob Noble Petroleum Inspector State of Alaska • • Alaska Oil and Gas Conservation Commission DATE: Tuesday, February 19, 2008 SUBJECT: Mechanical Inteo-ityTests CONOCOPHILLIPS ALASKA NC tD-132 KUPARUK RIV U WSAK 1D-132 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~~~ Comm Well Name: KUPARUK RIV U WSAK ID-132 API Well Number: so-oz9-22895-00-0o Inspector Name: Bob Noble Insp Num: mitRCN0802 1 9 1 2093 9 Permit Number: 198-121-0 ~~ Inspection Date: 212;2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well { 1D-132 Type Inj. ~ W ~ TVD ~ 3490 ~ IA 1080 ~ .2530.. ~-~ - -2480 ~ 2480 ~ ~ P T 19a1zIO !TypeTest I, sPT ~ Test psi lsoo ~ OA ~ ~ ! !, Interval wxrcovR p~F P ~ - Tubing ! 910 ~ 9to I 9IO i 910 ~~ Notes: - ~~R~ FEB 2 9 2008 Tuesday, February 19, 2008 Page l of I a 12/20/07 ~7~r~~U~~G~~r~ ~~v~~~~ ~~lr ~ ~ ~~~~ Schlumberger -DCS ~ - ~ ~ ~'a ~r" 2525 Gambell Street, Suite 400 ~"" Anchorage, AK 99503-2838 ATTN: Beth 4••.~~•~~>. ~~ ~~r'ti Well Job # Log Description NO.4532 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 1J-105 11837540 INJECTION PROFILE ~`~~}-(~''.~-- 11120107 1 1A-06 11837542 RST WFL ~•~ _~JG i, 11/22/07 1 10-05 11837537 LDL C - ( 11/17/07 1 16-12 11970607 INJECTION PROFILE 'T 12/04107 1 2N-327 11996582 OILPHASE SAMPLER Q~- (0 12115107 1 1D-132 11994588 SBHP SURVEY ~(_ - ~ 12/17107 1 3H-106 11996580 PATCH EVALUATION = 12/13/07 1 3N-02A 11970609 LDL '$ - 12/05/07 1 1C-125 11964553 INJECTION PROFILE - 12101107 1 2M-15 NIA PRODUCTION PROFILE ( ~ " 12110/07 1 2M-11 NIA PRODUCTION PROFILE '(q ~ ( 12108/07 1 3A-03B 11970604 SCMT '•~- J 12/01107 1 2T-217A 11978431 SCMT - 12/15/07 1 2L-330 11837544 FULLBORE MICRO SCANNER 11127107 1 2L-330 11837544 SONIC SCANNER 11127/07 1 • • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~ ~ ~ ~' ~ ~ I~ ~ SARAH PAL/N GO VERNOR 333 W. 7th AVENUE, SUITE 100 COI~SERQATIO O~IIDSSIOl~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Howard Gober FAx (907) 276-7542 Wells Group Engineer Conoco Phillips Alaska Inc PO Box 100360 Anchorage, Alaska 99510 l~~ DEC ~ ~ 2007 ,, r ~-~ i~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1 D-132 Sundry Number: 307-375 Dear Mr. Gober: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing, A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next workin day if the 23rd day falls on a holiday or weekend. A person ma not a g a Commission decision to Superior Court unless rehearing has been requested. DATED this~day of December, 2007 Encl. Sincerely • ~~ Cal'14COP~"11 S ~ 1 CJ-~ Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 14, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak Well 1 D-132 (PTD# 198-121 }. Injecting well 1 D-132 was drilled and completed in 1998. The well operated on water injection until July 2005 when it failed an MITIA. In October 2006 the well passed a Combo MIT after an external patch was installed on the casing near surface. A TecWel leak detect log located tubing leaks at 4,877'MD, and 1,810' MD. Caliper logs have identified multiple joints with 30-40% wall loss. Therefore, the tubing will be replaced rather than attempting to patch it. ~' The purpose of the proposed workover will be to pull the existing 3-1/2" tubing string and replace it with a new 2-7/8" tubing. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 263-4220. Sincerely, Howard B. G ber Wells Engineer CPAI Drilling and Wells Alaska flil & Gas ~,~n~, ~a~~ris~li~sar I 2_~ 211 U~ IL ?~l SEC 1 4 ( STATE OF ALASKA ~ ~d~~ ALASKA OIL AND GAS CONSERVATION COMMISSION + ka ~a~ ~ ~3S I.~Of1S ~Of31tT11sSi0l1 APPLICATION FOR SUNDRY APPROV-~ 20 AAC 25.280 II~II~~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ ' Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing Q Perforate New Pool ^ Re-enter Suspended Wetl ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-121 ` 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22895-00 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 Requires? Y2S ^ NO ^~ 1D-132 ' 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25650, ALK 468 RKB 41', Pad 71' / /?' ~,iD aruk River Field /West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5802' 4203' 5406' 5646' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 16" 121' 121' PRODUCTION 5015' 5-1/2" 5056' 3500' PRODUCTION 734' 3-1/2" 5790' 4191' Perforation Depth MD (5122'-5154', 5188'-5224' Pertoration Depth TVD ft 3562'-3591', 3623'-3657', 3670'- Tubing Size: Tubing Grade: Tubing MD (ft): 5238'-5244', 5284'-5290', 5300'-5320', 5326'-5332',& 3676', 3714'-3719', 3729'-3748', 3753'-3759', 3778'-3789', 3802'-381 3-1 /2" L-80 5056' Packers and SSSV Type: 5352'-5364', 5378'-5396' Packers and SSSV MD (ft) sealbore at 5044' MD none no SSSV none 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 21, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Howard Gober @ 263-4220 Printed Name Howard Gober Title: Wells Group Engineer Signature Phone 263-4220 Date j Z.(~ Commission Use Onl ti f i i th i t diti l N tif t t C C Sundry Number: on so a represen ve may w ness on ons o approva : o y omm ss a a ,_ , / Plug Integrity ^ BOP Test ~ Mechanical Integrity Test I~Q Location Clearance ^ Other: ~ ~~ ~~ ` ~~~S~S \G~~~ ' ,~ ~~~ i~Et ~ ~ 20D7 ~ Subsequent Form Required: ~~ APPROVED BY / '" ~~" ~ Approved by: H COMMISSION Date: ! t Form 10-403 Revised 06!2006 V ~~ ~ ~'+~ ~ t,' ~~ Q ~ /'~"' /Z~ge~ Sint i~Zu~l~a~7 *****REVISED***** West Sak 1 D-132 Genera! Workover Procedure 12/19/07 Pre-Rig Work 1. Obtain an updated SBHP reading (Done 12/17107 -1777 psi corrected to mid-perf. 9.3 ppg kill fluid with no overbalance) 2. Tag fill. (Done 12!17/07 - 5133' RKB or 11' below the top pert) 3. Pull DV at 4949'MD 4. Set 3" CIW H BPV 5. Prepare location for arrival of Workover Rig General Workover Procedure 1. MIRU Nordic 3 2. Pull BPV. Load well with 9.8 ppg brine. 3. Set BPV. ND tree. MU blanking plug 4. NU 11" 5M BOP and pressure test to 25012,500 psi. (The last SBHP measurement was 1,720 psi on December 17, 2007 at 5,125' AAD (3,564' TVD). The gradient stop at 5,017 MD (3,464' ND) was 1,675 psi. Factrapolated to mid- perf the pressure is 1,777 psi. Fill was tagged on the SBHP run at 5,133' MD or 11' below the top pert. The calculated maximum possible surface pressure assuming a gradient of 0.1 psi/ft is 1,673 psi. 5. Pull 3.5" tubing and run new 2.875" tubing completion 6. Prior to setting new completion, load IA with corrosion inhibited brine 7. Pressure test to to 1500 psi. We will not be able to pressure test the tubing at this time due to open perforations. 8. Set 2 way check 9. ND BOPS, NU tree, and pressure test 10. Pufl 2 way check.. Freeze protect welt. Set BPV. 11. RDMO Workover rig Post-Ria Work 1. Pull BPV 2. Set plug in nipple just above the seal assembly. 3. Pull SOV and set DV in GLM 4. RU chart recorder. Pressure test tubing and lA separately to 2500 psi. Hold each test for 30 min and record on a chart recorder. 5. Pull plug in the nipple 6. FCO fill in liner with coiled tubing 7. Return to injection - Well: 1 D-132 API: 50-029-22895-00 ~.- ConocoPhillips Field: WestSak PTD: 198-121 2007 RWO REVISED PROPOSED COMPLETION NEW COMPLETION WELLHEAD Lift threads: 3'/2' 8rd EUE BPV: 3" CIW H Model: Vetco West Sak Inj CONDUCTOR 16", 62.58 ppf, H-40, welded SURFACE CASING No Surface Casing in this Well PRODUCTION CASING 5.5", 15 ppf, L-80, BTC-MOD TUBING 2-7/8", 6.5 ppf, L-80, 8rd-MOD A: Nipple: 2-7/8° with 2.313" DS cLb 500' MD B: Gas Lift Mandrel No. MD TVD TYPE 1 4,949 3,402 1" KBMG C: Nipple: 2-718" with 2.25" D profile D: Seal Assembly @ 5,044' MD TUBING and LINER 3.5", 9.3 ppf, L-80, 8rd-MOD PERFS WS D: 5,122'-5,154' MD WS B: 5,188'-5,224' MD WS A4: 5,238'-5,244' MD WS A3: 5,284`-5,290' MD 5,300'-5,320' MD 5,326'-5,332' MD WS A2: 5,352'-5,364' MD 5,378'-5,396' MD Last Tag: 12/17/07 Tag Depth: 5,133' RKB Fill: 263' TD: 5,802' RKB Last Updated: 14-Dec-07 Updated by: HBG West Sak 1 D-132 General Workover Procedure 12/14/07 Pre-Ri Wo 1. Obtain n updated SBHP reading 2. Set IBP 3.5" liner. Perform positive and negativ pressure test on plug. 3. Dump bai aC03 on plug 4. Pull DV at 4 9'MD 5. Set 3" CIW H PV 6. Prepare locatio for arrival of Workover Rig General Workover Proc ure 1. MIRU Nordic 3 2. ND tree. MU blanking g 3. NU 11" 5M BOP and pre ure test 250/2,500 psi. (The last SBHP measurem t was ,042 psi on April 25, 2000, at 5,259' MD (3,690' TVD) which was at mi erf epth. Prior to rig arrival, an inflatable bridge plug will be set in the liner belo a seal assembly. Because of this, kill weight fluid should not be needed; h ever, in the event that the plug fails, the estimated brine weight needed t id-perf would be 10.6 ppg. Assuming a 125 psi overbalance, the brine w ht uld need to be 11.3 ppg. The calculated maximum possible surface essure ssuming a gradient of 0.1 psi/ft is 1,673 psi.) 4. Pull 3.5" tubing and run ew 2.875" t i 5. Prior to setting new co pletion, load IA 6. Pressure test tubing nd IA #0 2500 psi. 7. Set BPV 8. ND BOPE, NU tr ,and test tree 9. Freeze protect ell 10. RDMO worko r rig ng completion ~,cvith corrosion inhibited seawater ~ ~ ~c~ c ~~ (c~-o~ ~ Post-Rig Work 1. Pull BP 2. Pull S and set DV in GLM 3. Bail C03. Pull IBP. 4. Tag fill 5. Return to injection • • Well: 1 D-132 API: 50-029-22895-00 ~~"tjll~p$ Field: WestSak PTD: 198-121 2007 RWO PROPOSED COMPLETION / WELLHEA Lift threads: 3%" 8rd UE BPV: 3" CIW H Model: Vetco West Sak I CONDUCTOR 16", 62.58 ppf, H-40, welded SURFACE CASING No Surface Casing in this Well PRODUCTION CASING 5.5", 15 ppf, L-80, BTC-MOD TUBING and LINER 3.5", 9.3 ppf, L-80, 8rd-MO PERFS W S D: 22'-5,154' M D W S B' ,188'-5, 224' M D WS 5,238'-5,244' MD W 3: 5,284'-5,290' MD 5, 300'-5, 320' M D 5, 326'-5, 332' M D W S A2: 5, 352'-5, 364' M D 5, 378'-5, 396' M D I A I B D NEW OMPLETION A: Ni e: /8" with 2.313" DS @ 500' MD B: Gas Lift Mandrel No. MD TVD TYPE 1 --4,949 3,402 1" KBMG C: Nipple: 2-7/8" with 2.25" D profile D: Seal Assembly @ 5,044' MD ~~ ~ ice. ~1 ~J~ ~ Last T :07/49/01 Tag Depth. ,406' RKB Fill: n ill TD: 5,802' B Last Updated: 14-Dec- Updated by: HBG 1 D-132 (PTD 198-121) Rev General Workover Procedure Page 1 of 1 • Maunder, Thomas E (DOA) From: Gober, Howard [Howard.Gober@conocophillips.com] Sent: Wednesday, December 19, 2007 4:55 PM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: 1 D-132 (PTD 198-121) Revised Genera! Workaver Procedure Attachments: 1D-132 Revised Sundry Procedure.doc; 1D-132 Revised Proposed Schematic.xts Tom, The 10-403 was submitted last week for the workover on West Sak injector 1 D-132 (PTD 198-121 }. We completed a tag and shut-in bottom holes pressure survey on Monday (12!17}. We have f[t covering all but 11' of the perfs. My original plan was to isolate the perfs with an inflatable bridge plug. Wth no rat hole, t am hesitant to run this plug. Therefore, l wilt plan to do the workover with kill weight fluid. lam planning on using 9.8 ppg. Without a plug isolating the perforations, 4 will not be able to pressure test the tubing on the rig. The post rig work will include separate pressure tests of the tubing and IA to 2500 psi which will be recorded on a chart recorder. The fill in the finer will be cleaned out by coiled tubing during the past rig work. 1 have also included a revised proposed completion schematic for your review. Please let me know if you have any questions. «1 D-132 Revised Sundry Procedure.dor>> «1 D-132 Revised Proposed Schematic.xls» Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cefl Howard. Gober@conocophiilips.com 12/21 /2007 . ConocJ'Phillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 December 29, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7tl1 Avenue, Suite 100 Anchorage, AK 99501 SCANNED JAN 1 6 2007 <b~ \~\ \0\ Dear l\IIr. Maunder: 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 by surface casing annulus. The voids were fIrst fIlled with cement to a level of approximately 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 that was 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 top-fill operation was completed on December 16, 2006 and the sealant top was completed on December 27,2006 for IH-Pad and December 28,2006 for ID-Pad. Schlumberger Well Services mixed 15.7 ppg Expando cement in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The 2401 sealant was pumped in a similar manner. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself or M.l. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~cO~ Jerry Dethlefs ConocoPhillips Problem \Vells Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 12/29/2006 Initial Top Cement Final Top Sealant Well Name PTD# of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Oate Gallons Oate 1 H-01 193-006 12" na 12" na 7.4 12/27/2006 1 H-02 193-008 21' 4" 2.9 14' 6" 12/16/2006 na na 1H-10 193-030 4' na 4' na 29 12/27/2006 1 H-11 193-036 Surface na Surface na 1 12/28/2006 1 H-12 193-044 4'8" 0.6 8" 12/16/2006 4.98 12/27/2006 1 H-13 193-049 6' 0.8 4' 12/16/2006 29 12/27/2006 1H-14 193-052 35' 4.7 12" 12/16/2006 7.4 12/27/2006 1 H-18 193-020 14'4" 2.7 12" 12/16/2006 7.4 12/27/2006 1 H-21 193-046 4" na 4" na 2.4 12/27/2006 1 H-40 1 198-101 45' 4.4 18" 12/16/2006 20.1 12/27/2006 10-109 197-235 10'9" 2.1 12" 12/16/2006 10.8 12/28/2006 10-110 200-039 8'6" 1.4 10" 12/16/2006 9 12/28/2006 10-111 198-166 17' 7" 3.4 25" 12/16/2006 21 12/28/2006 1 0-120 197-221 13'6" 2.9 18" 12/16/2006 16 12/28/2006 10-121 197-181 13' 2.2 20" 12/16/2006 16.2 12/28/2006 1 0-132 198-121 10'8" 2.0 14" 12/16/2006 11 12/28/2006 1 0-133 197-206 6' 1.0 6" 12/16/2006 4.6 12/28/2006 1 0-136 200-046 10'2" 2.0 10" 12/16/2006 6.4 12/28/2006 10-137 200-047 11 ' 2.00 24" 12/16/2006 13.2 12/28/2006 1 0-138 200-048 11' 7" 2.3 4'6" 12/16/2006 29.7 12/28/2006 10-139 200-049 11'2" 2.2 18" 12/16/2006 9.9 12/28/2006 1 0-140 200-136 29'9" 3.4 12" 12/16/2006 na na . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE: Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West Intemational Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) 2) 3) 4) 5) 6) 7) 1 BL / EDE Disk 1 D - 132 Caliper Report 30-Dec-06 sCANNED JAN 0 8 2007 U.I~ 191- ,~\ -äc (t-/30Cl Signed : ß (l //~ l' ~ ¡I7¡J. )v f..')¡ á~j/Lf'_ i i aÚ//1 \ <U" Date,:' . ~ ..- ,/', ,,---;", --;j Print Name: PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAil: ~.', ,- '>. -. ,,"',. ""'~- , .,,:-_. ,-'-:--' _.~-:..~~~~.~- "",. -<---~- WEBSITE :C".c -."-",,.-.-.'- D:\OO _ PDSAi'-JC~2006\Z__ \V ord\ DistributlOn\Transmittal__ Sheets\TransmIt_ Origmal. doc I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Oate: Log No. : Run No.: Pipe1 Oesc.: Pipe1 Use: ConocoPhillips Alaska, Inc. December 30, 2006 8571 1 3.5" 9.3 lb. L-80 EUE Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 1D-132 Kuparuk Alaska 50-029-22895-00 Surface 5,074 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the DS No Go @ 5,007' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damage. The caliper recordings indicate the 3.5" tubing logged is in good to poor condition, with a maximum recorded wall penetration of 40% in the pup joints above and below the GLM. Wall penetrations from 20% to 40% wall thickness are recorded from 2,100' to 5,074'. The recorded damage appears in the form of a line of pits on the low side with intermittent areas of corrosion. No significant areas of cross-sectional wall loss or 1.0. restrictions are recorded throughout the interval logged. MAXIMUM RECORDED WALL PENETRATIONS: Line of pits Line of pits Line of pits Line of pits Line of pits 4,968 Ft. (MO) 4,940 Ft. (MO) 4,886 Ft. (MO) 3,717 Ft. (MO) 3,814 Ft. (MO) ( 40%) ( 40%) ( 39%) ( 35%) ( 35%) Jt. Jt. Jt. Jt. Jt. 156.3 @ 156.1 @ 155 @ 118 @ 121 @ MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No areas of significant cross-sectional metal loss (> 4%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant 1.0. restrictions are recorded throughout the 3.5" tubing logged. RECE\VE JAN 0 9 ZOO] ~OiI&GasCons, And'\Ofage I Field Engineer: K. Miller Analyst: M. Lawrence Witness: C. Fitzpatrick Pro.A.ct¡ve Diagnostic Serv'¡ces! Phone: or (888) 565-9085 Fax: Prudhoe Bay Field Office Phone: Stafford,. 7ï497 565-1369 E-maiì: PDS(gJmemorylog,com 659-2307 Fax: 659-2314 l> ..L c.... l Cî 'Õ" - 19 ( ti: 143CA I I Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (35.5' - 5070.9') Well: Field: Company: Country: Survey Date: 10- 132 Kuparuk ConocoPhiUips Alaska, Inc. USA December 30, 2006 I I I Approx. Tool Deviation Approx. Borehole Profile I 25 44 I 806 I 50 1590 I I 0 '- 75 2375 :?: (l) ...a .¡..J E u... ::::; ¡: Z ...c: ..... Î5- .£:= (l) 2 0 100 3153 I I 125 3926 I I 150 4713 I GlM 1 I 158.4 o 50 5071 100 Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Su rvey = 1 58.4 I I I I I Well: Field: Company: Country: 10-132 Kuparuk ConocoPhillips Alaska, Inc. USA I Tubing: Nom.OD 3.5 ins Grade & Thread l-80 Weight 9.3 f I I Penetration ami Metal loss (% wall) penetration body metal loss body I 100 150 I 50 o o to 1% 1 to 10%, 10 to 20 to 40 to over 20% 40% 85% 85% I o o I pene. loss I Damage Configuration ( body) 100 I 80 60 40 I 20 o I isolated pitting general line ring hole / poss corrosion corrosion corrosion ible hole I o I I PDS Report Overview ody Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal 51: Nom.lD 2.992 ins Bottom of Survey = 1 Analysis Overview page 2 I I December 30, 2006 MFC 24 No. 00387 1.69 24 M. Lawrence Nom. Upset 3.5 ins Upper len. 6.0 ins lower len. 6.0 ins Damage Profile (% wall) penetration body o o metal loss body 50 100 GlM 1 I I PDS REPORT JOINT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-132 Kuparuk ConocoPhillips Alaska, Inc. USA December 30, 2006 I Joint Jt. Depth Pen. Pen. F'en. Metal Min. Damag e Profile No. (Ft) \~::::(;I Body I.D. Comments (% wall) (Ins.) (Ins.) 0 50 100 .1 35 () 0.01 2 0 2.92 PUP .2 38 0 0.01 " 'I 2.95 PUP !" 1 44 0 0.03 10 I 2.94 2 76 0 0.01 0 2.95 3 109 0 0.02 0 2.95 4 141 0 0.01 I 2.95 5 172 I 0.01 t I 2.95 6 204 () 0.01 2.94 7 236 0 0.01 2.95 8 268 0 0.01 2.93 9 299 D 0.02 7 2.95 10 331 0 0.02 2.94 11 363 D 0.02 1 2.95 12 394 D 0.02 D 2.94 13 426 0 0.01 0 2.96 14 458 0 0.02 I 2.94 IiJI 15 489 D 0.01 6 D 2.95 prI 16 521 () 0.02 9 I 2.96 IiJI 17 552 0 0.02 ( () 2.95 IiJI 18 584- D 0.02 0 2.95 IiJI 19 616 D 0.01 D 2.95 ~ 20 647 () 0.02 I 2.94 11II 21 679 0.01 D 2.95 22 711 0.02 2.95 11II 23 742 0.01 t () 2.95 ¡¡¡ 24 774 0.01 () 2.95 25 806 ( om 0 2.94 III! 26 836 I 0.01 0 2.95 27 867 I 0.01 D 2.94 28 898 0 0.02 1 2.95 11II 29 930 () 0.01 ( I 2.95 30 961 () 0.02 9 () 2.95 III! 31 993 () 0.01 3 0 2.94 32 1025 0 0.01 6 0 2.95 33 1057 () 0.01 I 2.95 34 1088 () 0.02 II 2.95 35 1119 () 0.02 1 2.95 36 1150 D om ) I 2.95 37 1181 D 0.02 0 2.94 IiJI 38 1213 ( 0.01 5 2 2.95 II 39 1245 ( 0.01 6 0 2.94 fII 40 1276 ( 0.01 , 1 2.95 I 41 1306 ( 0.01 t 0 2.95 fII 42 1338 D 0.02 0 2.94 IiJI 43 1368 0 0.03 D 2.95 44 1400 0 0.02 D 2.95 IiJI 45 1431 D 0.02 () 2.94 III! 46 1463 () 0.02 9 I 2.96 III! 47 1495 0 0.01 5 () 2.94 48 1527 0 0.01 4 I 2.95 I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf 1-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-132 Kuparuk ConocoPhiDips Alaska, Inc. USA December 30, 2006 I Joint Jt. Depth Pel 'I Pen. Pen, I !\/le'lal Min. Damage P rofile No. (Ft.) Body I.D. Comments (%wall) Ii (Ins.) (Ins.) 0 50 100 49 1559 0 0.ü3 1;) II 2.95 50 1590 0 0.ü3 1 ! 1 2.94 Shallow nitlin<>. ¡ 51 1621 0 0.01 ¡ 2.95 52 1652 0 0.01 2.95 53 1684 0 0.01 S- 2.95 54 1715 0 0.D2 7 2.95 55 1747 0 0.02 e 1 2.95 56 1779 0 =;ii'!1 2.94 57 1810 0 2.95 58 1842 0 O. ! 2.94 59 1873 0 0.01 2.95 60 1905 0 0.02 ( 2.94 61 1937 0 0.01 ~i 2.94 62 1968 0 0.02 g 2.94 III 63 2000 0 0.01 1 0 2.94 64 2031 0 0.02 q () 2.94 III 65 2063 () 0.ü3 1 ì 2.94 Shallow line of nits. ~ 66 2095 () 0.ü3 1 ! 2.95 Shallow line of nits. 67 2127 () 0.08 11 ) 2.95 Line of nits. 68 2158 0 0.04 1H ) 2.94 Shallow line of nits. 69 2187 0 0.04 1(, 2.94 Shallow line of nits. 70 2219 0 0.05 "0 ) 2.95 Line of nits. 71 2250 (I 0.05 ;> 2.94 Line of nits. 72 2281 (I 0.04 I 2.94 Shallow line of nits. 73 2312 0 0.05 I 2.94 ShaHow line of nils. 74 2344 0 0.05 ) 2.93 Shallow line of nits. 75 2375 0 0.04 i 2.93 Shallow line of nits. 76 2407 0 0.07 51) ) 2.94 Line of nits. 77 2437 (I 0.05 5ii ¡ 2.95 Line of nits. 78 2468 0 0.06 n ) 2.94 Line of oits. 79 2499 0 0.ü3 1 2.96 Shallow line of nits. 80 2530 0 0.05 I 2.95 Line of nits. I'II~ 81 2562 0 0.04 1 2.97 Shallow line of nits. .11I 82 2590 0111, 0.06 i ) 2.94 Line of nits. 83 2618 0 0.06 I 2.94 I ine of nits. 84 2648 0 0.07 "'2]; ) 2.95 Line of nits. 85 2680 I 0.06 ) 2.94 Line of nits. 86 2711 I 0.06 ¡ 2.95 Line of nits. 87 2743 I 0.06 i 2.94 Line of nits. 88 2774 I 0.06 ;> 2.94 Line of nils. 89 2806 001\ 0.ü3 1 2.94 Shallow line of nits. 90 2837 () 0.05 1 ) 2.94 Shallow line of nits. 91 2869 0 0.05 Ii I 2.95 Shallow line of nits. 92 2900 0 0.06 14 ) 2.93 Line of nits. 93 2932 0 0.06 ~ 2.95 Line of nits. 94 2964 0 0.ü7 ;> 2.94 Line of nits. 95 2995 0 0.05 ! 2.95 Shallow line of nits. 96 3026 0 0.08 ! 2.94 Line of nits. ! 97 3058 0 0.05 1 2.95 Shallow line of nils. 98 3090 0 0.04 ,- 1 2.96 Shallow line of nils. I I I I I I I I I I I I I Body Metal Loss Body Page 2 I I I I PDS REPORT JOINT TABULATION SHEET I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-132 Kuparuk ConocoPhillips Alaska, Ine. USA December 30, 2006 I Joint Jt. Depth 1\'1 Pen. PE'n, i i\rletal Min. Damage Pr ofile No. (Ft.) Body 1.0. Comments (%wall) (Ies) (Ins.) (Ins.) 0 50 100 99 3121 0 0.07 ) 2 2.96 Line of nits. 100 3153 0 0.03 1 2.94 101 3182 0 0.02 2.96 102 3213 0 0.03 " 2.94 103 3245 I 0.06 2.94 Line of nits. 104 3274 I 0.01 6 2.96 105 3306 0,09 0.02 9 2.96 Pittirm. in uoset. 106 3337 I 0.08 31 2.95 I ine of oits. 107 3366 0 0.04 2.95 Shallow line of oils. 108 3397 0 0.07 2 2.95 Line of nits. 109 3427 0 0.04 , 2.95 Shallow line of nils. 110 3458 0 0.06 2 2.95 Line of nits. 111 3490 0 0.05 21 I 2.93 Line of nits. 112 3520 0 0.05 20 ! 2.94 Line of nits. 113 3551 0 0.04 i6 I 2.94 ShaJlow line of oils. 114 3583 0 0.05 1 2.95 Line of oits. 115 3614 0 0.05 I 2.94 Shallow line of oils. 116 3646 0 0.05 j 2.95 Shallow line of oils. j 117 3677 0 0.06 I 2.94 Li ne of ni ts. 118 3708 n 0.09 Vi ) 2.95 Line of nits. 119 3739 n 0.06 24 2 2.94 Line of nits. 120 3769 II 0.06 L 1 2.94 Line of nits. 121 3800 0 0.09 2 2.94 Line of nits. 122 3831 II 0.06 I 2.94 Line of oits. 123 3863 II 0.06 2 2.95 Line of nits. 124 3895 0 0.05 I 2.94 Shallow line of oils. 125 3926 0 0.07 I 2.94 Line of nits. 126 3958 ( 0.05 2 2.94 Corrosion. 127 3989 ( 0.04 I 2.94 Shallow line of oils. 128 4020 I 0.06 2 2.94 Line of oits. 129 4052 I 0.06 I 2.94 Line of oits. 130 4082 0 0.05 1 2.95 Shallow line of oils. 131 4114 ( 0.05 I 2.95 Line of nits. 132 4146 0 0.05 I 2.93 Shallow line of oils. 133 4177 I 0.06 2 2.95 Line of nits. 134 4209 ( 0.04 I! I 2.95 Shallow line of nils. 135 4240 O( J9 0.06 j' 2 2.95 Line of nits. 136 4271 I 0.08 I 3 2.95 Line of oits. 137 4303 I 0.08 2 2.95 Line of oits. 138 4334 0 0.07 ~j 2.95 Line of nits. 139 4366 0 0.08 2 2.95 Line of nits. 140 4397 0 0.07 2 2.94 Line of oits. 141 4429 0 0.08 2.93 Line of nits. 142 4460 0 0.08 2.95 Line of nits. 143 4492 0 0.09 2.94 Line of nits. 144 4524 0 0.05 2.95 Shallow line of oils. 145 4555 II 0.08 2.95 Line of oits. 146 4587 II 0.07 2.94 Line of oits. 147 4618 II 0.07 2.95 Line of nits. 148 4650 ( 0.07 2.95 Corrosion. I I I I I I I I I I I I I Body Metal Loss Body Page 3 I I I I PDS REPORT JOINT TABULATION SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf l-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 10-132 Kuparuk ConocoPhillips Alaska, Ine. USA December 30, 2006 I Joint It. Depth Peli, Pen. Per: Vletal Min. Damage Profile No. (Ft.) Upse: Body ;s 1.0. Comments (%wall) (Ii .) (Ins.) (Ins.) 0 50 100 149 4682 () 0.06 25 2.95 Line of oits. 150 4713 0 0.05 20 2.95 Line of oits. 151 4745 0 0.06 22 2.95 Line of oits. 152 4777 () 0.07 2.94 line of pits. 153 4808 () 0.08 2 2.94 Line of nits. 154 4840 () 0.07 2 2.95 Line of pits. 155 4871 0 0.10 2 2.95 Line of oits. 156 4903 I 0.05 1 2.93 ShaHow line of pils. , 156.1 4935 0 0.10 2.96 PUP Line of pits. 156.2 4949 0 0 I N/A GlM 1 (latch @ 3:00\ 156.3 4956 o 16 0.10 0 2.95 PUP line of oits. 157 4970 0.06 ') 2.94 Corrosion. 157.1 5001 I 0.01 I 2.94 PUP 157.2 5007 ( 0 I) 2.87 OS NO GO 157.3 5009 I) 0.02 2 2.96 PUP 158 5015 I) 0.09 4 2.95 Line of nits. 158.1 5046 I) 0 I 3.00 SBE 158.2 5052 I) 0 I 3.00 SEALS 158.3 5065 I) 0.08 32 2.94 PUP Line of oits. 1 58.4 5071 0 0.04 15 2 2.93 PUP Shallow line of nits. I I I I I I Body Metll loss Body I I I I I I I Page 4 I I ------ Well: Field: Company: Country: Tubin : ........- .. .. ........ .. .. PDS Report Cross Sections 10-132 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L-80 December 30, 2006 MFC 24 No. 00387 1.69 24 M. Lawrence Survey Date: Tool Type: Tool Size: I'-JO. of Fingers: Anal st: Cross Section for Joint 156.3 at depth 4968.283 ft Tool speed = 52 Nominal 10 = 2.992 Nominal 00 = 3.500 Remaining wall area = 97 % Tool deviation 32 0 Finger 13 Penetration = 0.102 ins Line of pits 0.10 ins = 40% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ------ Well: Field: Company: Country: Tubin : ------- - - P S Report ross S ons 10-132 Kuparuk ConocoPhillips Alaska, Inc. USA 3.5 ins 9.3 f L·80 December 30, 2006 MFC 24 No. 00387 1.69 24 M. Lawrence Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 156.1 at depth 4939.606 ft Tool speed = 52 NominallD = 2.992 Nominal OD 3.500 Remaining wall area 97 % Tool deviation = 38 0 Finger 14 Penetration = 0.101 ins Line of pits 0.10 ins = 40% Wall Penetration HIGH SIDE = UP Cross Sections page 2 - - - - I KRU 1 D-132 I TIJ~! .;J£. API: 500292289500 Well Tvoe: INJ Anole rm TS: deo@ SSSV Type: NONE Orig 7/30/1998 Angle @ TO: 18 deg @ 5802 Comoletion: Gas Lift Annular Fluid: 8.7000 brine LastW/O: Rev Reason: Pull Plua, Set WRP I ndrel/Oummy Reference Loa: Ref Loo Date: Last Undate: 8/29/2005 Valve 1 (4949-4950, Last T ao: 5406' TO: 5802 ftKB 00:4.725) Last T ao Date: 7/19/2001 Max Hole Anole: 59 deo @ 1937 TUBING Stril'l!"f",ÄLt (0-5056, 00:3,500, DescriDtion Size Too Bottom TVD WI GraciA I Thread 10:2.992) CONDUCTOR 16.000 0 121 121 62.58 H-401 WELDED , ROOUC110N PRODUCTION 5.500 0 5056 3500 15.00 L-80 r BTCM (0-5056, 00:5,500, PRODUCTION 3.500 5056 5790 4191 9.30 L-80 I EUE Wt:15,OO) U[:I!na Size I Ton I Bottom 1 TVD I Wt I Grade I Thread 3.500 I 0 I 5056 I 3500 I 9.30 I L-80 EUE NIP (5007-5008, Interval TVD Zone Status Ft SPF Date Tvee Comment 00:4.550) 5122-5154 3562 - 3591 WSD 32 4 3/20/1999 IPERF 2.5" HCBH 5188 - 5224 3623 - 3657 WSB 36 4 3/20/1999 Ii 2.5" HCBH 5238 - 5244 3670 - 3676 WSM 6 4 3/2011999 2.5" HCBH 5284 - 5290 3714 - 3719 WSA3 6 4 3/20/1999 2.5" HCBH 5300 - 5320 3729 - 3748 WSA3 20 4 3/20/1999 IPERF 2.5" HCBH 5326 - 5332 3753 - 3759 WSA3 6 4 3/20/1999 IPERF 2.5" HCBH 5352 - 5364 3778 - 3789 WSA2 12 4 3/20/1999 IPERF 2.5" HCBH ~96 3802 - 3819 WSA2 18 4 3/20/1999 IPERF 2.5" HCBH TVO Man Man Type V Mfr I V Type I V 00 I latch I Port I TAO T ~~~ I C~~t Mfr SSE 1 I 4949 3403 CAMCO KBG CAMCO I DMY I 1.0 I BK I 0.000 1 0 17/26/19981 (5044-5045, ~êCllJili :....., , ·""'^'..cv 00:5,000) TVO Tv""" DescriDtion 10 3455 NIP CAMCO 'OS' NOGO 2.812 5044 I 3489 SBE BAKER GBH-22 LSA W/12' SEALS 3.000 5078 I 3521 PLUG WRP set 8120/2005 0.000 5646 I 4055 PLUG Set Baker Bridae PluQ for PBTD. 0.000 'ROOUC110N (5056-õ790, 00:3,500, Wt:9,30) PLUG (5078-5079, 00/2,780) Perf (5122-5154) - ,-- Perf - -- (5188-5224) = = Perf (5238-5244) == 1== Perf (5284-5290) = Perf - (5300-5320) - 1-,,- PLUG (5646-5647, 00:3,500) I I I I I I I I I I I I I I I I I Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: K f:: LA:: , V 1:: 0 . STATE OF ALASKA . OCT 11 2006 ALASKA Oil AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons C '. REPORT OF SUNDRY WELL OPERATIONS Anchora ~ ommlsslon o Time Extension 0 o Abandon 0 Alter Casing 0 Repair Well 0 . Pull Tubing 0 Operat. ShutdownO Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 P. O. Box 100360 7. KB Elevation (ft): RKB 112' 8. Property Designation: Kuparuk River Unit .APt.. 2S"t..50 P Ib'Z~'~ 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR PRODUCTION PRODUCTION Perforation depth: measured 5802' feet true vertical 4203' feet measured 5802' feet true vertical ~ r feet ýzÞ ~ )Þ !t:rJ.J·t>f Length Size MD 121' 16" 121' 4944' 5-1/2" 5056' 734' 3-1/2" 5790' Measured depth: 5122-5154,5188-5224,5238-5244,5284-5290 true vertical depth: 3729-3748,3753-3759,3778-3789,3802-3819 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 5056' MD. Packers & SSSV (type & measured depth) Baker GBH-22 pkr = 5044 no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl NA NA NA NA 15. Well Class after proposed work: Exploratory 0 Development 0 16. Well Status after proposed work: OilO GasO WAG 0 Oil-Bbl Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Contact 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Signature L. Jerry Dethlefs/MJ Loveland @ 659-7043 Jerry Dethlefs Title ~ Phone Form 10-404 Revised 04/2004 R\G\NAL Stimulate 0 Waiver 0 Other Exploratory Service Re-enter Suspended Well 5. Permit to Drill Number: 198-121 . 6. API Number: 50-029-22895-00 o o 9. Well Name and Number: 10-132 . 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3500' 4191' RBDMS 8Ft 0 CT 3 1 2006 Casin Pressure Tubin Pressure Service 0 GINJO WINJ 0 . WDSPL 0 xe t: F¿ IcXiltb Well Integrity Supv. 907-659-7043 Date: 10-8-06 kh\ ~ /O·Z7..dp ~~ð~/;~ · 1D-132 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/24/2006IWelder cut base plate free from conductor. Excavate & install shoring box. 9/28/2006 Conductor Removal, Cut conductor off @ 10' 8" below top of mandrel hanger, cleaned cement and buffed SC. Appears to be good SC @ 10' . Hole located 59" down from top of mandrel hanger. 9/28/2006 Notified AOGCC State inspector (Jeff Jones) @ 2:30 p.m. that the conductor has been removed and that they will have approx 3-5 days for a visual inspection of the damaged PC if they so choose. 10/5/2006 Weld SC patch. Patch is 9' 3" long measured from uppermost weld on wedding band, to lowermost weld on wedding band. Material used: 7", 26#, L-80, .500" wall drill casing. 10/6/2006 MITIA(Post SC Patch Weld) -passed. Pressured up IA to 3000 psi with .5 bbls of diesel, started MITIA- T/I=SI/3000 15 min reading-T/I=SI/2960, 30 min reading- T/I=SI/2950, 45 min reading- T/I=SI/2950, 60 min reading- T/I=SI/2950. Treat all exposed PC with Denso paste followed by Denso tape. Weld on 10'5" of 16" 62.5# API Gr B conductor w/ a 4" cementing/sealant nipple. MECHANICAL IrEGRITY TEST (MIT) FORM~ I I 10/6/2006 WELL NO.: 10-132 DATE: WELL TYPE: PWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITIA I i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 13000 Psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S} USED TO PRESSURE TEST: I Diesel R d II W IIh d P b ~ d d . T t ecor a e ea ressures e ore an unnQ es. START TIME: I 0900 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)*" (PSI)* (PSI)** FAIL S TUBING SI SI SI SI SI SI T IA 0 3000 2960 2950 2950 2950 - PASS OA 1 COMMENTS: START TIME:14:40 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** (PSI)* (PSI)** FAIL S TUBING T IA OA 2 COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE 45 MINUTE 60 MINUTE PASS T START TIME: PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA OA 3 COMMENTS: rSC COMMENTS, * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min 45 and 60 minute readings for extended tests only FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: ¡D. Sauvageau / J. Arend cc: PWS 6/3/00 L.twa: LOnOCOrm1l1pS J::,Xl,;aVaUUIl OC I\.I:::pal1 nUJt::l;tJ '-' .~ Subject: [Fwd: ConocoPhillips Excavation & Repair Project] From: Thomas Maunder <tom _maunder@admin.state.ak.us> Date: Tue, 20 lun 2006 07:00:24 -0800 '1'0: Lou Grimaldi <Iou _grimaldi@admin.state.ak.us>, John Spaulding ;<john_spaulding@admin.state.ak.us>, John Crisp <john_crisp@admin.state.alcus>, Jeff Jones -<jeff jones@admin.state.ak.us>, Chuck Scheve <chuck _ scheve@ådmfu.state.ak.us>, Jim Regg <jim _regg@admin.state.ak.us> All, Enclosed, FYI and scheduling, is a message from Problem Wells regarding the "big dig" project they will be starting soon. Jerry has also included a copy of the SPE paper he/they prepared regarding causes and repairs. Tom -------- Original Message -------- ConocoPhillips Excavation & Repair Project Mon, 19 Jun 2006 14:06:18 -0800 NSK Well Integrity proj <NI878@conocophillips.com> tom maunder@admin.state.ak.us NS¡(-Well---IntegrTty proj <N1878@conocophillips. com> , aogcc prudhoe bay@admin.state.ak.us \ \)..-. \ ~ d- \~~-\d-\ Subject: Date: From: To: CC: Tom: I don1t remember how much of our plans we have shared with you on excavating and repairing wells at 1C & 1D pads. We have been submitting a lot of 10-403s for the work and there is a reason for that. Starting in the next two weeks we will focus on this project, which is pretty ambitious. The attached spreadsheet lists the wells we intend to excavate. Some of these were determined this last year to have surface casing leaks. Others we have chosen to "pro-actively" excavate and inspect to get a better understanding of the level of damage to be expected for the other single casing wells. At any point in time we will have two wells in progress, and hope to continue for the bulk of the summer. A couple of them we will intentionally target late in the year when the ground has less water encroachment problems. We have submitted Sundry requests for all but one well, three of which are in the mail to you today. Like the others, we expect that you agree inspections and repairs on these wells are important and will approve those as well. As we go through the project we will keep the Inspectors notified of our progress so they can see these casings exposed. However, we will be under a tight timeline and will not hold excavations open longer than is necessary. Hopefully they can arrange to inspect them in the several day period that each of them is exposed. If you have any questions about our project please let us know. The SPE paper we wrote on the subject is a good primer on the mechanism involved. I have attached a copy in case there is interest in your shop. Talk to you soon. «IC and ID Casing Repair List AOGCC.xls» «SPE-I00432-PP SC Corrosion West Region 2006 Final.doc» SCANNED JUN 2 '7 2005 Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7043 IC and ID Casing Repair List Content-Type: application/vnd.ms-excel Content-Encoding: base64 SPE-I00432-PP SC Corrosion West Region 2006 FinaI.doc Content-Type: application/msword lof2 6/26/20067:51 AM "} PRIORITY 1 2 3 4 5 6 7 \<;<6-- \ d \ ---; 8 ---, 9 10 11 12 13 14 15 16 ) NAME 1 C-121 1 C-1 31 1 0-1 09 1 0-111 10-120 '" ". u, . "' . "'__'_'.~I"'_"___'" .__... !~-_.._---,_._--_.~_._..~:.~-~~!~~...~-_._.._........_..-. 1 Dh127.···...·.·:.·. . ____..:...:~_:_._.____: ____ ____._.:._...J 1 0-132 1 0- 136 1 D..137 -.... -. ._--~--.. ..-. --~ - -"-------.. .-..__.. 1 0-138 - .--....--.......-.-........-... 1 D-139 1_... . . ..___ _._.__.._.____...._....._ 1 C-119 -.-.----"-___.._____----t.........,--_~____._._.. .'-----~ --'1 . 1.Q-135·. .j : .---....--...... .:.,. -....~':-..,--. ~.....--...--...:..... ··..-·-··1 1D~135·/1 ..-.-..--.-..:: --...--.._~.~.~-_. ~~ .-~,",~..;.._. ":,'-"-- '-'--'-1 10-1,41 I ConocoPhillips Alaska, Inc. 1 C and 1 D Suñace Casing Corrosion Repair Candidates TYPE INJ INJ INJ INJ INJ Gas Lift Gas Lift INJ INJ INJ INJ INJ INJ Jet Pump ESP Gas Lift COMMENTS I STATUS PTD# LEAK DEPTH (ft) --- -..-,.-.,.--,---- 201-080 4 201-185 7 197 -235 5* 198-166 5* 197-221 7 197-181 None 198-109 None 198-121 5 200-046 None 200-047 None 200-048 8 200-049 None 201-139 16 201-220 None 197-184 None 200-112 None Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig Proactive dig, backup candidate (has 500' casing) Proactive dig backup candidate. Notes: 1. Repairs will be performed in the priority order as listed, two repairs in progress simultaneously. 2. 10-135 and 10-141 are backup options in case excavations cannot be made on other wells. 3. List is a combination of wells with known leaks (8) and proactive inspections (2 injectors and 3 producers). 4. Proactive inspections are scheduled for wells that are currently shut-in and should not have rate impacts except 1 C-135 Jet Pump producer. 5. Rate impacts may be encountered if neighboring wells are shut-in during excavator activities or if additional flowlines need removal. 6. If excavations cannot be completed prior to rig arrival then SIMOPS operations will be considered or delays will be encountered. NSK Problem Well Supervisor 6/26/2006 .-, :;-"'::Jf:"" :¡~ "n-J iÍ...¡.'~~ -:.1 il 1Ó:' \ '1, 'I "I r' \.' ,!! i' '\ 'I I . ~ "'," " ',-." . f1 '. '\. "I ,,.- 01'\\\ ~!i" : :.Ii ,\,;£1 U Uu L1 :L:::J { .=-"'~ -':J .: Jì ~ il ;1- I , I " ' , "i ~ :<! =:J I 1 1 J I , 'I,' .' ) ;~~j .l~ 1'7'-j' ~ .l~\, "-:-".\ r~;7 ,"'\ 1 {I\ \ ;:, ! ^ '\ C \~ ~ :1I./ ,/ il \ " U '\ :,! j iJ \ '.'\ ,1 :\\, /,1 \ 1 ';1 ~ j'.'\ \j' .", \ ,W '. :I i-: \ j "- ~ r-; ~ nJ ) " 1 \ \ ¡ n. :\ ..w ·w ~ ~ t.J ,~l iW \:~ ~I l"--:J FRANK H. MURKOWSKI, GOVERNOR A....ASIiA ORAND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 t 6( ß' ....t~ Brad Gatham Pro blem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 Re: KRU-West Sak 1D-132 Sundry Number: 305-225 '. ,'" .... f" C;1) C) ')00\:: j; C l4X\H\~ EL, /\ liL-:~ ~ (.) Co ..) Dear Mr. Gatham: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter; or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decisio to Superior Court unless rehearing has been requested. DATED this4day of August, 2005 Encl. 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 5802' 4203' Casing Length Size Perforation Depth MD (ft): 5122-5154,5188-5224,5238-5244,5284-5290 5300-5320,5326-5332,5352-5364,5378-5396 Packers and SSSV Type: Baker GBH-22 no SSSV 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name¥~~athman RBDMS 8Ft tll'h ?? 7005 Signature ~ ~ Commission Use Only 1. Type of Request: Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: p, O. Box 100360 7. KB Elevation (ft): RKB 112' CONDUCTOR PRODUCTION PRODUCTION 121' 4944' 734' ~:' (J 1; J d / / '::>/ ~ CfYJ f3 /16-é)G k RECEIVED cz-¡~ AUG 11 Z005 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL D D D 20 AAC 25.280 Suspend D Operation Shutdown D Repair well 0 Plug Perforations D Pull Tubing D Perforate New Pool D 4. Current Well Class: Development D Stratigraphic D Exploratory D Service 0 Perforate D Alaska ~i~ Gas&nsA~n~ßrnl~_'~ AncliMage D Time Extension 0 Other D Re-enter Suspended Well D 5. Permit to Drill ~ber: 198-121 V 6. API Number: 50-029-22895-00 ,/ Stimulate 9. Well Name and Number: 1 D-132 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Burst Collapse 16" 121' 5056' 5790' 5-1/2" 3-1/2" Perforation Depth TVD (ft): 3562-3591,3623-3657,3670-3676,3714-3719 3729-3748,3753-3759,3778-3789,3802-3819 Packers and SSSV MD (ft) pkr = 5044 no SSSV 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D Gas D WAG D GINJ D Tubing Size: Tubing Grade: Tubing MD (ft): 3-1/2" L-80 5056' Service 0 Plugged D WINJ 0 Abandoned D WDSPL 0 8-15-05 Date: Contact: MJ Loveland/Marie McConnell Title: Problem Well Supervisor Phone (".'51 "1~ z. 'I Date ¥" I .. 0 r Conditions of approval: Notify Commission so that a representative may witness Sundry Number: /~ff-2.2.5 Mechanical Integrity Test ~ Location Clearance D Other ~cA\L~( :S:"'>\>«.c~ ~'Q~~~~~~ -\-0"\'ê..~ c..o..~S ~\"C)r-m ~pct\ , '--\ \Y"\.C-'0~""'~ ~~~ ~œpcß\èð C-o.s.\",~ Da~~~çii( Plug Integrity D BOP Test D BY ORDER OF COMMISSIONER THE COMMISSION INSTRUCTIONS ON REVERSE~·""', r, '..... t 1""\ . ,I /, I ,I' " J L]: i ConocoPhillips Alaska, Inc. RECEIVEr') AUG 11 2005 Kuparuk WelllD-132 (PTD 1981210) Alaska Oil & Gas CQn~., COIT\fi'!""t"'"'I Anchoi3~'~t: SUNDRY NOTICE 10-403 APPROVAL REQUEST 08/01/05 This application for Sundry approval for Kuparuk welllD-132 is for the repair ofa surface casing leak. The well is completed with a 5-1/2" x 3-1/2" tapered casing and is a produced water injector, completed in July 1998. On July 12, 2005, water was found leaking from the conductor top. The AOGCC was notified of the problem on July 12, 2005. The well was immediately plugged until diagnostics could be performed. This incident was reported as a spill to ADEC and the gravel was excavated from around the wellhead to clean the affected area. On 07/15/05 diagnostics were performed to locate the leak. Nitrogen was pumped down the IA to purge fluids from the conductor and the leak appears to be at 56" below the IA valve. At this shallow depth, excavation of gravel around the wellhead will be possible to fix the surface casIng. With approval, repair of the surface casing will require the following general steps: 1. Notify AOGCC Field Inspector of repair operation so they may witness the event. 2. Safe-out the well with plugs and load the tubing and IA with seawater and diesel freeze protection cap. 3. Remove additional gravel around wellhead if necessary. 4. Install nitrogen purge equipment for the OA and conductor so that hot work may be conducted in a safe manner. 5. Cut away the conductor casing and remove cement around surface casing for inspection. Approximately the top 6-feet of conductor will be removed to provide access to the surface casIng. 6. CP AI Mechanical Engineers will determine appropriate patch and/or repair to return the casing to operational integrity. 7. QA/QC the repair and MIT -OA for a final integrity check. 8. Install anti-corrosion coating to repaired area of surface casing. 9. Replace the conductor and fill the void with cement to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. File 10-404 with the AOGCC post surface casing repair. /...~ ;Ì i\ NSK Problem Well Supervisor 08/01/05 . ConocoPhillips AI:::, Inc. API: 500292289500 U. R:~~8~~¡ ::;9 brine :.,..,..,.,'.,..:'.¡r::::... C~:~~~ a.äfr~~~ } ~~~OO 1 :,\ Description // CONDUCTOR <t PRODUCTION :)~ PRODUCTION <t Tubing String~ TUBING \{: ;~~~ I T gP PerforaUons.·Sul11mary Interval TVD 5122 - 5154 3562 - 3591 5188 - 5224 3623 - 3657 5238 - 5244 3670 - 3676 5284-5290 3714-3719 5300 - 5320 3729 - 3748 5326 - 5332 3753 - 3759 5352-5364 3778-3789 5378 - 5396 3802 - 3819 ,Gas Lift MaridrelšNalves St MD TVD Man Man Type V Mfr Mfr 1 4949 3403 CAMCO KBG CAMCO Other (plugs, equip. ;etc~r;;. :JEWELRY Depth TVD Type 5007 3455 NIP 5007 3455 PLUG 5044 3489 SBE 5646 4055 PLUG Gas Lift mdrellDummy Valve 1 (4949-4950, OD:4.725) TUBING (0-5056, OD:3,500, ID:2.992) :>RODUCTlON (0-5056, OD:5.500, Wt:15.00) NIP (5007-5008, OD:4,550) PLUG (5007-5008, OD:2,812) SBE (5044-5045, OD:5,OOO) :>RODUCTION (5056-5790, OD:3,500, Wt:9,30) Peri (5122-5154) Peri (5188-5224) Peri (5238-5244) Peri (5284-5290) Peri (5300-5320) PLUG (5646-5647, OD:3,500) II,:::;::~:;:;,,: .. ......... .. ... ...... .... ...... . ...... ....... ........ ...... . ...... ..... .... ..... ... ....... ... ::"':':':':'~:::::::::" >: ,. .. '. ~:.;,:.:,:,:.:,:.:.:,:.;.:.:.:!:.;,:.:.:.:,~:,:::,:.:,:.:.: ~::::::l::::W(:::::l:::::St:::· :>::::::::::::::;:::::::::::::::::::;::::::::x:::::::::: ' "'.', """"'1';':'::"" .. .. æ i RECEiV[~'[) K~~G 11 2005 1D-132 Well Type: INJ ,Alaska Oil &. G}~ ~%'ts~~:~~§(a)"~':"':: Orig 7/30/1998 AM&:~: 18 deg @ 5802 Completion: Last W/O: Ref Log Date: TD: 5802 ftKB Max Hole Angle: 59 deg @ 1937 Rev Reason: Set PLUG Last Update: 7/25/2005 Size 16,000 5.500 3.500 Top o o 5056 Bottom 121 5056 5790 TVD 121 3500 4191 Wt 62.58 15.00 9.30 Grade H-40 L-80 L-80 Thread WELDED BTCM EUE Zone WSD WSB WSA4 WSA3 WSA3 WSA3 WSA2 WSA2 Status Ft SPF Date Type Comment 32 4 3/20/1999 IPERF 2.5" HCBH 36 4 3/20/1999 IPERF 2.5" HCBH 6 4 3/20/1999 IPERF 2.5" HCBH 6 4 3/20/1999 IPERF 2.5" HCBH 20 4 3/20/1999 IPERF 2.5" HCBH 6 4 3/20/1999 IPERF 2.5" HCBH 12 4 3/20/1999 IPERF 2.5" HCBH 18 4 3/20/1999 IPERF 2.5" HCBH V Type DMY VOD Latch Port TRO 1.0 BK 0.000 0 Description Date Run 7/26/1998 Vlv Cmnt ID 2.812 0.000 3.000 0,000 CAMCO 'DS' NOGO CA-2 BLANKING PLUG set 7/13/2005 BAKER GBH-22 LSA W/12' SEALS Set Baker Bridge Plug for PBTD. ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ., r' " (iCY"" I ,¡-\V Email to:Tom_Maunder@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. West Sak 1 KRU/1 0-132 07/15/05 Arend 1 Sauvageau AES Packer Depth Pretest Initial 15 Min. 30 Min. Well 10-132 Type Inj. N TVD 3,489' Tubing 350 2000 400 350 InteNal 0 P.T.D.1981210 Type test P Test psi 1500 Casing 0 750 75 0 P/F F Notes: Diagnostic MITT with plug in tbg after csg leak to conductor. Water returned from conductor during test. Well 10-132 Type Inj. N TVD 3,489' Tubing 350 1000 350 350 InteNal 0 P.T.D.1981210 Type test P Test psi 1500 Casing 0 1250 0 0 P/F F Notes: Diagnostic MITIA with plug in tbg after csg leak to conductor. Water returned from conductor during test. Well Type Inj. TVD Tubing InteNal P.T.D. Type test T est psi Casing P/F Notes: Well Type Inj. TVD Tubing InteNal P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. TVD Tubing InteNal P.T.D. Type test T est psi Casing P/F Notes: Test Details: SCANNED .JUL 2, 2 2005 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 T = Test during Workover 0= Other (describe in notes) MIT Report Form Revised: 06/19/02 2005-0715_MIT_KRU_1D-132_MITT.xls MEMORANDUM TO: THRU: FROM: Chair P.I. Supervisor John H. Spaulding Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. 1-D 114, 122, 128, 132 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I 1D-114 [Type,nj.I S I T.V.O. l a5~2 I Tubingl ~00 I ~00 I ~00 I ~00 P.T.D.I 1981590 Type testI p I Testpsil 883 I Casingl 360 I 26201 26001 26001 P/F I 13 Notes: WellI 1D-122 I Tvpelnj. I S I T.V.D. 13530 I Tubing I 1150 11150 [ 1150 11150 I,nterva, I 4 P.T.D.I 1981490 TypetestI P ITestpsil 883 I Casingl POS. I 2500 I 24901 2490 I P/F I P Notes: WellI ID-128 I Typelnj. I S I,.v.D. I Tubingl I I I ooI lntervall 4 P.T.D.I 1981330 Type testI I Testpsil 863 I Casingl 80 I 25001 2490 I 2490 I P/F I ~P Notes: WellI 1D-132 I Typelnj. I S I*.v.~. 13489 I Tubing I 1350 11350 11350 11350 I lntervall 4 P.T.D.I 1981210 ITypetestl ITestpsil 872 I Casingl POS. I 2500 I 2490 I 2490 I P/FI _P Notes: WellI P.T.D.I Notes: 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 Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details As noted in the above report all wells passed. Well houses were found to be clean and orderly. M.I.T.'s performed: 4 Attachments: Number of Failures' 0 Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. 2003-0620_M IT_KRU_ 1 D- 132_js .xls 7/9/2003 8CANNEF~' Jt. JL' :~' 3 ~ 20D3 Well Compliance Report File on Left side of folder 198-121-0 KUPARUK RIV U WSAK 1D-132 50- 029-22895-00 PHILLIPS ALASKAINC MD 05802 J TVD 04_203 - Completion Date: ~98 Completed Status: 1W1NJ Current: Microfilm Roll / - Roll 2 / Name D 8768 L DGR/EWR4-MD L DGR/EWR4-TVD Interval Sent Received T/C/D SPERRY MPT/GR/EWR4 OH 10/7/98 10/7/98 ~-3' 121-5802 ~/T~/~' ~/~ OH 10/7'98 10/8'98 t.4'5-3 121-4203 ~ OH 10/7/98 10/8/98 L INJP F~.UNAL 4990-5450 ~1/12/00' CH 5 L SCMT ~ 5000-5683 ~. CH 5 L SCMT %~i~AL BL(C) 5000-5683 44'b639~ 6111~/! ~ / 'ql CH 5 n WFL/RST i,~L 4900-5646 Al/i~['~t] CH 5 R SRVY RPT t~'~I~ERRY 0-5802. OH Daily Well Ops~,~/~{00 Was the well cored? yes ~ Comments: 2/2/0O 2/15/00 2/18/99 2/24/99 6/8/99 6/16/99 5/6/99 5/19/99 8/19/98 8/26/98 Are Dry Ditch Samples Required? yes ~..~And Received-?--yes~o Analysis Description ~y ----~8~,.Set-.# Tuesday, August 01, 2000 Page I of 1 2~2~OO Schlumberger NO. 121149 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1A-22 PRODUCTION PROFILE 000111 I 1 '2M-02 C~ ! CL... INJECTION PROFILE 000113 I 1 12M-03 ~ INJECTION PROFILE 000113 I 1 3G-26 PRODUCTION PROFILE 000116 I 1 3G-26 WATER FLOW LOG 000116 I 1 1 D-132 INJECTION PROFILE 000112 I 1 ~-r'~lC~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 6/8/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 AI'I'N: Sherrie NO. 12633 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool/West Sak Well Job # Log Description Date Color Print 2T-210 99240 :CBL W/PSP/SCMT 990523 1 2N-320 99241 SCMT 990303 1 2L-323 b,~ L_. 99239 CBT W/PSP/SCMT 990221 1 1C-18 99243 CBT W/PSP/SCMT 990402 1 1 D- 132 L~. ~ ,-.-- 99248 SCMT 990216 1 ID-125 99249 CBT W/PSP/SCMT 990220 1 1D-114 ~,.~ i c ..... 99246 CBT W/PSP/SCMT 990421 1 I D- 128 99247 SCMT 990215 1 1D- 122 ~ ~ ¢ .... 99244 CBT W/PSP/SCMT 990226 1 1 D- 111 bc~ c 99245 CBT W/PSP/SCMT 990415 1 1 C- 14 ~,c f ¢ 99242 SCMT 990122 1 SIGNE ~.. ~.~OL_,L~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 5/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie NO. 12557 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia Color CD-R Print 1D-10 ~ ~:;:~,"~" 98193 REPROCESSEDDSl 980410 1 1 1 1D-111 CBL 990415 1 1 1D-114 CBL 990421 I ] 1D-132 WFL W/RST 990416 1 1 2B-02 PROD. PROFILE 990423 1 1 3N-18 PROD. PROFILE 990425 I ] 3G-25X 99200 USIT 980107 1 3H-11 99201 USIT 990428 I SiGNED.Ok~~""~ RE(,.,i:IVEi Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: j~/~/ 'i ~! 'i999 Alaska 0ii & Gas Oo[~s. Commi8sio~'i Schlumberger 3940 Arctic Boulevard Anchorage, Alaska 99503 907-273-1700 (phone) 907-561-8317 (fax) 20-April- 1999 State of Alaska Alaska Oil&Gas Conservation Commission Attn: Blair Wondzell Re: ARCO 1D-132 well Dear Sir: On 16-Apr-99 Schlumberger ran a Water Flow Log (WFL) on well 1D-132 for ARCO Alaska Inc. Seven station measurements were made looking for any evidence of water upflow behind casing above the top set of perforations. All measurements were made while injecting into the well. Based on the WFL data, there is no indication of migration above the top perforation at 5122' at this point in time. Sincerely v J/d!k~Kas0/gkY tr ['--- /Sch/umb~ger Wireli~~ng ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 . j' March 29, 1999 Mr. Robert Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-132 (Permit No. 98-121) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on West Sak 1D-132. If there are any questions, please call 265-6890. Sincerely, T. W. Mc Kay Senior Drilling Engineer Kuparuk Development TWM/skad . STATE OF ALASKA -' . ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL E~ GAS ~1 SUSPENDED [~ ABANDONED~ SERVICE [] INJECTOR 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-121 3 Address 8 APl Number :,':~' ' ~ ;': _: ~ , ::' -; r' ' P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22895 ". ?;i;": 4 Location of well at surface 9 Unit or Lease Name 436'FNL, 600'FEL, Seo. 23, T11N, R10E, UM ;, ,;..,.i;':::..:~'.-. · ' ~I~~ KuparukRiverUnit ~'~ -~-' ...."r'~'-'~'""" r'"~'~- ' ~' ' ~i 10 Well Number At Total Depth 11 Field and Pool 1455' FSL, 1780' FEL, Sec. 23, T11 N, R10E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. West Sak Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date22.Jul.98Spudded 13 25-Jul-98Date T.D. Reached 14 30-Jul-98Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 5802' MD & 4203' TVD 5694' MD & 4100' TVD YES ~ NO ~ NA feet MD 1516' APPROX 22 Type Electric or Other Logs Run G~Res, CCL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD I CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT ~ECORD 16" 62.58¢ H-40 SURF. 121' 24" 235 sx AS 11 5.5"x 15.5¢ L-80 SURF. 5056' 8.5" 1. 180 sx ASlII LW 3.5" 9.3¢ L-80 5056' 5790' 8.5" 2.430 sxClass G, 271 sx AS I 24 Pedorations open to Production (MD+TVD of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 5122'-5~ 54' MD 3~2'-3591' WD 4spf 3.5" 5054' N/A 5188'-5224' MD 3623'-3657' TVD 4 spf 5238'-5244' MD 3670'-3676' TVD 4 spf :26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 5284'-5290' MD 3714'-3719' TVD 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5300'-5320' MD 3729'-3748' TVD 4 spf N/A N/A 532b'-5332' MD 3753'-3759' WD 4spf 5352'-5364' MD 3778'-3789' TVD 4 spf 5378'-5396' MD 3802'-3819' TVD 4 spf 27 PRODUCTION TEST Date First Production Method of Operati:;::~wing, gas lift, etc.) 0 ~ ~ ~ ~ ~ A L Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL ~TIO TEST PERIOI' Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. 'J 30. '-- GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top West Sak Sand 5119' 3559' Base West Sak Sand 5582' 3994' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge.signed ~"'"~~ ~J' ~ TitlepreparedShallOWby Name/NumberSands Team LeadersharonDATEAiisup. Drake/263_4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- 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: 12/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-132 WELL ID: AK9661 TYPE: AFC: AK9661 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:07/22/98 START COMP: RIG:RIG ~ 245 WI: 0% SECURITY:0 API NUMBER: 50-029-22895-00 BLOCK: FINAL:07/29/98 07/22/98 (D1) MW: 9.5 VISC: 234 PV/YP: 31/58 APIWL: 6.3 TD: 470'(470) DRILLING @ 900' SUPV:CUNNINGHAM/MORRISON Move rig 75' from 1D-134 to 1D-132. Accept rig @ 0800 hrs. NU diverter and test. Spud @ 1630 hrs. drilled from 121' to 470' 07/23/98 (D2) MW: 9.5 VISC: 210 PV/YP: 46/57 TD: 2732' (2262) Drilling @ 3930' SUPV:CUNNINGHAM/MORRISON Drilling 8.5" hole from 470' to 2732' APIWL: 6.0 07/24/98 (D3) MW: 9.5 VISC: 215 PV/YP: 41/54 TD: 4930'(2198) DRILLING AT 5100' SUPV:CUNNINGHAM/MORRISON Drilling 8.5" hole from 2732' to 4930' APIWL: 6.7 07/25/98 (D4) MW: 9.6 rISC: 225 PV/YP: 49/51 APIWL: 4.2 TD: 5802' (872) RUNNING 5.5X3.5 CASING SUPV:CUNNINGHAM/MORRISON Ream to 2757'. Drilling 8.5" hole form 4930' to 5802' 07/26/98 (D5) MW: 9.7 VISC: 75 PV/YP: 32/25 APIWL: 0.0 TD: 5802'( 0) WELD UP AND RUN 1" PIPE IN 8.5 X 5.5 ANNULAS, RAN TO 715' PL SUPV:CUNNINGHAM/MORRISON Run 3.5x5.5 tapered casing string. Work thru bridges. Pump 1st stage cement. No returns at surface. 07/27/98 (D6) TD: 0'( SUPV: 0~ MW: 9.7 VISC: 83 PV/YP: 32/26 Drill out stage tool APIWL: 4.6 Flush out diverter system. Run 1" line for top job. Pump top job. 07/28/98 (D7) MW: 9.7 riSC: 82 PV/YP: 31/28 APIWL: 4.7 TD: 5802'(5802) RUNNING COMPLETION. ( NOTE:STARTED HAULING INJ. MUD TO 1R-1 SUPV:CUNNINGHAM/PENROSE Drill out cement from 2429' to 2501'. Test BOPE 300/2250. Drill out stage tool @ 2501', wash to 2534'. Run 2-7/8" DP. Try to circ out thick mud. Lost 12 bbl. CBU very thick cement contaminated mud. Date: 12/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 07/29/98 (D8) MW: 9.3 VISC: 62 PV/YP: 20/17 APIWL: 7.6 TD: 5802' ( 0) STUNG IN SEAL ASSY & TSTD BACKSIDE TO 3000% - OK. 3-1/2" CS SUPV:CUNNINGHAM/PENROSE Run 3.5" completion to 5054'. Attempt to sting into SBR w/seal assy. Try isolation, circulation and reverse circulation. No success. CBU. Recover small amount of thick, cement contaminated mud. RIH w/mill on 3.5" tbg. Tag at 5054' Mill and work junk from 5054' to 5067'. Recover pieces of rubber, aluminum and cement. 07/30/98 (D9) MW: 8.7 riSC: 0 PV/YP: 0/ 0 TD: 5802'( 0) RIG RELEASED SUPV:CUNNINGHAM/PENROSE Rig released @ 1000 hrs. 7/30/98. APIWL: 0.0 ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~' K1(1D-132(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-132 PERFORATIONS-E-LI N E 0102991958.3 DATE DAILY WORK UNIT NUMBER 03/20/99 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 NOI NO SWS-ELMORE JOHNS FIELD AFC# CC# Signed ESTIMATE AK9661 18WSTF7SC Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 200 PSI 200 PSI 200 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED A-2 , A-3 , A-4 , B SANDS[Perf] TIME LOG ENTRY 07:00 MIRU E-LINE, PRESSURE TEST TO 3000 PSI. HELD JOB SITE SAFETY MEETING. 08:15 RIH WITH CCL AND 2.5" HC GUN, 4 SPF. TIE-IN AND PERFORATED 5378' TO 5396'. POOH. 09:30 RIH, TIE-IN AND PERFORATED 4 SPF, 5352' TO 5364'. POOH 10:20 RIH TIE-IN AND PERFORATED W/4SPF 5326' TO 5332'. POOH 11:40 RIH TIE-IN AND PERFORATEDW/4 SPF 5300' TO 5320'. POOH 12:45 RIH TIE-IN AND PERFORATED W/4 SPF 5284' TO 5290'. POOH. 13:30 RIH TIE-IN AND PERFORATED W/4 SPF 5238' TO 5244'. POOH. 15:00 RIH TIE-IN AND PERFORTED W/4 SPF 5204' TO 5224'. POOH. 16:00 RIH TIE-IN AND PERFORATED W/4 SPF 5188' TO 5204'. POOH. 17:20 RDFN. ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~, K1(1D-132(W4-6)) WELL JOB SCOPE JOB NUMBER 1 D-132 P E R FO RATIO N S-E-LI N E 0102991958.3 DATE DAILY WORK UNIT NUMBER 03/21/99 PERFORATE DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 6 NOI NO SWS-ELMORE JOH NS FIELD AFC# CC# Signed ESTIMATE AK9661 25WS1 D6DL Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 400 PSI 0 PSI 200 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATED "D" SANDS 5122' TO 5154'[Perf] TIME 07:00 08:30 08:45 LOG ENTRY MIRU SCHLUMBERGER E-LINE. HELD JOB SITE SAFETY MEbl lNG. PRESSURE TEST LUBRICATOR TO 3000 PSI. RIH W/20' HC PERF GUN , 4 SPF , TIE-IN AND SHOOT PERFS 5134 'TO 5154'. POOH. 09:45 11:00 PERFS COMPLETED ON 1D-132, RDMO. RIH W/12' HC PERF GUN , 4 SPF AND TIE-IN AND SHOOT PERFS 5122' TO 5134'. POOH " SURVEY CALCULATION AND FIELD WORKSHEET i ~ Job No. 0450-99485 Sidetrack No. Page 1 of ___2__. Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. 1 D-PAD/1D#132/K4 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. I~ WELL DATA Target TVD (FT) Target Coord. N/S ........... Slot Coord. N/S ___ -436.00 Grid Correction .... _0.0_0~0__ ....... Depths Measured From: RKB ~ MSL~] SS~ Target Description ................................... Target Coord. E/W Slot Coord. E/W -600.00 Magn. Declination 27.440 Calculation Method MINIMUM CURVATURE Target Direction ............ !D.D) ...... Build\Walk\DE per: lOOft!~ 30m;-'I lOm!~! Vert. Sec. Azim.. !.~9.9_=28 ........... Magn. to Map Corr. _ 27..z~40 Map North to: O_T_HER SURVEY DATA ' ~ Total Coordinate i Build Rate ! Walk Rate ! i Survey I Survey Incl. [ Hole :: Course '~ - ..... -E +- 'v~-- ','B..u--ild .... i ( ) .=Vertical Date ', Tool '. Type i Depth I Angle ! Direction ; Length TVD ! Section ..... ~qi~+ii () i-)-7 (i-- DL ,+, Right (+) Comment .............. i (FT) i IDD) i (DD) i, (FT) ....... (["~- .......... i ...................... ~FT) i (FT) Per 100 FT)I urop I-) i Left (-) i ;~ .,I 0.00 I, 0.00i~ 0.001 0.00 :~ 0.00 °.°° ~i 0.00 ~ , i~TiE IN POINT .......... ~ ............... ~. ......... _~ . , 22-JUL-98 ' MWD / 121.00 0.00" 0.00 121.00 121.00 0.00 0.00 ! 0.00 0.00' 0.00 63/4"MACH1C-AKO-1.4deg. ...................... 22-JUL-98 ri ........................ MWD~ 157.00 0.50 214.00 36.00 157.00 I ........ 0.15 ...... -0.13i/ ......................... -0.09 1.39 1.39 ~ ........................................... ~ S/S .............................................. GYRO --nn- ~-~ ~-~ :-0.-~ j ~11~' 2.18 ......... ~.. O~- 22-JUL-98 MWD 218.00 1.75 242.00 61.vv ,_,, .,,,.' 1.09 22-JUL-98 MWD 274.00 4.00 237.00 56.00 273.91 3.27 -2.25 -3.45 4.04 4.02 ,, 22-JUL-98 MWD 337.00 6.50 222.00 63.00 336.65 8.30 -6.10 -7.68 4.49 3.97 -23.81 , 22-JU L-98 MWD 392.00 8.50 205.00 55.00 391.18 15.21 -12.10 -11.48 5.39 3.64 -30.91 , 23-JUL-98 MWD 466.86 14.59 216.81 74.86 464.50 29.72 -24.68 -19.48 8.69 8.14 15.78 23-J U L-98 MWD 562.60 19.08 208.38 95.74 556.13 56.69 -48.11 -34.15 5.33 4.69 -8.81 23-JUL-98 MWD 651.47 24.01 208.45 88.87 638.76 88.90 -76.81 -49.68 5.55 5.55 0.08 23-JUL-98 MWD 743.83 26.04 207.21 92.36 722.45 127.54 -111.36 -67.90 2.27 2.20 -1.34 23-J U L-98 MWD 834.89 28.14 202.64 91.06 803.52 168.78 -148.97 -85.31 3.25 2.31 -5.02 23-JUL-98 MWD 925.70 34.13 197.33 90.81 881.23 215.67 -193.10 -101.16 7.25 6.60 -5.85 23-JUL-98 MWD 1016.28 39.14 197.87 90.58 953.89 269.68 -244.60 -117.51 5,54 5.53 0.60 23-J U L-98 MWD 1107.91 42.27 198.27 91.63 1023.35 329.42 -301.40 -136.05 3.43 3.42 0.44 23-J U L-98 MWD 1197.99 44.32 199.73 90.08 1088.91 391.18 -359.79 -156.18 2.53 2.28 1.62 23-JUL-98 MWD 1288.41 46.19 198.75 90.42 1152.56 455.40 -420.43 -177.33 2.21 2.07 -1.08 23-JU L-98 MWD 1379.61 50.63 199.34 91.20 1213.08 523.59 -484.88 -199.59 4.89 4.87 0.65 23-J UL-98 MWD 1470,90 56.49 199.53 91,29 1267.28 597.00 -554.11 -224.02 6.42 6.42 0.21 23-J U L-98 MWD 1651.64 57.14 199.39 180,74 1366.21 748.26 -696.73 -274.41 0.37 0.36 -0.08 .23-JUL-98 MWD 1936.59 58.76 198.04 284.95 1517.42 989.75 -925.47 -351.88 0.70 0.57 -0.47 23-JUL-98 MWD 2221.10 55.97 197.51 284.51 ' 1670.84 1229.23 -1153.59 -425.03 0.99 -0.98 -0.19 23-JUL-98 MWD 2503.94 54.24 196.13 282.84 1832.64 1460.99 -1375.63 -492.18 0.73 -0.61 -0.49 23-JU L-98 MWD 2675.17 56.20 200.34 171.23 1930.34 1601.55 -1509.13 -536.23 2.32 1.14 2.46 ~ SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-99485 Sidetrack No. Page 2 of 2 Company ARCO ALASKA, lNG. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT Well Name & No. 1D-PAD/1 D#132/K4 Survey Section Name Definitive Survey BHI Rep. ROBBY BARNARD. IN"~I'=~ WELL DATA TargetTVD (F-r) Target Coord. N/S ..................... Slot Coord. N/S -436.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description ......................... Target Coord. E/W .................... Slot Coord. E/W ........ 2_6_0_0.:_00_ ..... Magn. Declination _ _.~_7_..~.4_0_ .......... Calculation Method .M_.!.NIM__U_M__.C_.U_R_.V__A..T._U~E_' Target Direction .................... (..DD~) ...... Buitd\Walk\DL per: l OOft~ 30m[ ! l Om['~ Vert. Sec. Azim.. .... 1.99...2.8 Magn. to Map Corr. . ._ 27..440 ..... Map North to: O_T.~E._R. ........................... SURVEY DATA ........ , ........... ~ ................. ~ ............................. ? ........... ~ ........................................ ~ ............. i ............ ~ ...................................... ~ Surve i ~ ! I I Total Coordinate ! Y l Survey i Incl. : Hole , Course ; Vertical ................... ~ ................ Date Tool .... I -,- ~, uepm i Ange ! Direction ; Length TVD Section N(+)/S(-) i E(+)/W(-) DL [ B,,u,ld (.+.) I R!gh,!!,+) ! Comment i /ype ! (FT) (DD) i (DD) I (FT) (FT) ! (F'F) ', (FT) (Per 100 FT). Drop (-) .................... 1 ............ ~- ........................................................................... 24-JUL-98 I, MWDi 2878.52154.65 20i.65'i"--2~;~i';~5 ....... ~34-~17~t-! i768.90 ....... --~-~65'i45; ...... -596-.20 ...... 073-'i ..... ~0.7'6 Oi6~-:,63-~"uAC~l-~-~,K~-l.4degl -'~-~--~I'L--~-~~ MWD 33---'-52.28 '5--7.3; '"-'-~-~.~T-' ~--~ .... -~.~)~.7-~-- ~-~3~4~ ;~3-6h~) 'j ...... :~-;~-i-i-;~7- ..... ~)'i-6-~ ............... ;';~6-- ............ :~)~';;- ........................................................................ 24-J U L-98 MWD 3638.59 55.60 196.54 286.31 2465.92 2401.99 -2263.75 -803.19 0.83 -0.60 -0.67 24-JUL-98 MWD 3924.35 55.67 200.17 285.76 2627.26 2637.78 -2487.57 -877.45 1.05 0.02 1.27 24-J U L-98 MWD 4019.22 52.57 200.85 94.87 2682.86 2714.62 -2559.56 -904.37 3.32 -3.27 0.72 24-JUL-98 MWD 4114.42 49.10 200.21 95.20 2742.97 2788.40 -2628.67 -930.26 3.68 -3.64 -0.67 _ -- 24-JUL-98 MWD 4209.30 44.01 198.96 94.88 2808.20 2857.26 -2693.54 -953.37 5.45 -5,36 -1.32 24-J U L-98 MWD 4303.95 43.22 197.97 94.65 2876.72 2922.54 -2755.46 -974.05 1,10 -0.83 -1.05 _. -- 24-JUL-96 MWD 4397.63 42.63 198.09 93.68 2945.32 2986,33 -2816,13 -993.80 0.64 -0,63 O. 13 24-JUL-98 MWD 4493.13 39.52 198.92 95.50. 3017.30 3049.06 -2875.63 -1013,70 3.31 -3.26 0.87 24-J U L-98 MWD 4586.81 35.55 199.74 93.68 3091.57 3106.12 -2929.48 -1032.57 4.27 -4.24 0.88 24-JUL-98 MWD 4685.46 32.20 199.93' 98.65 3173.47 3161.10 -2981.20 -1051.22 3.40 . I -3,40 O. 19 24-JUL-98 MWD 4776.87 30.48 198.42 91.41 3251.54 3208.64 -3026.09 -1066.85 2,07 -1.88 -1.65 -- 24-J U L-98 MWD 4872.25 28.39 199.17 95,38 3334.60 3255.50 -3070,47 -1081.94 2,23 -2,19 0.79 25-JUL-98 MWD 4969.21 25.71 197.85 96.96 3420.95 3299.59 -3112,27 -1095.96 2,83 -2.76 -'1.36 25-J U L-98 MWD 5063,96 22.22 195.13 94,75 3507,52 3338.01 -3149.14 -1106.94 3.86 -3.68 -2.87 , 25-JUL-98 MWD 51'59,88 20.11 196.83 95.92 3596.97 3372.58 -3182.43 -1116.45 2.29 -2.20 1.77 25-JUL-98 MWD 5442,88 19.67 196,91 283.00 3863.08 3468.78 -3274,57 -1144.39 0.'16 -0,16 0.03 25-JUL-98 MWD 5744.97 18.39 195.45 302.09 4148.66 3567.13 -3369.15 -1171.87 0.45 -0.42 -0.48 25-JULY98 MWD 5802.00 18.39 195,45 57.03 4202,78 3585,08 -3386.49 -1176.67 0,00 0.00 0.00 PROJ*BHC=3585.09'@199.16deg, Kuparuk Unit Kuparuk 1D 1D-132 SURVEY REPORT 17 August, 1998 ORIGINAL Your Ref: API-500292289500 Last Survey Date 25-July-98 Job# AKMMS0299 KBE- 111.9' DRILLING ~=;ERVI ~-ES RECEIVED - AUG 2 6 Ala~a Oil & Gas Corm. And~orm:je Survey Ref: svy50 Sperry-Sun Drilling Services Survey Report for '1D-132 Your Ref: AP1-500292289500 Kuparuk Unit Measured Sub-Sea Ve~ical Depth Incl. Azim. Depth Depth (~) (fi) (fi) 0.00 0.000 0.000 -111.90 0.00 121.00 0.000 0.000 9.10 121.00 157.00 0.500 214.000 45.10 157.00 218.00 1.750 242.000 106.09 217.99 274.00 4.000 237.000 162.01 273.91 337.00 6.500 222.000 224.75 336.65 392.00 8.500 205.000 279.28 391.18 466.86 14.590 216.810 352.60 464.50 562.60 19.080 208.380 444.23 556.13 651.47 24.010 208.450 526.86 638.76 743.83 26.040 207.210 610.55 722.45 834.89 28.140 202.640 691.62 803.52 925.70 34.130 197.330 769.33 881.23 1016.28 39.140 197.870 841.99 953.89 1107.91 42.270 198.270 911.45 1023.35 1197.99 44.320 199.730 977.01 1088.91 1288.41 46.190 198.750 1040.66 1152.56 1379.61 50.630 199.340 1101.18 1213.08 1470.90 56.490 199.530 1155.38 1267.28 1651.64 57.140 199.390 1254.31 1366.21 1936.59 58.760 198.040 1405.52 1517.42 2221.10 55.970 197.510 1558.94 1670.84 2503.94 54.240 196.130 1720.74 1832.64 2675.17 56.200 200.340 1818.44 1930.34 2878.52 64.650 201.650 1933.84 2045.74 3070.19 56.600 200.330 2042.06 2153.96 3352.28 57.330 198.470 2195.85 2307.75 3638.59 55.600 196.540 2354.02 2465.92 3924.35 55.670 200.170 2515.36 2627.26 4019.22 52.570 200.850 2570.96 2682.86 Local Coordinates Nothings (fi) 0.00 N 0.00 N 0.13S 0.79 S 2.25 S 6.10S 12.10 S 24.68 S 48.11 $ 76.81S 111.36 S 148.96 S 193.10 S 244.60 S 301.40 S 359.79 S 420.43 S 464.88 S 554.11S 696.73 S 925.47 S 1153.59 S 1375.63 S 1509.13 S 1665.45 S 1813.14 S 2036.19 S 2263.75 S 2487.57 S 2559.56 S Eastings (ft) 0.00 E 0.00 E 0.09 W 1.06W 3.45W 7.68W 11.48W 19.48W 34.15W 49.68W 67.90W 85.31W 101.16W 117.51W 136.05W 156.18W 177.33W 199.59W 224.02W 274.41W 351.88W 425.03W 492.18W 536.23W 596.20W 652.84W 731.37W 803.19W 877.45W 904.37W Global Coordinates Dogleg Ve~ical Nothings Eastings Rate Section (fi) (fi) (°/100fi) (fi) 5959229.23 N 560490.64 E 0.00 5959229.23 N 560490.64E 0.000 0.00 5959229.10 N 560490.55 E 1.389 0.15 5959228.43 N 560489.59 E 2.179 1.09 5959226.95 N 560487.21E 4.039 3.27 5959223.07 N 560483.01 E 4.494 8.30 5959217.04 N 560479.25 E 5.394 15.21 5959204.40 N 560471.36 E 8.685 29.72 5959180.84 N 560456.88 E 5.327 56.69 5959152.02 N 560441.58 E 5.548 88.90 5959117.32 N 560423.64 E 2.270 127.54 5959079.58 N 560406.53 E 3.245 168.78 5959035.33 N 560391.04 E 7.250 215.67 5958983.70 N 560375.10 E 5.542 269.68 5958926.75 N 560357.02 E 3.428 329.42 5958868.19 N 560337.37 E 2.533 391.18 5958807.39 N 560316.70 E 2.207 455.40 5958742.76 N 560294.96 E 4.892 523.59 5958673.34N 560271.09 E 6.421 597.00 5958530.32 N 560221.84 E 0.365 748.26 5958300.96 N 560146.22 E 0.696 989.75 5958072.25 N 560074.91E 0.993 1229.23 5957849.68 N 560009.55 E 0.731 1460.99 5957715.83 N 559966.57 E 2.321 1601.55 5957559.04N 559907.87 E 0.929 1768.90 5957410.89 N 559852.41E 1.165 1927.01 5957187.22 N 559775.68 E 0.610 2163.48 5956959.09 N 559705.70 E 0.825 2401.99 5956734.68 N 559633.24 E 1.049 2637.78 5956662.47 N 559606.90 E 3.319 2714.62 Comment Kuparuk 1 D Continued... 17 August, 1998 - 9:12 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-132 Your Ref: AP1.500292289500 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4114.42 49.100 200.210 2631.07 2742.97 2628.67 S 930.26W 5956593.16 N 559581.57 E 4209.30 44.010 198.960 2696.30 2808.20 2693.54S 953.37W 5956528.11N 559558.98 E 4303.95 43.220 197.970 2764.82 2876.72 2755.46 S 974.06W 5956466.02 N 559538.80 E 4397.63 42.630 198.090 2833.42 2945.32 2816.13 S 993.80W 5956405.19 N 559519.54 E 4493.13 39.520 198.920 2905.40 3017.30 2875.63 S 1013.70W 5956345.54 N ' 559500.12 E 4586.81 35.550 199.740 2979.67 3091.57 2929.48 S 1032.57W 5956291.53 N 559481.68 E 4685.46 32.200 199.930 3061.57 3173.47 2981.20 S 1051.22W 5956239.67 N 559463.45 E 4776.87 30.480 198.420 3139.64 3251.54 3026.09 S 1066.85W 5956194.65 N 559448.18 E 4872.25 28.390 199.170 3222.70 3334.60 3070.47 S 1081.94W 5956150.15 N 559433.45 E 4969.21 25.710 197.850 3309.05 3420.95 3112.27 S 1095.96W 5956108.24 N 559419.77 E 5063.96 22.220 195.130 3395.62 3507.52 3149.14 S 1106.94W 5956071.29 N 559409.08 E 5159.88 20.110 196.830 3485.07 3596.97 3182.43 S 1116.45W 5956037.92 N 559399.84 E 5442.88 19.670 196.910 3751.18 3863.08 3274.57 S 1144.39W 5955945.56 N 559372.65 E 5744.97 18.390 195.450 4036.76 4148.66 3369.15 S 1171.87W 5955850.76 N 559345.92 E 5802.00 18.390 195.450 4090.88 4202.78 3386.49 S 1176.67W 5955833.38 N 559341.27 E All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 199.280° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5802.00ft., The Bottom Hole Displacement is 3585.09ft., in the Direction of 199.160° (True). Dogleg Rate (°/100ft) 3.682 5.449 1,103 0.636 3.306 4.271 3.398 2.068 2,225 2.832 3,863 2.291 0.156 0.452 0.00o Vertical Section (fi) 2788.40 2857.26 2922.54 2986.33 3049.06 3106.12 3161.10 3208.64 3255.50 3299.59 3338.02 3372.58 3468.78 3567.13 3585.08 Comment Projected Survey Kuparuk 1D Continued... 17 August, 1998 - 9:12 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-132 Your Ref: API-500292289500 Kuparuk Unit Kuparuk 1 D Comments Measured Depth (ft) 0.00 5802.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 0,00 0.00 N 0.00 E 4202.78 3386.49 S 1176.67 W Comment Tie-in Survey Projected Survey 17 August, 1998 - 9:12 - 4 - DrillQuest 2/18/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATrN: Sherrie NO. 12347 Company Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Well Job # Log Description Date Blueline Sepia Print 1D-128 SCMT 990215 1 1 1D-132 SCMT 990216 I 1 1L-09 PRODUCTION PROFILE W/DEFT 990207 1 1 2H-07 PRODUCTION PROFILE 990129 I 1 2T-10 Luc_. INJECTION PROFILE 990212 1 1 3N-11 U,,.~ c... INJECTION PROFILE 990211 1 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: OFll I--I--I ~ G S Ei Ft L/I r' ~::: S WELL LOG TRANSMITr,~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs October 7, 1998 1D-132, AK-MM-80299 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, Ct(}, Anchorage, AK 99518 1D-132: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-029-22895-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22895-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 · (907) 273-3500. Fax (907) 273-3535 0 I~11 I_1_ I I~1 (~ WELL LOG TRANSM1Tr~ To; State of Alaska Alaska Oil and Gas Comervation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-132, AK-MM-80299 October 7, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of 2 Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way,/tG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22895-00 OCT 0 7 i93'0 Oii& Gas Cons, r3omm~.io~ Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518. (907) 273-3500 · Fax (907) 273-3535 19-Aug-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 D-132 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 5,802.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) AU(; 2 6 1998 Naska 0it & Gas Cons. O0mmission Anchorage 5631 Silverado Way, Suite G ,, Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. MEMORANDUM State of Alaska TO: David JohnS~. Chairman Alaska Oil and Gas Conservation Commission DATE: July 27, 1998 THRU: Blair Wondzell, ~ FILE NO: P. I. Supervisor 7[¢~t[ ~3 FROM: Larry Wade,/ :~,,,~, SUBJECT: Petroleum Inspector/ .DOC Top Job Parker 245 KRU 1D-132 PTD 98-121 July 27,1998: I traveled to Kuparuk to witness a top job on Parker 245. They had opened their stage tool in the 5.5" casing but couldn't establish any returns. They pumped 45 bbls of 15.7 ppg AS1 thru the stage collar. We ran 805' of linch pipe down the annulus breaking circulation every 150' We then pumped two bbls of water followed by 10 bbls of ARCO flush which was than chased with 130 bbls of 11ppg AS3 light. We got cement returns at 125 bbls but pumped 5 more bbls into the cellar to empty the tub. Calculated annular volumes was 63.8 bbls if it had been a guage 8 ½" hole. The pipe was then pulled from the annulus and the void filled with dry AS 3 cement. SUMMARY: Witnessed a top job on West Sak 1D-132, 10 hours. Attachments: cc; NON-CONFIDENTIAL TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 7, 1998 Thomas W. McKay Shallow Sands Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Rc: Prudhoe Bav Unit 1D-132 ARCO Alaska. Inc. Permit No. 98-121 Sur. Loc. 436'FNL. 600'FEL. Sec. 23. T11N, R10E. UM Btmnhole Loc. 1443'FSL, 1788'FEL. Sec. 23. T11N. RIOE. UM Dear Mr. McKav: Enclosed is the approved application for permit to drill the above referenced well. PLEASE NOTE: Your request for an exception to the requirements of 20 AAC 25.033(e) and 25061(a) is NOT needed. Those requirements apply to exploratory and stratigraphic test wells only. Thc permit to drill docs not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention cquipmcnt (BOPE) must be tested in accordance with 20 AAC 25.035: and thc mechanical integrity (MI) of thc injection wells must bc demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficicnt notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed bcfore drilling below thc surface easing shoe, must be given so that a representative of the Commission may witness thc tests. Notice mas' be given bv nspector on the North Slope pager at 659-3607. David W. Johnston .,:, Chairman '--...,~.~ BY ORDER OF THE COMMISSION dlffEnclosures CC~ Department of Fish & Game. Habitat Section w/o cncl. Department of Environmental Consetwation w/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill lb Type of Well Exploratory E~ StratigraphicTest [~ Development Oil Re-Entry Deepen Service X Development Gas O SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. :~roperty Designation West Sak Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468/' 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 436' FNL, 600' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1602' FSL, 1734' FEL, Sec. 23, T11N, R10E, UM 1D-132 #U-630610 At total depth 9. Approximate spud date Amount 1443' FSL, 1788' FEL, Sec. 23, T11 N, R10E, UM 7/7/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 D-133 5825' MD 1443' @ TD feet 9.4' @ 400' feet 2560 4190' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 250' feet Maximum hole angle 56.53° Maximum surface 1400 psig At total depth 1841 psig (TVD) 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 69' 41' 41' 110' 110' +_200 CF 8.5" 5.5" x 15.5#/ L-80 BTC MOC 5784' 41' 41' 5825' 4190' 635 Sx Arcticset III & 3.5" 9.3# 425 Sx Class G & 60 sx AS I 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~ -:, .... Intermediate Production Liner ,J{-~"'i0 R1GINAL Perforation depth: measured true vertical Aiaska 0it & (_ as C0r s, Oom nissi0 Anchorage X20. Attachments Filing fee X Property plat [] BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC25.050 requirements X ,. Signed21' I hereby certify th~--~~ ~¢~//at the foregoing is true and correct .tO the best of my kno./~~~-"' TitleWledgeShallow Sands Team Leader Date ~/' /~ ( ! Commission Use Only Permit Nurr~er . _ I APl number ~ I Approval date _.,, ~ /7./) I See cover letter for '~ ~ - / ~1 I 50- 0 .,I.. ff ... ,,l.,3_ ~' ~) S'" [ '7 "' '~ '" '¢ '~I other requirements Conditions of approval Samples required [--; Yes [~ No Mud log required [-~ Yes ~ No Hydrogen sulfide measures E~ YeS [~No.,.--.., Directional survey required [~]Yes BI No Required working pressure for BOPE r--~2M ~(,~~ 5M E~] 10M E] 15M Other: Hi'/-I- rigi ., S!gn By David W. Johnston by order of .,..,/ ~ Approved by Commissioner the commission Date / "" 7 Form 10-401 Rev. 7-24-89 Submit in triplicate Drill, Case and Completion Plan for West Sak 1D-132 (K4) Monobore Injector General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 110' RKB. Weld landing ring on conductor. 2. Move in / rig up drilling rig. Install diverter & function test same. 3. Spud and directionally drill 8-1/2" hole to desired target through West Sak interval. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Condition hole for casing, trip out. 5. Run and cement 3-1/2" 9.3# L80 8RD x 5-1/2" 15.5# L80 BTC tapered casing string to surface, displace cement with mud. Perform stage job and top job as required. NOTE: Stage (DV) tool to be installed +/- 200 ft TVD below the base of permafrost interval. 6. Nipple down diverter and install wellhead. Nipple up BOP stack and pressure test same to 3000 psi. 7. Pick up 4-3/4" mill tooth bit, 3-1/2" drill collars, and 2-7/8" drill pipe. Trip in and drill out stage collar. Clean out to top of 3-1/2" casing. 8. Pressure casing to 3,000 psi for 30 minutes per AOGCC regulations. Record results. 9. Swap well over to non-freezing completion brine. Circulate well clean. Trip out. 10. Rig up and run 3-1/2" tubing tieback to surface for monobore inj_e.~ct~0~r. Sting into seal bore and pressure test tubing and annulus to 3,000 psi. Set tubing hanger. Install back pressure valve. 11. Nipple down BOP stack. Install production tree and pressure test same. 12. Secure well, release rig. 13. Rig up Coiled Tubing Unit (CTU) and clean out 3-1/2" monobore tubing to PBTD. Circulate well to clean brine. Secure well and release CTU. 14. Rig up E-line unit and RIH with CBL/CET, and run cement bond log across West Sak interval. Report results to office for remedial action if necessary. 15. Rig up E-line unit and RIH with through-tubing perforating guns. 16. Perforate well overbalanced. POOH with perf guns. Repeat runs as required to perforate all desired West Sak intervals. Rig down E-line unit. 17. Install back pressure valve, shut in and secure well. 1 D-132 (K4) Page I TAB, 06/11/98, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS & DRILLING AREA RISKS West Sak 1D-132 (K4) Drillinq Fluid Type Extended Bentonite Slurry Drillinq Fluid Properties: Property Density Plastic Viscosity Yield Point Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to TD Initial 8.8-9.0 ppg 4O 15-45 5-20 10-30 8-15 8.0-10.0 4-6 % Spud to TD Final 9.7-10.0 ppg 35 20-35 5-15 10-35 5-10 8.0-9.5 8-12 % Drilling Fluid System: Tandem Brandt Scalping Shale Shakers Triple Derrick Flow Line Cleaners Solids Processing System to Minimize Drilling Waste Desander, Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Mud Hoppers with Mixing Pumps *Spud mud should be adjusted to a FV between 200 - 250 sec/qt to drill gravel beds. Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Only one hole section will be drilled in this well. This single hole section will be drilled using a diverter system only for well control. A tapered 5-1/2" x 3-1/2" surface / production casing string will be run at total depth (TD). This combination surface / production casing will be cemented to surface using a stage (DV) collar. The stage collar will be placed approximately 200 feet TVD below the base of the permafrost interval. MASP (Maximum Anticipated Surface Pressure): Since a separate string of surface casing is not planned for the West Sak 1D-132 (K4) well, there is no surface casing to be drilled out below requiring a BOP stack to be utilized. The combination surface / production hole to be drilled from surface through the West Sak pay zone can safely be drilled using a diverter system only for well control purposes. 1 D-132 (K4) Page I TAB,06/11/98,v. 1 Based on actual well test data from the nearby WSI-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/fi, or 8.2 to 8.8 ppg EMW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.? ppg can be predicted as a maximum mud weight required to safely drill this formation, assuming a TVD of 3,581' MD/TVD. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Since the combination surface / production casing will not be drilled out, leakoff test and MASP calculations are not necessary for drilling ahead. However, MASP calculations for cased hole operations are in order. Calculating MASP based on the highest recorded reservoir pressure from the WS1-01 well, and assuming a gas gradient of 0.11 psi/ft from the West Sak base to surface, the following MASP can be computed: MASP -- (4002 ft)(0.46 - 0.11 psi/fi) = 1400 psi Based on this calculation for MASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 5-1/2" x 3-1/2" combination surface / production casing in this well, the BOP stack will be installed and tested to 3,000 psi. The stage collar will then be drilled out and the well cleaned out to PBTD. At that time, the casing will be pressure tested for 30 minutes at a surface pressure of 3,000 psi as well. The 5-1/2" 15.$# LB0 BTO casing to be used has a burst rating of 7,000 psi; 70 % of this burst rating is 4,900 psi. After testing, a 3-1/2" tubing tieback string will be installed in the well to be used as the injection string. Drillinq Area Risks: Drilling risks in the West Sak 1D-132 (K4) area are limited to lost circulation and potential borehole instability in and below the permafrost formation. Lost circulation will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. Based on previous Drill Site 1D drilling results, 10.0 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AAI requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak 1D-132 (K4). Well Proximity Risks: The nearest existing well to West Sak 1D-132 (K4) is WS 1D-133 (J5). As designed, the minimum distance between the two wells would be 9.4' at 400' MD. Annular Pumping Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-1D. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-132 (i(4) surface casing / production tubing annulus will be filled with diesel and/or non-freezing brine after setting the 3-112" tubing tieback string and prior to the drilling rig moving off of the well. 1D-132 (K4) Page 2 TAB,06/11/98,v.1 16" Conductor @ 80' WesCSak 1D-132 (K4) Injector Completion 5-1/2" x 3-1/2" Tapered String G. 3-1/2" Vetco-Gray tubing hanger 3-1/2" EUE 8RD-Mod pin down Weatherford Gemoco 5-1/2" DV Stage Collar Stnd. Grade BTC Threads (set +/- 200 TVD below permafrost) F. 3-1/2" L-80 9.3# EUE 8RD-Mod tubing to surface Production csg. 5-1/2" 15.5# L-80 BTCM run XO/SBE to surface XO set +/-100' above top perf (+/- 5077' MD / 3493'-I-VD) E. 3-1/2" x 1" Camco 'KBG-2~9' mandrel w/DV & latch, 3-1/2" x 15' pups installed above & below, BTCM pin × EUE 8RD-Mod box Special Clearance Coupling D. 1 jt 3-1/2" L-80 9.3~ EUE 8RD-Mod tubing C. 3-1/2" Camco 'DS' landing nipple w/2.812" No-Go profile. 3-1/2" x 6' L-80 pups installed above and below. EUE 8RD-Mod B. 1 jt 3-1/2" L-80 9.3# EUE 8RD-Mod tubing A. Baker 3-1/2" 'GBH-22' Locator Seal Assembly w/12' of seals & Iocator 3-1/2" x 6' handling pup installed on top. EUE 8RD-Mod box up Iiaker 5-1/2" XO, BTC x LTC aker XO Coupling w/Iocator shoulder, LTC x SBE aker 5" OD x 4" ID Seal Bore Extension aker XO, SBE x 3-1/2" EUE 8RD D Sands B Sands A Sands Production csg. 3-1/2" 9.3# L-80 EUE 8RD-Mod run TD to XO/SBE (+/- 5077' MD / 3493' -I-VD) to (+/- 5825' MD / 4190' -I-VD) TAB, 6/11/98, v.2 KUPARUK RIVER UNIT - WEST SAK OPERATIONS 20" DIVERTER SCHEMATIC L_=_ 5 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 4 .I 3 HCR . MAINTE~NANCE & 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 PS! BALL VALVE. 4. 20"- 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINF_ THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20"- 2000 PS! ANNULAR PREVENTER. TWM, 9/15/97 8 i 6 5 13 5/8" 5000 PSI BOP STACK West Sak Operations - Injector Wells ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH 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 BOTTOM PIPE RAMS. TEST BO'I-I'OM 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 TESTTO 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 DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13, RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14, PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY, VBRS WILL ACCOMODATE 3-1/2" TO 6" OR 4-1/2" TO 7" PIPE ODS AS APPROPRIATE. 1. 16" - STARTING HEAD 2_ 7-1/16' - 5000 PSI TUBING HEAD 3. 7-1/16' - 5000 PSI X 13-5/8" - 5000 PSI DOUBLE STUDDED ADAPTER/SPACER SPOOL 4. 13-5/8" 5000 PSI X 13-5/8" 5000 PSI SPACER SPOOL 5. 13-5/8" - 5000 PSI PIPE RAMS 6. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 7. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 8. 13-5/8" - 5000 PSI ANNULAR TWM, 9/18/97 I V C~,ot~ b~ ~h For: BROCKWAY O~te i=l~fled: 29-Uay-98 Plot Ref~ren~ ;; ~ 1~132/K~ V~. ~. Coo~;nat~ ~ rn fe~ ~ference sro{ ~1~2. T~e Ve~al ~p~ ore ref~ence ~B (Palm ~24~). 300 300 600 900 1200 1500 1800 2100 2400 27OO 3000 3300 3600 3900 4200 4500 30O ARCO Alaska, Inc. Structure : Pad 10 Well : 132 Field : Kuparuk River Unit Location : North Slope, Alaska 199.28 AZIMUTH 3435' (TO TARGET) · **Plane of Proposal*** 200 ! ESTIMATED SURFACE LOCATION: 436' FNL, 600' FEL SEC. 23, T11N, RIOE tRKB ELEVATION: 112' KOP TVD=250 TMD=250 I]EP=0 BEGIN TURN TO TARGET TVD=350 TMD=350 OEP=3 6.90 11.42 16.22 21.11 DLS: 5.00 de9 per 100 ft 26.04 30.99 35.96 40.93 45.91 50.89 EOC 'rv0=1237 TM0=1413 OEP=516 TARGET LOCATION: J 1602' FSL, 1734' FEL SEC. 23, T11N, RIOE TARGET TVD= 3728 TM0=5333 DEP=3435 SOUTH 3242 WEST 1134 MAXIMUM ANGLE 56.53 DEC B/ PERMAFROST TVD=1628 TMD=2122 DEP=1107 BEGIN ANGLE DROP TVD=2641 TMD=3959 0EP=2640 55.30 49.50 46.30 43.30 T/ UGNU SNDS TVD=2981 TMD=4476 0EP=3028 40.30 37.30 34.30 31.30 28.30 25.30 22.30 T/ W SAd< SNDS/EOO TVD=3581 TMD=5177 0EP=3381 TARGET - A3 TVD=3728 TMD=5333 OEP= TARGET ANGLE 20 DEG B/W SAK SNDS TVD=4002 TMD=5625 DEP=3534 TD - CSG PT TVB=4190 T~=58;~5 DEP=3§03 I i i I i i I i ii i i I i i i I ii I I i 300 600 900 1200 1500 1800 21 O0 2400 2700 3000 3300 Vertical Section (feet) -> <- West (feet) 900 600 300 0 I I I I I I I Begin Turn to TorCe~ ~$ Base Permafros[ Angle Drop Ugnu Sands West Sak Sands / EOD - West Sok A3 West Sak Sands rD - 5 1/2 Casing Pt TO LOCATION: 1443' FSL, 1788' FEL SEC. 23, T11N, RIOE DLS: 3.00 deg per 100 ft i i I i 3600 3900 300 300 0 300 6OO 9O0 1200 1500 1800 2100 2400 2700 3000 3300 3600 0 I V ~o~e~ ~ ~;~ch For: BROCKWAY D~te plotted: 2g-~y-g8 Plot Reference is Ceordino[es ore in feet reference s~ot ~132. Vertical Depths ~re reference IJi l C 0 Alaska. Structure : Pad lO I1:152 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 200 180 160 140 120 1 O0 80 60 40 20 0 20 40 60 80 1 O0 20 6o ~o -'" , '~oo ~ 13oo ..-/ /" 8 '-k_ 80~'- /" .-' 900 /'" '/ 000 /"/' ",, "' " ' / // /" 1 600 \ \ ~ / / ..-" ,' 500 --- \ \ 900,.,' / ~ 1 O0 ,-~',~,~ /'~00 ~ X ", 1000 · / / ..,ou~ , ---/- \ ~00 ........... 20 ./ O0 ." / 800 ¥ ............ .'/' / /...'"' .~701 ......... fi_ _0_0_ .... ~8_0_.0_ .... k~:~ 1400 ,,' $ ,,' ~(.o/.,,' ~oo .... i \ -/' ," / 1500' 60 -" 2'~ // "' /// ~800 1500i k 1000// / / ,,' ./700 / ouu -' ," ," / _~ i \ ~ 8oo ,/' ~ 1300 ," 1100/ ' / --'-'~ ~ \ // ,"~00 ~,,/ / ./'600 ~_~.~00 ~. ~1600 / "ooo / -------.~ 1 oo [ \ , oo , oo,., ¢__o__o__:.o..o. . 1100 ,, ~ '-........ , 900 · / 700 "'-. i ~oo ,.,'" 1300 2900 ,' ~ 800 / ~oo /' j o " " " 'k ~oo ,'"' 30002500;, 2100 1600 ~_500 T~ ,,' 6~oo ," / .' 300 I ~ 1800 ,,,' 1400 ¢ 900 "., 700 , 400 800~ 1000 I , i ',, 1900 1500 ¢ 1000 ! ,,, 900 ; i I ' \\ i I i i i I i I i I i I I i I i i i i i I i i I i i i i 200 180 160 140 120 1 O0 80 60 40 20 0 20 4-0 60 80 1 O0 120 <- Wesf (feel) 80 100 120 140 160 180 2OO 22O 240 260 280 3OO 20 2O 40 60 80 1 O0 ,--I- 120 '-~ 140 I v 240 260 280 300 220 20O 18o 160 O~0tea ~ ~ For: BROCKWAY Date platted : 29-May-§8 Plot Reference is ~ 10-132/K4 Vets. Coordinates ore in feet reference slot ~152. Vertical Depths ore reference ~B Structure : Pod 1D Well: 152 Field : Kuporuk River Unit Location : North Slope, o 200 240 280 320 360 400 440 480 520 560 600 640 680 72O 760 800 - 840 - 880 - 920 <- West (feet) 480 440 400 360 320 280 240/~ 200 160 120 80 40 0 40 80 52O ~'--/I //' 400 .,.-' #-'(2oo '" '" 1100 . /' 1200 1700 1100 i500 1600 1100 6OO /' ,.'"1200 /' .. / / / .,, / !000 ,' / / / / / / / / / / .,' 1,300 ,' / 1400 1300 1200 / / 500 I I I i I i I i I i 1000 i 1500 ] 1000 1700 1800 1900 20OO 2100 1100 2100 11200 22oo~ 1300 ~ 2300 ! / 1400 24O0 ! ! ! ¢2500 / / 1500~ / i/ 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 <- West (feet) ' ' ' 800',.,, '¥. 1900 240 900 280 2000 32O 36O 400 440 480 0 520 560 "~ 6OO v 640 680 720 76O 800 840 880 92O Creoted by finch For: BROCKWAY ~ate plotted : 2g-I~ay-g8 Plot Reference ;s ~ 1D-132/K¢ Verm ~3. Ca~;nates ere in feet reference slot ~132. Vert~el Depths are re~erence ~8 (Park~ ~2~5), Alaska, Inc. r--~ct--~-re--~-'Pad 1-~ ...... ~;11:132 --- Field : Kuparuk River Unit Location : North Slope, Alaska goo 1 ooo 1100 1200 1300 1400 1500 1600 ~ 1700 · q--1800 0 19oo I V 2000 2100 2200 2300 2400 2500 2600 2700 <- West (feet) 1300 1200 1100 1000 go0 800 700 600 500 400 300 200 100 0 100 200 ...':%;,0 , 26 / /500 / /2800, 3100 ,'" / 2900/ ~0/1600 / / ~ ~300,; 2000/ / !3soo,," / 3000/ /~00,,, itI IIt /'1900 / / / ,/ j2300 ! ,, / / ¢ 2400 / ! ,, / 12500 ! / ! ' 2600 / / / / 2700 / / 2800 1 I I I I ? I I I I I~ 2100 2200 / / ¢' 1600 / / 700 1800 1900 20OO 220C 2700~ I 2800~40£ / / ! / 2900 / 2500 / / ! / 3000 / 2600 ! 31oo / ! / / ! I 190C /~ I 2600 1600 ~300 1700 1800 2700 2800 ! 2000 / 2900 3200 ¢ I I 3000 I , I ! 3100 / ! 21oo 3300 i 3200 ! I 3300 / I ! 3400 ! I 3500 3400 1 ? 2200~ 3600 ! , ! I 3700 / , 3800 / ! i 3900 ;500 / i ooo ! I , 4100 I 2300 / O0 / / / 3600 / I I I I I I I I I I I I I I I I 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O0 0 1 O0 200 <- West (feet) 900 lOOO 11oo 200 1300 1400 1500 1600 0 1700 ~ --i- 1800 '-~ 9OO I V 2O00 2100 22OO 2300 2400 2500 260O 2700 ARCO Alaska, Inc. Pad 1D 132 slot #132 Kuparuk River Unit North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E R E P O R T Baker Hughes iNTEQ Your ref : WS 1D-132/K4 Vets. #3 Our ref : prop2190 License : Date printed : 29-May-98 Date created : 16-Apr-97 Last revised : 27-May-98 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 18 1.316,w149 30 18.908 Slot location is nT0 17 57.028,w149 30 36.399 Slot Grid coordinates are N 5959228.709, E 560490.505 Slot local coordinates are 436.00 S 600.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference Nort~ is True North Report is limited to clearances less than 500 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object we11path PMSS <0 - 7340~>,,10,Pad 1D PMSS <556-7024~>,,9,Pad 1D MSS <3311-8200~>,,7,Pad 1D PGMS <0-8610~>,,6,Pad 1D PGMS <0-8930~),,5,Pad 1D PGMS <O-7502'>,,4,Pad 1D PGMS <0-8070~>,,3,Pad 1D PGHS <O-9783'>,,2,Pad 1D PGMS ~O-8365~>,,1,Pad 1D 1D-D Version #2,,1DoD,Pad 1D 1D-F Version #2,,1D-F,Pad 1D 1D-B Version #3,,1D-B,Pad 1D TOTCO Survey,,WS-8,Pad 1D PMSS <O-5462~>,,J3,Pad 1D WS 1D-127/L1 Vets. #3,,127,Pad 1D WS 1D-128/K2 Vets. #3,,128,Pad 1D WS 1D-126/J1 Vets. #5,,126,Pad 1D WS 1D-110/C3 Vets. #3,,110,Pad 1D WS 1D-125/H2 Vets, #3,,125,Pad 1D WS 1D-123/G1 Vets. #3,,123,Pad 1D WS 1D-122/F2 Vets. #3,,122,Pad 1D WS 1D-116/E1 Vers. #3,,116,Pad 1D WS 1D-114/D2 Vets. #3,,ll4,Pad 1D WS 1D-113/C1 Vets. #3,,113,Pad 1D WS 1D-112/A1 Vets. #3,,112,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 28oApr-98 104.8 650.0 650.0 29-Apr-98 300.0 100.0 100.0 6-Nov-97 29.9 604.8 5700.0 13-Nov-97 72.4 250.0 250.0 13-Nov-97 192.5 250.0 250.0 4-Aug-92 312.8 250.0 250.0 4-Aug-92 433.1 0.0 0.0 4-Aug-92 552.9 250.0 250.0 10-Dec-97 673.0 0.0 250.0 24-Nov-9? 88.0 250.0 250.0 24-Nov-97 24.5 500.0 500.0 24-Nov-97 58.0 250.0 5660.0 21-May-98 78.4 875.0 875.0 1-Dec-97 45.0 100.0 ' - 100.0 27-May-98 120.0 250.0 250.0 27-May-98 105.0 250.0 250.0 27-May-98 135.0 250.0 250.0 27-May-98 478.0 250.0 250.0 27-May-98 148.0 250.0 250.0 27-May-98 223.0 250.0 250.0 27-May-98 238.0 250.0 250.0 27-May-98 358.0 250.0 250.0 27-May-98 388.0 250.0 5780.0 27-May-98 403.0 250.0 250.0 27-May-98 418.0 250.0 250.0 wS 1D- 158 WS 1D-141 WS 1D- 142 W$ 1D- 140 WS 1D-139 W$ 1D- 143 W$ 1D- 144 WS 1D- 145 WS 1D- 146 WS 1D- 147 WS 1D- 148 WS 1D- 149 WS 1D- 152 WS 1D- 150 WS 1D- 153 WS 1D- 154 WS 1D-155 WS 1D-Iii/B2 Vets. #3,,11i¥~ad 1D WS 1D-136/J7 Vets. #1,,136,Pad 1D PMSS <0-4414'>,,GS,Pad 1D PMSS <0-4530'>,,F6,Pad 1D PMSS <O-4515'>,,F4,Pad 1D PMSS ¢0-4590'>,,ES,Pad 1D PMSS <O-5142'>,,E3,Pad 1D PMSS <0-5205'>,,ET,Pad 1D PMSS <0-5047'>,,G3,Pad 1D PMSS <0-4850'>,,D4,Pad 1D PMSS <0-5126'>,,D6,Pad 1D PMSS <381-6092'>,,C7,Pad 1D 'Lll Vets. #1,,158,Pad 1D 'All Vets. #1,,141,Pad 1D 'B10 Vers. #l,,142,Pad 1D /A9 Vets. #1,,140,Pad 1I) 'B8 Vets. #1,,139,Pad 1D /C9 Vets. #1,,143,Pad 1D /DS Vets. #1,,144,Pad 1D /Cll Vets. #1,,145,Pad 1D /D10 Vets. #1,,146,Pad 1]) /E9 Vets. #1,,147,Pad 1D /Ell Vers. #1,,148,Pad 1D /F8 Vets. #1,,149,Pa~ 1D /G9 Vets. #1,,152,Pad 1D ~F10 Vets. #1,,150,Pad 1D ~H10 Vets. #1,,153,Pa~ 1D ~Jll Vers. #1,,154,Pad 1D /H8 Vets. #1,,155,Pad 1D WS 1D-156/J9 Vers. #1,,156,Pad 1D WS 1D~157/K10 Vets. #1,,157,Pad 1D WS 1D-159/L9 Vets. 91,,159,Pa~ 1D WS 1D-160/K8 Vets. #1,,160,Pad 1D WS 1D-161/L7 Vets. #1,,161,Pa~ 1D WS 1D-138/K6 Vets. #1,,138,Pa~ 1D WS 1D-151/G11 Vets. #1,,151,Pad 1D WS 1D-107/B4 Vets. #1,,107,Pad 1D WS 1D-102/A5 Vets. #3,,102,Pad 1D WS 1D-103/B6 Vets. #3,,103,Pad 1D WS 1D-104/A7 Vets. #3,,104,Pad 1D WS 1D-108/A3 Vets. #3,,108,Pad 1D PMSS <1957-5265'>,,JS,Pad 1D WS 1D-101/C5 Vets. #3,,101,Pad 1D PMSS <O-5015'>,,G7,Pad 1D PMSS <O-4778'>,,H4,Pad 1D WS 1D-131/L3 Vets. #3,,131,Pad 1D WS 1D-134/L5 Vets. #3,,134,Pad 1D 27-May-98 27-May-98 8-Dec-97 19-De=-97 16-Dec-97 22-Dec-97 30-Dec-97 ?-jan-98 6-Jazl-98 12-Jan-98 19-Ja~-98 27-Jan-98 27-May-98 27-May-98 27-May-98 27-May-98 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-A~r-97 15-Apr-97 15-Apr-97 15-Apr-97 15-Apr-97 15-A~r-97 15-Apro97 15-Apr-97 15-Apr-9? 15-Apro97 15-Apr-97 27-May-98 27oHay-98 27oMay-98 27-~4ay-98 15oApr-97 27-May-98 27-May-98 27-May-98 27-May-98 27-~ay-98 24-Nov-97 27-May-98 13-Nov-97 9-Nov-97 27-May-98 27-May-98 463.0 70.9 255.0 270.0 285.0 329.7 375.0 345.0 165.0 495.0 540.0 569.7 222.4 217.2 209.1 226.0 235.5 201.7 195.3 189.8 185.3 182.0 179.9 179.0 183.9 179.4 187.9 192.9 199.0 206.0 213.8 231.6 241.4 251.7 131.9 181.0 523.0 613.0 598.0 583.0 508.0 9.4 628.0 53.8 30.0 15.0 45.9 250.0 675.0 100.0 100.0 100.0 250.0 100.0 100.0 100.0 100.0 100.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 501.7 250.0 250.0 250.0 250.0 250.0 250.0 400.4 250.0 700.0 100.0 250.0 800.0 5303.2 675.0 100.0 100.0 100.0 250.0 100.0 100.0 100.0 100.0 100.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 4501.3 250.0 250.0 250.0 250.0 5760.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 250.0 501.7 250.0 250.0 475O.4 250.0 250.0 250.0 400.4 250.0 700.0 100.0 5824.6 800.0 E£v]' DA~ IeY i ~ i~Pl ... I~E:',~IPT. ION IRE:~ "i~ ! DE,~T, RiPTION _. AIRSTRIP ' ~ ' ~, 10.~ ~ i 112~ ~ ~ ~ ~ClNI~ MAP ~ ,,~ ,,, , . .. 122 ~ 123 ~, 125 ' 127~ 126 I 128 e6 ' I ' t'2. 040~~ 132 ~ i I O ~0 ' ~ I I i ~' ] '. , LEGEND SEE SHEET ~ 2 FOR NOmS ~O LO~TION INFORMATION , m m ·~ s~ 0 EX/STING CONDUCTORS ~ J~ LOUN URY ~ "ZS-STZKEO" CONOO~T~ LOCA ~ON~[~ & ASSOCMTgS, INC. ~ "PROPOSED" CONDUCTOR L~ADON ~ENG~EERS P~N~RS ...... ~A' 1D..... M~ULE XX ' UNIT' 01 ARCO Alaska, Inc. a~ DRILL Sl~ 1-D ~ ~ST SAK PHASE lB - ~ C~DUCTORS AS-STAKED LOCA3ONS .. i . · . ., ' DESCRIPTION DESCRIPTION NO TES COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.D. 27. ELEVATIONS SHOWN ARE BRITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES SHOWN ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. I-D MONUMENTS PER LHD AND ASSOCIATES. .:7.CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECTIOIVS 14 & 23, TOWNSHIP. 11 NORTH, RANGE 10 EAST, U.M. 4. DATE OF SURVEY: 5/16/98, FIELD BK. L98-42 Pgs. 8-14. .5. DRILL SITE I-D GRID NORTH IS ROTATED 00' 01' 05" WEST FROM A.S.P. ZONE 4 GRID NORTH. ~. SEE DRAWING NSK-`7.5-1 FOR AS-BUILT LOCATIONS OF CONDUCTORS 1-8; CEA-D1DX-6104DIO FOR CONDUCTORS I05,106,109,115, I 17-121, 124,129,1,70,1,73 & 135; AND CEA-DIDX-6104DI3 FOR CONDUCTORS 9 & 10. S. 1B WEST SAK-1 THIS SURVEY V/CINITY MA P SCALE: I" -- I MILE ,y, A.S.P.s 'X' I LA TI TUDE L ONGi TUDE "* 5, 959, 738. 9 ** 5,959, 708.9 ** 5, 959, 693. 9 *' 5, 959, 648. 9 ** 5, 959, 6,73. 9 ** 5,959,618.9 ** 5, 959,588. 9 5, 959, 469. 0 5,959,45.7.9 5, 959, $ 79. 2 5, 959, $65. 9 5, 959, 348. 9 5, 959, 334. I 5, 959, 244. 0 5,959,229.2 5, 959,153. 8 560, 490. 6 560, 490. 6 560, 490. 6 Sec. 14, T. 11 N., 70' 18' 02, 05' 70' 18' Of. 75" 70' 18' 0I. 60" R. IO E 149' .TO' 36. 28" I49' 30' ,76.28" 149' $0' ,76.29" 560,490.6 560, 490. 6 560, 490. 6 560, 490. 6 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 7 560, 490. 8 Sec. 23, 70' 18' 70' 18' 70' 18' 70' 18' 70' 17' 70' 17' 70' 17' 70' 17' 70" 17' 70* 17' 70' 17' 70" 17' 70" I7' T. 11 N., 01. 16" 01.01" 00,87" 00.57" 59.39" 59.24" 58. 51" 58. 36" 58.21" 58. 06" 57.18" 5ZOJ* 56. 29" R. 10 E. 149' `70' `76.`70" 149' 30' 36. 30" 149' 30' ,76. 30" 149' 30' 36.31" 149' 30' 36.34" 149' 30' .76.34" 149' $0' `76. $6" 149' `70' .76..76" 149' .70' .76..76" I49' 30' .76..77" I49' 30' `76.`79" 149' .70' .76~.79" 149' 30' .76.41" ** Proposed location, work in progress 'ARCO Alaska, Inc. LOUNSBURY & ASSOCIATES, INC. E~r~NEERS PLANNERS SURVEYORS AREA: ID MODULE: XX DRILL SITE 1-D CADD FILE NO. I IDRA1MNG NO: LK6104014 5/16/98 UNIT: D1 WEST SAK PHASE lB - WELL CONDUCTORS AS-STAKED LOCATIONS SHEET: NSK 6.104-d14 I REV: 2 OF 2 m 0 ARCO Alaska, Inc. ~- ¢- Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 11, 1997 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill West Sak 1 D-132 West Sak Phase 1 B Development Well, Kuparuk River Unit Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak sands in the vicinity of 1D pad. The well is designed as a monobore injection well using a 5-1/2" x 3-1/2" tapered casing string, with 3-1/2" tubing used as a tieback string. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottomhole locations proposed for the well per 20 AAC 25.005 (c) (2). Note the 40 acre spacing requirements governed by the West Sak Pool Rules. 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). Note that due to the pressures expected in the West Sak sands, ARCO proposes to test the 5000 psi BOP equipment to a maximum of 3000 psi, pending AOGCC approval per this letter and APD. Please note that due to the large number of KRU and West Sak wells which have penetrated the West Sak sands in this area, ARCO has a clear understanding of the formation pressures to be encountered. As a result, no overpressured strata is expected in this area. There are also no shallow hazards expected at WS 1D-132, such as shallow gas. There have been eight (10) Kuparuk wells and (14) West Sak wells drilled from KRU 1D pad, and no occurrences of shallow gas or other hazards have been observed. There is a gas sand at approximately 2,100' TVD which is present, but has not caused any past problems in the existing wells which penetrated this sand using a diverter system only. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany An exception to the requirements set out by 20 AAC 25.033 (e) and 25.061 (a) are hereby requested for this APD because of this regional experience. A prediction of the maximum downhole and surface pressures which may be encountered however are included in this APD per 20 AAC 25.035 (d) (2). 6) A complete proposed casing and cementing program is attached as per 20 AAC 25.030. A wellbore schematic is also attached visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. 8) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. 9) Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S monitoring equipment functioning on the rigs as is the standard operating procedure in the Kuparuk River Unit drilling operation. 10) Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. An exception to the requirements detailed in 20 AAC 25.005 (c) (8) is thus requested. Please note that the anticipated spud date for this well is July 7, 1998. If you have any questions or require further information, please contact Tom Brockway at (907) 263-4135 or Tom McKay at (907) 265-6890. Since~t~'? ~,~ ,~ .///'~ Thomas A. Brockway ~ Operations Drilling Enginee~r'' Attachments: cc: West Sak 1D-132 Well File Tom McKay ATO-1202 Keith Lynch ATO-1228 Ike Bellaci ATO-1260 Cliff Crabtree NSK6 · WELL PERMIT CHECKLIST COMPANY ~ I~ (. CO WELL NAME FIELD & POOL INIT CLASS '] - ~ ~ w3 GEOL ~ ~ L~ - ~ ~ Z PROGRAM: exp [] dev [] redrll [] servr,~wellbore seg I] ann. disposal para req II AREA ~ c~ 0 UNIT# / )/ ~ O ON/OFF SHORE 0//1 ADMINISTRATION A~,R DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING ;ARPP.. DATE 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved. 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... N N N N ~N (~ N N .~_N N N N YC¢ N Y N 31. Data presented on potential overpressure zones 32. Seismic analysis of shallow gas zoO.. 33. Seabed condition su?~e) ............. II ABPR DATE 34. C~y progress reports ....... II ~AR DI'-D¥~P-~A-~'11 35.--~-~h proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... II (B) will not contaminate freshwater; or cause drilling waste... ~ N Y N Y N Y N Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N M:chel~lis! rev 05/29/98 dlf:C:\msoffico\wordiar~\diana\<: e~.t :; ENGINEERING: UIC/Annular COMMISSION: JDLL..-.~ co ..... GEOLOGY: RPC.__~_ PLEASE NOTE: Your request for an exception to the requirements of 20 AAC 25.033(e) and 25.061(a) is NOT needed. Those requirements apply to exploratory and stratigraphic test wells only. Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Thu Oct 01 09:52:54 1998 Reel Header Service name ............. LISTPE Date ..................... 98/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 98/10/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT (WEST SA/<) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 1 AK-MM-80299 S. GONIOTAKI B. MORRISON 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING 1D-132 500292289500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-OCT-98 OPEN HOLE MWD RUN 2 AK-MM-80299 S. BURKHA3tDT B. MORRISON MWD RUN 3 AK-MM-80299 S. BURKHARDT B. MORRISON 23 llN 10E 436 600 .00 111.90 70.40 CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 5802.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1, 2, AND 3 ARE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER -MUELLER TUBE DETECTORS AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 ( EWR4 ). 3. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E MAIL MESSAGE FROM MIKE WERNER OF ARCO ALASKA, INC. ON 08/26/98. 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5802 'MD, 4203 ' TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = MUD MOTOR DRILLING (NO ROTATION). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE RPD RPM RPS RPX GR FET ROP $ START DEPTH STOP DEPTH 83.0 5764.0 83.0 5764.0 83.0 5764.0 83.0 5764.0 90.5 5771.5 121.0 5764.0 122.5 5803.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BA~E 1 121.0 2732.0 2 2732.0 4930.0 3 4930.0 5802.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 ROP MWD FT/H 4 1 68 FET MWD HOUR 4 1 68 RPS MWD OHMM 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max DEPT 83 5803 GR 11.8508 149.054 RPX 0.5604 2000 RPM 0.0861 2000 RPD 0.05 2000 ROP 12.6709 1673.18 FET 0.0751 11.1795 RPS 0.2097 2000 Mean Nsam 2943 11441 72.3689 11363 101.324 11363 86.2839 11363 87.321 11363 276.754 11362 0.45929 11287 84.4416 11363 First Reading 83 90.~5 83 83 83 122.5 121 83 Last Reading 5803 5771.5 5764 5764 5764 5803 5764 5764 First Reading For Entire File .......... 83 Last Reading For Entire File ........... 5803 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE S~Y VENDOR TOOL CODE START DEPTH RPD 83.0 RPM 83.0 RPS 83.0 RPX 83.0 GR 90.5 FET 121.0 ROP 122.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2693.5 2693.5 2693.5 2693.5 2700.5 2693.5 2731.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHF~4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 23-JUL-98 ISC 5.06 CIM 5.46/EWP4 1.38 ~ORY 2732.0 121.0 2732.0 .0 58.8 TOOL NUMBER P1033CRG6 P1033CRG6 8.500 8.5 SPUD MUD 9.00 234.0 8.7 400 6.3 5.500 4.370 6.500 3.300 28.6 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max'frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 1 API 4 1 RPX MWD 1 OHMM 4 1 RPM MWD 1 OHMM 4 1 RPD MWD 1 OHMM 4 1 ROP MWD 1 FT/H 4 1 FET MWD 1 HOUR 4 1 RPS MWD 1 OHMM 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 83 2731.5 1407.25 GR 16.756 142.247 69.2371 RPX 0.8282 2000 167.855 RPM 0.0861 2000 155.396 RPD 0.05 2000 162.886 ROP 20.0781 627.319 281.569 FET 0.0916 1.5256 0.3681 RPS 0.5144 2000 140.684 First Nsam Reading 5298 83 5221 90.5 5222 83 5222 83 5222 83 5219 122.5 5146 121 5222 83 Last Reading 2731.5 2700.5 2693.5 2693.5 2693.5 2731.5 2693.5 2693.5 First Reading For Entire File .......... 83 Last Reading For Entire File ........... 2731.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEA/DER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET~ 2694.0 4892.0 RPD 2694.0 4892.0 RPM 2694.0 4892.0 RPS 2694.0 4892.0 RPX 2694.0 4892.0 GR 2701.0 4899.5 ROP 2732.0 4930.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 24-JUL-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 4930.0 2732.0 4930.0 28.4 57.3 TOOL NUMBER P1033CRG6 P1033CRG6 8.500 8.5 LSND 9.50 300.0 9.0 400 6.0 10. 000 7.341 7.000 4.000 32.8 REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 68 RPX MWD 2 OHMM 4 1 68 GR MWD 2 API 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHMM 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 RPS MWD 2 OHMM 4 1 68 Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 2694 4930.5 3812.25 4474 RPX 0.6517 2000 58.8539 4397 GR 11.8508 142.009 69.8698 4398 RPM 0.1054 2000 34.9488 4397 RPD 0.1099 2000 28.7738 4397 ROP 14.1572 1673.18 314.14 4398 FET 0.0751 6.7496 0.405104 4397 RPS 0.2097 2000 47.5742 4397 First Reading 2694 2694 2701 2694 2694 2732 2694 2694 Last Reading 4930.5 4892 4899.5 4892 4892 4930.5 4892 4892 First Reading For Entire File .......... 2694 Last Reading For Entire File ........... 4930.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NU/~BER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 4892.5 5764.0 RPD 4892.5 5764.0 RPM 4892.5 5764.0 RPS 4892.5 5764.0 RPX 4892.5 5764.0 GR 4900.0 5771.5 ROP 4931.0 5803.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: 25-JUL-98 ISC 5.06 CIM 5.46/EWP4 1.38 MEMORY 5802.0 4930.0 5802.0 18.4 28.4 TOOL NLTM~ER P1036CRG6 P1036CRG6 8.500 8.5 LSND 9.50 250.0 9.5 400 6.7 2.800 2.078 3.750 3.000 34.5 $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 GR MWD 3 API 4 1 RPX MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHMM 4 1 ROP MWD 3 FT/H 4 1 FET MWD 3 HOUR 4 1 RPS MWD 3 OHMM 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 Name Min Max Mean DEPT 4892.5 5803 5347.75 GR 29.161 149.054 88.0466 RPX 0.5604 112.891 9.1862 RPM 0.6253 78.1308 8.77185 RPD 0.6182 65.4478 8.67029 ROP 12.6709 605.594 168.128 FET 0.1087 11.1795 0.864978 RPS 0.5742 85.9789 8.9871 First Last Nsam Reading Reading 1822 4892.5 5803 1744 4900 5771.5 1744 4892.5 5764 1744 4892.5 5764 1744 4892.5 5764 1745 4931 5803 1744 4892.5 5764 1744 4892.5 5764 First Reading For Entire File .......... 4892.5 Last Reading For Entire File ........... 5803 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/10/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/10/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Scientific Technical Services Service name ............. LISTPE Date ..................... 98/10/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File