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Home My WebLink About197-050Operations Performed: Depth Depth Structural Conductor Surface Intermediate Production Abandon ❑ Suspend ❑ for Redrill n Inc STATE ALASKA OIL AND G SCON CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Plug Perforations Fracture Stimulate Perforate Pull Tubing ❑ Other Stimulate ❑ 'rforate New Pool ❑ Alter Casing Q Repair Well Q Re-enter Susp Well ❑ 4. Well Class Before Work: Development ❑ Exploratory ❑ 5. —Pe rr Stratigraphic ❑ Service ✓ 197-050 a. Alaska 9g51n ❑ 6. API Number: 50-029-22753-00-00 KRU-30-19 E REC,rc NFED JUN 2 0 2019 0 at' siutdown Chamm ❑ ADL0025520, ADL025513 submit electronic and printed data per 20AAC N/A iition Summary: measured 9407' feet true vertical 6—feet measured 5007' feet true vertical38-02 measured feet Length Size 80' 16" 5309' 7.625" measured Liner 428P 4.5" kry n depth Measured depth 9072�010 feet True Vertical depth 6554'=feet e, grade, measured and true vertical depth) d SSSV (type, measured and true vertical depth) tion or cement squeeze summary: ated (measured): N/A escriptions including volumes used and final pressure: Prior to well operation: N/A Subsequent to operation NA Attachments (mimed per 20 AAC 2&070,25,071. &25.283) y Report of Well Operations Q ies of Logs and Surveys Run ❑ led and Electronic Fracture Stimulation Data ❑ I hereby certify that the foregoing is true and correct to Winter Plugs measured 8928' feet Junk measured 5007' 'feet Packer measured 5120' feet true vertical 3874' � feet MD TVD Burst 121' 121' 5350' 4025' 9407' 6816' 4.5" L-80 512=— 3874' BAKER SABLM/ZXP LINER TOP PACKER 5120' —� 3874' N/A Average Production or 15. Well Class after work: rvrt� Exploratory ❑ Development ❑ Service 16. Well Status after work: 3STOR ❑ WINJ ✓ Oil ❑ ❑ WAG ❑ GINJ ❑ est of my knowledge. Sundry Number or N/A Collapse Pressure SUSP❑ SPLUG Contact Name: Roger Wint�Mouser Contact Email:N1927(oi7Conoco�� Cnntn�� oma.,.._. acn Form 10-404 Revised 4/2017 / A/ �` /�' RBDMSI�o) JUN 2 Submit Original Only 4 N O CO E O L Q N .n O f cn C O C r O z v l N I Q U CL c CL Q v U° c y o O u r � -1.- 650 RECEIVED r W 2k-1s trjEB 4 2 "L'u1ti WELL LOG TRANSMITTAL AOGCC To: Alaska Oil and Gas Conservation Comm. January 29, 2016 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 "�/204 �.1.K.BENDER Anchorage, Alaska 99501 RE: Temperature Survey: 30-19 Run Date: 12/25/2015 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 30-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22753-00 Temperature Survey Log 200 t 1 Color Log 50-029-22753-00 5 KK") JUL PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MAg.....,(1) `�� • • P j ~ ^~ 111 P r ff SARAH PALlN, GOVERNOR .~ a _ L.~ _ t_.f ~5~~ OI~ ~ a~[v-7 r'~~ 333 W. 7th AVENUE, SUITE 100 CO1~ST' RQATIOIK COl-II~IISSIOrT ,' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 CANCELLATION SUNDRY APPROVAL N0.301-173 Mr. Perry Klein Well Integrity Project Supervisor ~,~ ~,~` 1~ ~~; ; _ ~ ~'~~;J ConocoPhillips Alaska, Inc. ~ P.O. Box 100360 Anchorage, AK 99510-0360 RE: Cancellation of Sundry Approval 301-1.73 (KRU 30-19) PTD 197-050 Dear Mr. Klein: Pursuant to ConocoPhillips Alaska, Inc. (CPAI)'s request dated March 30, 2009 the Alaska Oil and Gas Conservation Commission (Commission) hereby cancels Sundry Approval 301-173, which allows continued water injection. The copy of Form 10-404, Report of Sundry Operations, provided with CPAI's request noting the cancellation of Sundry 301-173 has been placed in the Commission's files. Kuparuk River Unit (KRU) well 30-19 is a monobore injector that exhibits a tubing leak at approximately 5475 feet measured depth. Approval to continue water only injection was contingent on CPAI successfully installing a patch across the tubing leak and implementation of several conditions set out in the sundry approval. CPAI indicates that the initial patch failed a numerous attempts to retrieve the patch have been unsuccessful. The well remains shut in until a rig workover can be completed. Consequently, Sundry Approval 301-173 no longer applies to operation of this well. Instead, injection in well KRU 30-19 will be governed by provisions of the underlying Area Injection Order No. 2B. DONE at Anchorage, Alaska and dated April 7, 2009. p ~~ Daniel T. eamount, Jr. Cathy . Foerster oh {. l m~ Chair Commissioner missioner ~h Aec;~ ap06 C.QA"~ ~',~~~ G `-10~-~ rcQo~ ~~Vrgvc~sg~~ ~,,~ o~~. a~ cc~kls~~ '~'~tc `rct.ackhS~,t1t`r.\h~t-~ V-~c~~ . ~ h !~'i-~/"/ Sac. • Con ' ' ocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 30, 2009, Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~h Avenue, Suite 100 Anchorage, AK 99501 • ~~~~ r. /( ~ ~ ~: ~'~' ~ ~ `" ~r: ,~ .. ~~ ~-~~'` ~t `~ 2p09 Subject: 30-19 (PTD 197-050) request for cancellation of sundry approval # 301-173 Dear Mr. Seamount: ConocoPhillips Alaska requests cancellation of sundry (301-173). The well suffers from T X IA communication and is a single surface casing design. Several attempts to patch the tubing have been made. The most recent resulting in a fish stuck @ 5007' preventing further well work without the use of a work over rig. The well has been shut in since Jan 2001 and will remain shut in until repaired. If you require any additional information please contact myself or MJ Loveland at 659-7043 Perry Klein Well Integrity Project Supervisor .. • __ ~~~~D STATE OF ALASKA AP~ ~ 7 ~b~~ ALASKA OIL AND GAS CONSERVATION COMMISSIOI~~~~~~ p ~ ~8S ~Oi1S. ~OnltillSSl9tl REPORT OF SUNDRY WELL OPERATION 1-.,,,r,____:. 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q XXL Sundry Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate [f Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 197-050 / 3. Address: StraUgraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22753-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 65' 30-19 8. Property Designation: 10. Field/Pool(s): ADL 25520 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 9415' feet true vertical 6823' feet Plugs (measured) Effective Depth measured 9262 feet Junk (measured) true vertical 6702 feet Casing Length Size MD ND Burst Collapse Structural coNDUCroR 121' 16" 121' 121' SURFACE 5285' 7-5/8" 5350' 4024' LINER 4287' 4-1/2" 9407' 6816' Perforation depth: Measured depth: 9072'-9086', 9100'-9120', 9191'-9201' true vertical depth: 6554'-6565', 6576'-6592', 6647'-6655' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5120' MD. Packers &SSSV (type & measured depth) pkr- BAKER'SABLMIZXP' ; HES PACKER 2.313 X 2.205 XN NIP SET 8/9/2002 pkr- 5120' ; 8928' SSSV=NIP SSSV= 507' 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 NA -- Subsequent to operation NA -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service X Daily Report of Well Operations 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 N/A if C.O. Exempt: 301-173 contact MJ Loveland/ferry Klein 659-7 43 Printed Name MJ Lovel d Title Well Integrity Proj Supervisor Signature Phone: 659-7043 Date ~~42/j ~ ~~ n 1 Drake 263-4612 Form 10-40 Revised 04/2006 ~ ~ / Submit Original Only ~ i 30-19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 416!2009 ConocoPhillips Alaska requests cancellation of sundry (301-173). The well suffers from T X IA communication and is a single surface casing design. Several attempts to patch the tubing have been made. The most recent resulting in a fish stuck @ 5007' preventing further well work without the use of a work over rig. The well has been shut-in since Jan 2001 and will remain shut in until repaired. ConocoPhillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~,s March 30, 2009, ~~ ~" ~,~ ~~ Alas a Seamount mmi n ~n~h®r~~ ~~~~Sp O & Gas Co sslo v,~ 333 West 7th Avenue Suite 100 ~~;.vy Anchorage, AK 99501 '~y~~~ ~~~' ~ `~ ~a~ Subject: 30-19 (PTD 197-050) request for cancellation of sundry approval # 301-173 Dear Mr. Seamount: ConocoPhillips Alaska requests cancellation of sundry (301-173). The well suffers from T X IA communication and is a single surface casing design. Several attempts to patch the tubing have been made. The most recent resulting in a fish stuck @ 5007' preventing further well work without the use of a work over rig. The well has been shut in since Jan 2001 and will remain shut in until repaired. If you require any additional information please contact myself or MJ Loveland at 659-7043 Perry Klein Well Integrity Project Supervisor Change Approved Program 0 2. Operator Name: ConocoPhilfips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 - 7. KB Elevation (ft): RKB 65' 8. Property Designation: Kuparuk Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth C_ašing . Structural CONDUCTOR SURF. CASING LINER Perforation depth: e e RECEt\!ED 2 2006 STATE OF ALASKA APR 1 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TI~ on & Gas :<'"- ,.' LQmrmSSIOi! t !'~!~~ Abandon 0 Alter Casing 0 Repair Well 0 Pull Tubing 0 Ope rat. ShutdownO ô o o Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic D Other Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 197-050/ 6. API Number: 50-029-22753-00 .~ploratory D Service 0 9. Well Name and Number: 30-19 10. Field/Pool(s): Kuparuk River Field / Kuparuk Oil Pool measured 9415' feet true vertical 6823' feet measured 9262 feet true vertical 6702 feet Length Size MD 121' 16" 121' 5285' 7-5/8" 5350' 4287' 4-1/2" 9407' Plugs (measured) Junk (measured) Burst TVD Collapse 121' 4024' 6816' Measured depth: 9072'-9086',9100'-9120',9191'-9201' RBDMS BFl4PR 12 2006 true vertical depth: 6554'-6565', 6576'-6592', 6647'-6655' ~iCA~~~~EIJ Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5120' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SABLMIZXP'; HES PACKER 2.313 X 2.205 XN NIP SET 8/9/2002 pkr= 5120'; 8928' I SSSV= NIP SSSV= 507' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl o 0 o 0 15. Well Class after proposed work: Exploratory 0 Dèvelopment 0 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A IfC.O. Exempt 305-371 13. Oil-Bbl Casln Pressure Tubin Pressure 0 0 0 0 Service 0 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations_X WDSPL D 0' Title Phone Problem Well Supervisor Date form 10-404 Revised 04/2004 _ Submit Origin a! Only e e 30-19 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/14/2006 10 attempts to fish the original patch with conventional slick line, braided slick line and coiled tubing have thus far been unsuccessful. With the original patch blocking any further progress the plan forward is to leave the well shut in and work it over to remove and replace the current completion. . ---._- ~ - ~1T~lJŒ e nTl rF,¡,i Þ¡í\ n,Æ\~ Œ, ;,/,"",8\ Ub U LnJ Lb LrlJ @; U \.1 Lru e AI,ASJiA. OILA.lÐ) GAS CONSERVATION COMMISSION Marie McConnell Pro blem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ,~..p~':i lGt1' '" Re: KRU 30-19 Sundry Number: 305-371 ~CANNeG 1, f-' 'ìf' r,¡; ..L. \.) LCUe Dear Ms. McConnell: 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 fonn. 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 decision to Superior Court unless rehearing has been requested. Sincerely, C(ì} (.~()5 e STATE OF ALASKA øf]S ¡-'l /"7/S ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 I RECEIVED f'l)(~DEC 062005 Alaska 0;1 & Gas Cons. Commissio Anchorage 1. Type of Request: Abandon D Suspend D Operational Shutdown D Perforate D Waiver D Other D Alter casing D Repair well 0 Plug Perforations D Stimulate D Time Extension D Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to D?mber: ConocoPhillips Alaska, Inc. Development D Exploratory D 197-050 3. Address: Stratigraphic D Service 0 6. API Number: ./" P. O. Box 100360, Anchorage, Alaska 99510 50-029-22753-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 65' 30-19 8. Property Designation: 10. Field/Pool(s): Kuparuk Unit Kuparuk River Field 1 Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (It): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9415' 6823' 9262 6702 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121 SURF. CASING 5285' 7-5/8" 5350' 4024 LINER 4287' 4-1/2" 9407' 6816 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9072'-9086',9100'-9120',9191'-9201' 6554'-6565',6576'-6592',6647'-6655' 4-1/2" L-80 5120' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'SABLM/ZXP'; HES PACKER 2.313 X 2.205 XN NIF pkr= 5120'; 8928' SSSV= NIP SSSV= 507' 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development D Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 12/06105 Oil D Gas D Plugged D Abandoned D 16. Verbal Approval: Date: WAG D GINJ D WINJ 0 WDSPL D Commission Representative: 17. I hereby certify that the is true and correct to the best 0 my knowledge. Contact: McConnell 1 Loveland Printed Name Marie McConnell 4- Title: Problem Well Supervisor ¿L-, .~¿ .MA7 Signature A~",.J' ~ Phone 659-7224 Date 12/02/05 { Commission Use Only sun~l'umber: ( Conditions of approval: Notify Commission so that a representative may witness ( -y }t=)-.~-r Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D Other: ~()~ <L~~'\\>~\- ~<L'dO~~c.. à-S-, ~~\ R8DMS BFL DEC 072005 s,œ_ APPROVED BY Date: /11 r /05 Approv d b~ l ( COMMISSIONER THE COMMISSION -~; , RIG Sb/j· Form 10-403 R sed 7/2005 u mlt In upllcate INAL e e ConocoPhillips Alaska, Inc. Kuparuk Well 30-19 (PTD 1970500) SUNDRY NOTICE 10-403 APPROVAL REQUEST 12/02/05 The purpose of this sundry request is for approval to reset the liner patch to repair the mono bore casing/tubing leak. ~ t'V\.1()~ 'o()~ Kuparuk well 30-19 is a monobore injection well classified as a "failed MIT" due to the construction ofthe wellbore (i.e., the packer is not set within 200' of the perforations) --. t'\C C>-""\J\\Jc; and requires a passing MITT and MITIA every 2 years to continue water only injection. ~~'(.\. ~Çk~ In February 2001 the MITT failed with a very slow leak off rate. Initial diagnostics -\a ~~ indicated a liner leak at 5475' based on a Borax PNL log. The leak was patched in - 'dlc August 2002 per sundry approval 201-173. A sundry report was submitted, however ç;.. MITTs continued to fail with a very slow leak off and the well remained shut in post patch. A Tecwel LDL (a new sonic leak detect tool) was ran on 10/06/05 and located the leak in a collar at 5532', just below the existing patch. A caliperlog ran on 11/09/05 showed the tbg and liner were in good to fair condition. The Borax PNL log is not as precise in locating leaks as the Tecwel LDL. It is believed that the leak at 5532' is the original leak identified in 2001. The nature of the leak has always been a slow leak off consistent with a collar leak. Approval to reset the patch over the leak at 5532' is required prior to repair of the well. The repair will provide the mechanical integrity necessary for water injection to commence. With approval, repair of the liner leak will require the following general steps: 1. Pull 25' long patch set at 5461'. 2. Reset the patch over the collar leak at 5532'. 3. Perform an AOGCC witnessed MITT & MITIA per Sundry Approval 301-173. 4. Submit a 10-404 report to AOGCC post repair. 5. Submit an Administrative Approval request to replace Sundry Approval 301-173 for a variance for mono bore water only injection. ~ NIP (507-508, 00:4.500) TUBING (0-5120, 00:4.500, 10:3.833) SLEEVE (5068-5069, 00:4.500) SURF. CASING (0-5350. 00:7.625, Wt:29.70) PKR (5120-5121, 00:7.000) LINER (5120-9407, 00:4.500. Wt:12.60) PATCH (5461-5486. 00:3.500) NIP (8729-8730. 00:3.833) PKR (8928-8929, 00.3.958) Perf (9072-9086) Perf (9100-9120) Perf (9191-9201) e e KRU 30-19 CønocoPhilUpsAlaska, Jnc. 30-19 ¡lill¡:¡:i:/:·¡·:i:·¡¡il·I·lllil.I.::::: ..................... f,P"I' . i,:-o;.12D227s~<.H)--_· SSS',¡ r,p; NIPPLE .\"''''.".I¡.j!, I::hm~ '=;n91-e ~j)' I S :;9 de;J :1;> H94i'- ~rigl~} @:. T[: :1rl ::HiJ @:. 9415 .....c IJ !~eñ':;c.:n : )\....(. L PLUGS Las~ lJ~~d~:o ~ Î ')/30/2\.105 . ,'1 ell T, pe I~~' ",,_ ü·':J ·....:Jrrl:le~ t:'. . ,:/H!1::-J~¡ Las: 'l'vlO I{of I C~; Da':). . Tü: ;;;~ 1:) '::<." Max nc.:=u ¡~rI9IG: . f;.6 do;} @ ?:¡on '~~:',~,T~:;:[~;~~: I ~~~;~OC1 . Casing String - ALL STRINGS Descri tion Size CONDUCTOR 16.000 SURF. CASING 7.625 LINER 4.500 Tubing String - TUBING Size Top 45(;':; ¡;. Perforations Summary Interval TVD 9072 - 9086 6554 - 6565 Bottom TVD Wt Grade Thread ~b75 ";> GO I.·¡m ;\,50 R-2 Status Ft SPF Date T e Comment 14 6 4/13/1997 IPERF 3-3/8" HSD Csg Gun; 60 deg hasin 20 6 4/13/1997 IPERF 3-3/8" HSD Csg Gun; 60 deg hasin 10 6 4/13/1997 IPERF 3-3/8" HSD Csg Gun; 60 deg ph¡"!':;in.~~ ::¡..;¿o Zone A-3 9100 - 9120 6576 - 6592 A-2 9191 - 9201 6647 - 6655 A-1 Other (plugs, equip., etc.) - JEWELRY D~p~h . ~yp TYP,e .:;'.'1 :'),,1, :'\i." 5068 3841 SLEEVE 5120 3875 PKR 5461 4098 PATCH 8729 6294 NIP 8928 6443 PLUG 8928 6443 PKR General Nates. Date Note 6/412001 LEAK found 5475' MD PATCHED 8/1412005 EXTERNAL CASING PATCH INSTALLED AT BOTTOM OF CASING MANDREL HANGER. SLEEVE PATCH: 27" LONG x 8", X65 PIPE 101712005 CASING LEAK VERIFIED 5513' Description ID ~.b1:¡ 3,813 3.812 2.375 3.750 0.000 2.313 ::~im{;ü .~¡;. N ';"') ~ \:) (~O Baker 'CM' Sliding Sleeve; Closed 9/10/97 Baker'SABLM/ZXP' HES 3.8" OD PATCH 24.8' LONG W/2.375" ID SET 8/9/2002 Cameo 'DB' Ni Ie NO GO PLUG set 8/18/2002 HES PACKER 2,313 X 2,205 XN NIP SET 8/912002 e e Name of Recipient Page 1 of 1 12/04/05 December 3,2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 5GANNE[) DEC 16 20DS Dear Mr. Maunder: Enclosed please find the following Sundries for ConocoPhillips Alaska, Inc: ~ 30-19 (PTD 197-050) 10-403 Sundry Application to pull and reset the liner patch.~ 3G-24 (PTD 190-134) 10-403 Sundry Application to patch the tbg leak. 1L-23 (PTD 191-062) 10-404 Sundry Report oftbg leak patch repair work. 1 Q-04 (PTD 184-234) 10-404 Sundry Report of attempted tbg leak repair work. Please call me or MJ Loveland at 659-7224 if you have any questions. Sincerely, ~~ð/Øfþ~ Marie McConnell Problem Well Supervisor Attachments Maunder, Thomas E (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs@conocophillips.com] Sent: Friday, September 23, 2005 4:41 PM To: Maunder, Thomas E (DOA) Cc: 'NSK Problem Well Supv' Subject: RE: Monobore Injection Wells Tom: To my knowledge you are correct. Since we recently "discovered" 2M-09A, I cannot guarantee there are not other anomalous wells out there we do not know about. But your list looks complete for the wells we do know about. Should we come across another in this situation you will be the first to know. Jerry Dethlefs Problem well Supervisor ConocoPhillips Alaska 907-659-7043 -----Original Message----- From: Thomas Maunder (mailto:tom maunder~admin.state.ak.us] Sent: Friday, September 23, 2005 9:22 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Monobore Injection Wells Jerry, et al: We are checking our records and wanted to confirm the wells that are monobores. There are various wells out there that have had the name "monobore" attached to them. For this message, monobore means a well that does not have a separate production casing set proximate to the injection horizon and the packer is set a significant distance above the zone. The first 4 wells on the list have the packers set in the surface casing. The wells on our "list" are: 3K-22 .;~ 30-19 ~~~-~ 3Q-21 3R-25 and possibly 2M-09A 3H-lOB would also be on the list, but it is a producer never having been converted. Thanks in advance for your assistance. Tom Maunder, PE AOGCC 1 RE: lA-09 (PTD 1811520) cause off ailed MIl identified by ne... e Sub.iect: RE: 1 A-09 (PTD 1811520) cause of l"ailed MITIA identified by new LDL tool I;rom: NSK Problem Well Supv <n]6] 7@conocophillips.com> Date: Mon, 17 Oct 2005 09:21 :53 -0800 To: NSK Problem WeB Supv <n 1617@collocophillips.com>, Thomas Maunder <tom _ maunder@admill.statc.ak.us> cc: James Regg <jimJegg@admin.statc.ak.us> Tom, The other wells are: 3G-24 - tbg leak found between bottom GLMs at 9346' 3F-13A - Tbg leak to OA found in the packer at 5678' 30-19 - casing leak found in the liner at ~12~\~~-05D All these will have sundries for repair that will report the leak depths once a repair plan is decided. Marie -----Original Message----- From: NSK Problem Well Supv f, C Sent: Monday, October 17, 20059:14 AM To: 'Thomas Maunder' Cc: 'James Regg' Subject: RE: 1A-09 (PTD 1811520) cause of failed MmA identified by new LDL tool Tom, The work load here is such that if a report isn't required there isn't time or resources to create it or it would take time away from monitor the wells for integrity and catching any compliance issues to avoid NOVs, our highest priority. The email was something I sent you as a courtesy as I thought you'd be interested from both a well and engineering prospective. This work will be reported on the summary list of completed wellwork submitted to AOGCC as required. If a repair is made on this well, the sundry will mention the leak depth. Yes, our internal guidelines have changed, internal waivers are no longer issued for failed MITIAs if the well also had a failed MITOA. Marie -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, October 17, 2005 8:01 AM To: NSK Problem Well Supv Cc: James Regg Subject: Re: 1A-09 (PTD 1811520) cause of failed MITIA identified by new LDL tool Marie, Good news on the new diagnostic tool. Is it possible to submit a "report" ofthe work on lA-09? You could submit it with a 404. What are the other wells that you indicate were successfully logged? You state that lA-09 no longer meets CPAI internal requirements. Have the internal requirements changed? Look forward to your reply. lof2 3/6/2006 10: 18 AM RE: lA-09 (PTD 1811520) cause off ailed MIl identified by ne... e Tom Maunder, PE AOGCC NSK Problem Well Supv wrote, On 10/16/2005 4:18 PM: Tom, This note is to inform you of recent diagnostic results on 1A-09 (PTD 1811520). This well has a failed MITIA (Sundry approval 303-307) that was assumed to be a packer or casing leak as an MITT wmp passes. The leak rate was too slow to identify the depth with known logging tools. A new ultrasonic leak detect logging tool (tecwel) was ran in the well on 10/8/05 and identified the leak depth at 2574'. I reviewed the 303-307 sundry for the failed MITIA and didn't see any issues. CPAI has determined this well no longer meets our internal requirements and the well has been SI. The leak is in close proximity to the OA cmt shoe and the OA shoe leaks. At this time, it is uncertain when or how the well will be repaired, but the appropriate sundry will be submitted at that time. Tecwel can measure leak rates down to something around a quart or cup per minute. Three other wells with small leaks were logged successfully. Marie McConnell Problem Well Supervisor 659-7224 20f2 3/6/200610:18 AM 3M-27 and 30-19 e þ~""ùY' . >, _ .."..."'....................,..'.'.....".~........'0. ' _'¡:"_>~~';:-f:~:-:' - ." .--__- Subject: 3M-27 and 30-19 ¡¡'rom: NSK Problem Well Supv <nI617@conocophillips.com> Date: Mon, 26 Scp 2005 13:41:12 -0800 To: bob _fleckenstcin@admin.statc.ak.us Bob, The 10-404's submitted for 3M-27 and 30-19 were for conductor "Top Ofts". Can you make corrections accordingly and we will be more specific in the future. Thanks, Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 SCANNED NOV 03 2DD5 1 of 1 9/27/20058:07 AM ... e e STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1, Operations Performed: Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Other [2]-rt:Jr --J- ßð/ Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Time Extension g9~ Change Approved Program 0 Operat ShutdownO Perforate 0 Re-enter Suspended Well 2, Operator Name: 4, Current Well Status: 5, Permit to Drill Number: ConocoPhillips Alaska, Inc, 0 0 ... , Development Exploratory 3, Address: Stratigraphic 0 Service [2] 6, API Number: p, 0, Box 100360 50-029-22753-00 7, KB Elevation (ft): 9, Well Name and Number: RKB 65' 30-19 8, Property Designation: 10, Field/Pool(s): Kuparuk River Unit Kuparuk River Field 1 Kuparuk Oil Pool 11, Present Well Condition Summary: Total Depth measured 9415' feet true vertical 6823' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SURF, CASING 5285' 7-5/8" 5350' 4024' LINER 4287' 4-1/2" 9407' 6816' Perforation depth: Measured depth: 9072'-9068',9100'-9120',9191'-9201' true vertical depth: 6554'-6565',6576'-6592',6647'-6655' Tubing (size, grade, and measured depth) 4-112" , L-80, 5120' MD, Packers & SSSV (type & measured depth) pkr= BAKER 'SABLM/ZXP'; HES PACKER 2.313 X 2,205 XN NIP SET 8/9/2002 pkr= 5120'; 8928' SSSV= NIP SSSV= SOT 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS 8Ft SEP 2 6 20D5 Treatment descriptions including volumes used and final pressure: 13, Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation SI 0 0 Subsequent to operation SI 0 0 14, Attachments 15, Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory 0 Development 0 Service [2] Daily Report of Well Operations _X 16, Well Status after proposed work: OilO GasO WAG 0 GINJO WINJ[2] WDSPL 0 17, I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Marie McConnell/MJ Loveland @ 659-7224 Printed Name ~~rie McConnell .Jd/7 ...../ ~ Title Problem Wells Supervisor Signature ~j/~/A"': ~ ,¿#," y, ~". 0 Phone 907 -659-7224 Date 9/16/2005 '7 . %. ~'l' fl'l ~ð//.. /, Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only e , 30-19 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 9/14/2005 Top off conductor with corrosion inhibitor/waterproofing sealant. Circulated 10 BBLS 125 deg F fresh water at 0,7 BPM down existing conductor hose to cmt top, Conductor TOC @ -3.3ft from conductor top. Vac'd water from cellar to TOC, Pumped 7 gallons of 2401 film coating corrosion inhibitor at 111 deg F, switched products and pumped 13.5 gallons of ROYFILL 404- B corrosion inhibitor filler at 118 deg F, ¡¡it) \. r\ t; \ t:::/~ ~ STATE OF ALASKA . C~I ~" ALASKA OIL AND GAS CONSERVATION COMMISSION " AUG 2 6 I·~""o REPORT OF SUNDRY WELL OPERATIONS¡~#['10¡!& 2005 Abandon D Repair Well 0 Plug Perforations D Stimulate D Other 4:',':: Ôn3. Ca"h . A"{,Pðl!J°' ,q'{18!$S:' Alter Casing 0 Pull Tubing D Perforate New Pool D Waiver D Time Extension Bge ' .ðOl] Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development D Exploratory D 197-050 3. Address: Stratigraphic D Service 0 6. API Number: P. O. Box 100360 50-029-22753-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 65' 30-19 1. Operations Performed: ) ') 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURF. CASING LINER Perforation depth: measured 9415' feet true vertical 6823' feet measured feet true vertical 6276' feet Length Size MD 121' 16" 121' 5285' 7-5/8" 5350' 4287' 4-1/2" 9407' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 4024' 6816' Measured depth: 9072'-9068',9100'-9120',9191'-9201' ,<;;';;«'"" ¡ ¡d\.H~U ~ f': :1 ¡ ! G. ~:,)I fD 1') 0 (p::- o;o¡¡l:W'Q""M't"M"iJIi."",-, nU ~ (. ,) U '- ",I~j true vertical depth: 6554'-6565', 6576'-6592', 6647'-6655' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 5120' MD. Packers & SSSV (type & measured depth) pkr= BAKER 'SABLM/ZXP'; HES PACKER 2.313 X 2.205 XN NIP SET 8/9/2002 pkr= 5120'; 8928' SSSV= NIP SSSV= 50T 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mef Water-Bbl CasinQ Pressure TubinQ Pressure Prior to well operation SI 0 0 Subsequent to operation SI 0 0 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development D Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 305-159 Contact Marie McConnell/MJ Loveland @ 659-7224 Ma,rie Mcconn, ell '" ' "', A' //Title Problem Wells Supervisor Signature~~ø /' ø~~ K\nG \ N A ,:7;~~~ Date 8/21/2005 Form 10-404 Revised 04/2004 Y ;X¡S~rig~ Printed Name ) 30-19 DESCRIPTION OF WORK COMPLETED SUMMARY ) Date Event Summary 7/8/2005 Cut top 2.5' off conductor. Removed cement and exposed 7-5/8" casing. Found externally corroded casing with a pin hole leak 14" below bottom of csg mandrel hanger as shown in Photo #1. John Crisp witnessed casing damage. 8/6/2005 Cut and removed an additional l' of conductor for a total of 3.5' of conductor removed. Removed cement and exposed an addition l' of casing for inspection to determine the required patch length. 8/14/2005 Seal welded top casing threads to casing hanger mandrel bottom. Seal welded top collar to casing pup. Installed external surface casing sleeve patch over corroded casing from seal weld to seal weld. Patch was a 27" long section of 8", X65 pipe, split and welded to surface casing across corroded casing as shown in Photo #2. Patch design drawing also attached. 8/17/2005 MITIA to 3000 psi passed. See attached MITIA report. This MITIA was done to verify patch integrity only as tbg plugs for welding work were still in place both above and below the packer. 8/21/2005 Installed denso corrosion resistant coating on the patch and exposed surface casing. Patched conductor. Installed hose in conductor for upcomming top job. I ~.-<, -' , , ;~,,"q ~, N I ' , ,.:' ~ ,"'i : II¡¡ __,' j, ~: ~ I 1 ...~.\ .,~ '''''"~ ' Ii , ". \ j¡ J~i""~"~) f ,,( -. ~.~, ~~~.I ",œ\,! I ,.....d,.!'.!! n~. Photo 1: 30-19 External corrosion damage of7-5/8" casing 07-08-05 . .~, '~tr~'1¥~"::;2,r' .:'.', ".:':: ...... ~.:'~. r ¡U)li< ~'1t· r~~ ,~,"'If( '.::.' ," I',',·' .1 i:' r r 11. -"j 11'1 , 1,1,. .,,' ,',I", I ~ ,1 r:' I ,fl1 II" 1'¡ltf" I'~II,I'II" '''1,': Ii ',lk,l" ~II' ,.1:' , "', 't 11"'~ 1/1,,1 I ' I' 'I" 01, "I '.," "" ¡" ¡... I f Lh ,I: I, J¡- I I~J¡i!~ ¡ ,:111:11, :'':' ,hl' 1':,11,:,1111: :'1; ,J~" 11,11;1 ;1, I .: I ~ I ". i' : 'I, '1'1I ' :, " . " 1111' i' . I' : ,,' 'I' , ~ I... "'~. !~I"1,11; Ilì JJ:, :1 ~,Jjll.~ 1,.~II,I',1 :11:¡'I:·}II.I'II~,I,I".lill,":"" ,III,'ht,'II,II,;'it¡ !I:I .. . ·¡f·\ . I r I ,~j" 'Ill 'I!I I :'II,I¡'I"!::II' ',.' 'I ::IiIW'¡" :111' b~~:tI.).!. ,I, .,1 1 :' il.~i. I' "'lLjj "1. ',!h, 1,1 II:, Jill ',: ':: ,," ¡,,:fi, ','.:1'.'" ~~ ~:'...~.....:r_-m-prr..;II.· . '"r:;'ã..-!!'..-:J, '-;,ïJ':'-JL ~Tili'.-.Ir~"",.IIJ"'"''''''' ¡¡¡;1..¡:~·..m:I';';'.i.:"~»'-"~~'· Photo 2: 30-19 Completed casing patch 08-18-05 ') Subject" I' ." ;;iÞ I.tt r t t:I £~ Co S. I' "tj ~ I ~ e 1./ e File f.) S :3 r¥ -21/0.5 30 -.19 I By ~h;'i:;;¿lI'¿), ·§;eo/ weld the lÁ~ðds 7úb¡n1/~~/"'~ at the ¡)40Jlldrl"¡:i Lo/lor fY1a/1dri / (2 u.X:,Jd ~sses) /-"~ ~ / / skev~ / // . ¡::j'i; -5 /~ LIe. b l;;e I t!A. ~ . . Into th~ '=oe bf I ~/~/ fA e Set;Ä; I l.Ve I d / /0 D ~ h,r {3o tÁ tl1e. M4ndrí / ~ ~ .f Co I/a r 5 /e~ IJ~ lJÆ)¡S / ~ / / / I' / / / ,/ / ,I / I / ~ / ¡1. <~ I ~ a £x/sb:', /' / . c;.cts/~j / ~~ Lo/IQr ~ / · ?re -1Ie~ I the J1h;fdr¡ / , ~ Co//t::;r iô tile $~~ reg 'J'Yl t.$. C/ S éCl5/';tJ lie 0 d h,r 5e& I t¿e Ij¡~ · G,rDo ve we Id a'¿ both eJ1ds of the '5 lee ve &v Y1/I4t¿ h S lee ve t¡"II'~ hne~ s ~ I, · Ca'S/"(J /5 7 /9 ().D (Á Se 8" ApI SLX- X¿'S II é), "375 t¿! o. $7Jr.)" Un:; / / p/I'e ¡; r i4e sl¿:et/e- ~ a.L. PRINTING (907) 563-4743 : I I -t- - t r I I t , ) Sheet number Calculations Chart .t of 1- 7/.17/ðS- Date ,.027/1 WI I I µ I I I I I I MECIi~~ICAL INTEGRITY TEST (MI. )FORM WELL NO.: 130-19 I DATE: 18-17-05 WELL TYPE: ISWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITIA I i.e., Tbg, IA 19-5/8", OA 113-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 13000 I psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel T START TIME: 11630 E S T Record all Wellhead Pressures before and durinq Test. PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** 1500 1700 1700 1700 o 3000 2900 2890 TUBING IA OA 1 COMMENTS: T START TIME: E S TUBING T IA / 9-5/8" OA /13-3/8" 2 COMMENTS: T START TIME: I E S TUBING T IA / 9-5/8" OA /13-3/8" 3 COMMENTS: MISC COMMENTS: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI)* (PSI)** PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE I PRESSURES PRESSURES PRESSURES PRESSURES (PSI) (PSI) (PSI) (PSI) PASS OR FAIL PASS PASS OR FAIL PASS OR FAIL * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! m -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION m -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. m -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. W.t 10. Sauvageau / B. Rogers I ness: cc: PWS 6/3/00 1 &part= 1.3&. 1001813 i?'"'7~·3.$... ()6 mailbox:1 1 IFl/email/defau1t/MaiVancmail1.state.ak.us/lnbox?number= (JPEG Image, 2304x1728 pixels) KRU _ 30-19 _ surC csg_repaír _2005-0727 jc.1PG \C; ~ -OS- D o-.t.. \ J? \..cA Co Co '" .' \),)E. \~.: ~t\..re - / 7/28/20059:35 AM '- ~ ~- _..~- 9 2005 2 SCÁNNED JUL ~-- "-'B'¡ec'-~", _, . >C-~-l.t-¿ , :i, ri't " '.. "~ :~<~'~;~, :,'.. ~ l:)ji,t.;f or C of ') ) /9?-'&5u /111 f-r I¡ II iUÞ, I~' I' , \' I ' '.;..J I ¡ / / ¡ FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AlO) GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jerry Dethlefs Pro blem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska ..~,'~_ 2 ?o (\ ~f SCANNED JtH ~ L Re: Kuparuk 30-19 Sundry Number: 305-159 Dear Mr. Dethlefs: 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 holiday or weekend. A person may not appeal a Commission decisio to) Superior Court unless rehearing has been requested. DATED iliis4 day of July, 2005 Encl. ) ConocJPhillips Alaska ') P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 E ,¡p"'''\ E ""'" ...LJ' ~'VED JUt {} X Z005 l~i~;~~ska Oil & Ga!,~ Coni). Commission June 30, 2005 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 30-19 (PTD 1970500). The approval request regards a repair for a surface casing leak. Please call Marie McConnell or MJ Loveland at 659-7224 or me at 659-7043 if you have any questions. Sincerely, ~. /c~ Jerry Dethlefs Problem Well Supervisor Attachments OR\GiNAL 1. Type of Request: Abandon STATE OF ALASKA R'·"! E ,",," ALASKA OIL AND GAS CONSERVATION COMMISSION- (.ill E "IE APPLICATION FOR SUNDRY APPROVAL ¡u¡ 0 ';( Z005 20 AAC 25.280 ,. - 1 o Suspend 0 Operation Shutdown 0 Perforate []Uask~ Oi~ 8!~Flt'@COn:UOnl'ñ',~~~~fc!~sP. 0 o Repair well 0 Plug Perforations 0 Stimulate 0 Timekxtêhslé'áì[j[] Other 0 o Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 ) ) *ï I Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 65' 8. Property Designation: Kuparuk River Unit 4. Current Well Class: Development 0 Stratigraphic 0 Exploratory 0 o Service 5. Permit to Drill N!:!.r:nber: 197 -050 v' 6. API Number: -/ 50-029-22753-00 9. Well Name and Number: 30-19 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 9415' 6823' Casing Length Size CONDUCTOR 121' 16" SURF. CASING 5285' 7-5/8" LINER 4287' 4-1/2" 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): MD TVD Burst Collapse 121' 121 ' 1640 psi 670 psi 5350' 4024' 6890 psi 4790 psi 9407' 6816' 8440 psi 7500 psi Perforation Depth MD (ft): 9072'-9068', 9100'-9120', 9191 '-9201' Packers and SSSV Type: pkr= BAKER 'SABLM/ZXP'; HES PACKER 2.313 X 2,205 XN NIF SSSV= NIP Perforation Depth TVD (ft): 6554'-6565',6576'-6592',6647'-6655' Packers and SSSV MD (ft) pkr= 5120'; 8928' SSSV= 507' Tubing Size: 4-1/211 Tubing Grade: L-80 Tubing MD (ft): 5120' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for 7/8/2005 Date: 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Service 0 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 ~ Dethlefs Signature 7 ~ -./ L O~ Commission Use Only Plugged 0 WINJ 0 Abandoned D WDSPL 0 Contact: Title: Phone 659-7224 Jerry Dethlefs Problem Well Supervisor Date ~/27'/Ó..r- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: .:3~ 5 - (l~? Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other "'O\'\~\ 1:."'~~~c..\.c~ \>,.)~~ \~\... \oco...~~<t.'{ f?O~~ . eq ir /: L\ ). ("...(... \~ \ .......~ Ç> "'0 \a ~() ~U "'t........ '\0. \-\tI..... O~ \ <tdL ~ ~~, r 7~'1 RBDMS BFL JUL 1 i 1005 11~ ( BY ORDER OF COMMISSIONER THE COMMISSION Date: INSTRUCTIONS ON REVERSE 0 RIG I N A L Submit in Duplicate ) ) ConocoPhillips Alaska, Inc. Kuparuk Well 30-19 (PTD 1970500) ~~/,'ii1:~.' l'I'~'fÞ ~ ;ß'!.1I~ tf""'" 1''''·- ßC:: JUL 0 1 2005 SUNDRY NOTICE 10-403 APPROVAL REQUEST i~J~S¡Œ Oil i& 06/29/05 This application for Sundry approval for Kuparuk well 30-19 is for the repair of a surface casing leak. The well is a monobore completion that is designated as a water only injector, completed in April of 1997. On August 4, 2003, liquids in the conductor were observed while attempting to perform a State witnessed MIT -IA. The AOGCC field representative on location was Chuck Scheve, notification was also sent on 8/04/03. The well was immediately plugged until diagnostics could be performed and remains secured until the casing is repaired. On 11/09/03 diagnostics were performed to locate the leak. After clearing out some unconsolidated cement from the top of the conductor, the leak site was determined to be approximately 2' below the conductor top. The location of the leak being very near the surface will expedite and simplify the repair process. 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 the floor grate and equipment from around the wellhead. 4. Install nitrogen purge equipment for the IA 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 4-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 ~ li\e casing to operational integrity. 7. QA/QC the repair and MIT -IA 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 material designed to seal out water and oxygen. 10. Backfill as needed with gravel around the wellhead. 11. Remove plugs and return the well to production. 12. File 10-404 with the AOGCC post repair. OR\G\NAL ) .1t:~~.. l¡¡¡\;~¡fi¡:¡;;;¡:¡.j.J\ ConocoPhillip·s Alaska toe \~~,":""""":""':'¡11 ... : . .. ... .... : " .. ... · . ...' .. :, .. ~ ~ . 30~9 PLUG (507-503, 00:3.810) TUBI NG (0-5120, 00:4,500, 10:3.833) PLUG (5068-5069, 00:3.810) SLEEVE (5068-5069, 00:4.500) PKR (5120-5121, 00:7.000) LINER (5120-9407, 00:4.500, Wt:12,60) NIP (8729-8730, 00:3.833) PKR (8928-8929, 00:3.958) Perf (9072-9036) Perf (9100-9120) Perf (9191-9201 ) J ~ j ~ ~ ~ ì ~ ~ 1 ,tics ;.-..:::.' ,...... :'.?:o:' =1 API: 500292275300 SSSV Type: NIPPLE Annular Fluid: Reference Log: LastTag: 9262 Last Tag Date: 2/9/2001 Casing String - ALL STRINGS Description CONDUCTOR SURF. CASING LINER Tubing String. TUBING Size Top 4.500 0 ) KRU Well Type: INJ Orig Completion: 4/8/1997 Last W/O: Ref Log Date: TO: 9415 ftKB Max Hole Angle: 56 deg @ 2509 Size 16.000 7.625 4.500 Top o o 5120 Bottom 121 5350 9407 TVD 121 4024 6816 30-19 Angle @ TS: 39 deg @ 8942 Angle @ TO: 38 deg @ 9415 Rev Reason: SET PLUGS Last Update: 918/2004 Wt 62.50 29.70 12.60 Grade H-40 L-80 L-80 Thread Other (plugs, equip., etc.) - JEWELRY Depth TVD Type 507 507 NIP 507 507 PLUG 5068 3841 SLEEVE 5068 3841 PLUG 5120 3875 PKR 5461 4098 PATCH 8729 6294 NIP 8928 6443 PLUG 8928 6443 PKR Géhérå(N6te.¡{ .. Date Note 6/4/2001 LEAK found @ 5475' MD 11/9/2003 LOCATED HOLE IN 7 5/8" SURFACE CASING 2' BELOW ANNULUS VALVE. Interval 9072 - 9086 TVD 6554 - 6565 9100 - 9120 6576 - 6592 9191 - 9201 6647 - 6655 Zone Status Ft SPF Date Type A-3 14 6 4/13/1997 IPERF A-2 20 6 4/13/1997 IPERF A-1 10 6 4/13/1997 IPERF Description Cameo 'DB' Nipple NO GO 3.81" DB LOCK W/PX PLUG set 9/7/2004 Baker 'CM' Sliding Sleeve; Closed 9/10/97 XX PLUG set 9/7/2004 Baker'SABLMIZXP HES 3,8" 00 PATCH 24.8' LONG W/2.375" 10 SET 8/9/2002 Cameo 'DB' Nipple NO GO PLUG set 8/18/2002 HES PACKER 2.313 X 2.205 XN NIP SET 8/9/2002 Comment 3-3/8" HSD Csg Gun; 60 deg phasing 3-3/8" HSD Csg Gun; 60 deg phasing 3-3/8" HSD Csg Gun; 60 deg phasing ID 3.813 0.000 3.813 0.000 3.812 2.375 3.750 0,000 2.313 V",1'~~l+ i~ .t"~" \~.. 'tn ""' ì""'t' t:'-', . l" /' ,.~~, ~ \.lL_ \.,,¡? t:: ~ \/ t:: ni! ð¡ JUL 0 : 2005 ORIGINAL MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM' Randy Ruedrich DATE: August 4, 2003 Commissioner --z ~ ~\¢)~SUBJECT: Mechanical Integrity Tests T-~:p,-Maueder E? ~ ~1/', Conoco Phillips P.I. Supervisor \"'+' ~..\ 30-19 KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I30-19IType,nj.IN I T.V.D. 13857 ITubingl 100013050 I,nte va, I V P.T.D.I 197-050 TypetestI P ITestpsil 964 I Casingl 100I 200 I 200I 200I P/F I E Notes: Tubing test, Additonal 30 minutes showed steady loss of 150 psi per 15 minutes WellI 30-19 [Typelnj.I N I T.V.D.I 3857 ITubingl 1100 I I I Ilntervall V P.T.D.I 197-050 TypetestI P ITestpsil 964 I Casingl 200 I 1700I 500I I R/F I E Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: IWe"I P.T.D.I Notes: casing test, fluid surfaced in cellar Type Inj. Type test IType Inj. Type test IType Inj. Type test 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 I traveled to Conoco Phillips 30 Pad in the Kuparuk River Field and witnessed the semi-annual MIT on well 30-19 as required by variance. This well is a monobore injector. A plug had been set in the tubing at 8928' with the top perf at 9072'. A patch had been installed in the tubing at 5461 in an attempt to repair a known leak. Attempts to pressure test the tubing failed, showing a steady pressure loss of 150 psi per 15 minute period. An attempt to pressure test the 7 5/8" X 4 1/2" annulus also failed with a pressure decline of 1200 psi in 15 minutes and diesel surfacing in the cellar. The well was left shut in with the plug still in the tubing. M.I.T.'s performed: 1_ Number of Failures: 2 Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. 2003-0804_MIT_KRU_30-19_cs.xls 8/15/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 65 feet 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service~X Kuparuk Unit 4. Location of well at surface 8. Well number 907' FNL, 3330' FEL, Sec. 22, T13N, R9E, UM (asp's 525584, 6021910) 30~19 At top of productive interval 9. Permit number / approval number 1080' FNL, 337' FWL, Sec. 27, T13N, R9E, UM 197-050 / At effective depth 10. APl number 50-029-22753 At total depth 11. Field / Pool 1356' FNL, 5030' FEL, Sec. 27, T13N, R9E, UM (asp's 523914, 6016175) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 9415 feet Plugs (measured) true vertical 6823 feet Effective depth: measured 9262 feet Junk (measured) true vertical 6702 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 304 sx AS I 121' 121' SURF. CASING 5285' 7-5/8" 344 sx ASLW, 439 sx Class G, 60 5350' 4024' LINER 4287' 4-1/2" 340 sx Class G 9407' 6816' Perforation depth: measured 9072'-9086', 9100'-9120', 9191 '-9201' true vertical 6554'-6565', 6576'-6592', 6647'-6655'J E EIVED Tubing (size, grade, and measured depth) 4-1,2", 12.6#, L-80 Tbg @ 5120' MD. NOV 1 2'2002 Packers & SSSV (type & measured depth) BAKER 'SABLM/ZXP' @ 5120' MD. A~a~ 011 & Gas ~0ns, C0mmissior, Anchorage CAMCO 'DB' NIPPLE NO GO @ 507' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1200 - Subsequent to operation NA - 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _Water Injector /~ 17. I hereby ce~ify that the foregoing isLrue and correct to the best of my knowledge. Signed ~/'~¢¢E~ ~,¢~~ Title Problem Well Supervisor Date ///~?~////~'~-- ~' Jerald C. Dethlefs ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE Phillips Alaska, Inc. Kuparuk Well 30-19 (PTD 1970500) SUNDRY NOTICE 10-404 11/08/02 On 02/10/01 an IBP was set in the well for performing an AOGCC required MIT; the test failed. Diagnostics and leak detect logging (Borax/PNL) found a leak in the monobore casing/tubing @ 5475'. The leak was to be repaired before water injection could commence in the well. In addition, the existing landing nipple is set too high (343' md, 260' tvd) to meet AOGCC criteria for testing (< 200' from perforations). A new landing nipple was to be set on a packer within the 200' tvd interval so that standard wireline-set plugs may be used for MIT testing. The following events transpired to satisfy the terms of the Sundry approval: 08/09/2002: RUN HALCO. RETAINER- SET @ 8930- W/2.205" NO GO NIP. FOLLOW W/ HALCO. PATCH TO BE SET ACROSS COLLAR @ 5475'. PATCH RUNS FROM 5464.77' - 5485.61' CELMD. PACKER PUMPED DN TO DEPTH-- W 1 BPM INJECTION FLUIDS--- WELL LEFT SHUT IN-- STBY FOR MIT. POSITION PACKER @ 8911.6-- CCL TO ELEMENT 18.4 -PACKER ELEMENT DEPTH 8930-- FIRE SETTING TOOL--- GOOD INDICATION .... POOH POSITION PATCH @ 5444.7 - CCL TO TOP ELEMENT 20.0 FT- PATCH SET @ 5464.7 TO 5485 .....FIRE SETTING TOOL ..... GOOD INDICATION ..... POOH 08/19/2002: SET 2.31" XN PLUG @ 8930' RKB. MIT'd TBG 3000 PSI, OK. WELL READY FOR MIT. 08/23/2002: MIT-T - marginal pass, T/I - 1050/650 pressure up Tubing with diesel to 2500 psi, 15 minute reading T/I=2300/700, pressure up tubing to 3000 psi, 15 minute reading T/I= 2825/750 pressure up tubing to 3500 psi, 15 minute reading T/I= 3350/800, 30 minute reading T/I=3200/780 It appears the leak was not fully sealed by the patch. Diagnostics are in progress; the patch may need to be pulled and ran again. NSK Problem Well Supervisor 11/08/02 of PHILLIPS PETROLEUM COMPANY NIP (507-508, ~ OD:4.500) (0-5120, 0D:4.500, ID:3.833) SLEEVE (5O68,5069, 0D:4.500) PKR (5120-5121, OD:7.000) LINER (5120-9407, 0D:4.500, Wt12.60) KRU 30-19 APl: 1500292275300 Well Type:I INJ SSSV Type:I NIPPLE Orig 14/8/1997 I Completion:I Annular Fluid:I Last W/O:I Reference Log:I Ref Log Date:I Last Ta~1:19262 TD:19415 ftKB Last Tag Date:12/9/2001 Max Hole Angle:156 deg (~ 2509 Angle (~ TS:139 deg @ 8942 Angle @ TD:I38 deg @ 9415 I Rev Reason:lSat plug by ImO Last Update:18~29~2002 Description I Size i Top Bottom TVD J Wt I Grade I Thread CONDUCTOR I 16.000 0 121 121 162.501 H-40 I SURF. CASING 7.625 0 5350 4024 I 29.70 ] L-80 I LINER 4.500 5120 9407 6816 I 12.601 L-80 J :T~bihgSt~hg~:TUB!NG: :::. :::: ' Size I Top I Bottom I TVD Wt I GradeI Thread 4.500I I IO 5120 3875 12.60 I L-80 I NSCTR-2 P~:rforati:~ S~a~;: ::: Interval TVDIZone IstatusI~t laPelDate I TypeI Comment 9072-9086 6554-6565 I A-3 I 1~41 6 14/13/1997J IPERF ]3-3/8" HSD Csg Gun; 60 I I I I I I Ide9 phasin~ 9~00-9~20 657~-~592 I A-2 I I 20 I 6 I./~3/~99711PERF 13-3/8" HSD Csg Oun; 60 J J J J ] ] Ide9 phasin9 ~-~20~ ~-~5 I A-~ I I~°1 ~ 1~/~71~ER~p-~"HSDC~gG~":~0 I I I I I I Ideg phasing Depth ~TVD ~ Type Description ID 507 [507 ~ NIP Camco'DB' Nipple NO GO 3.813 5068 J3841 J SLEEVE Baker'CM' Sliding Sleeve; Closed 9/10/97 3.813 5120 ~3875 ~ PKR Baker'SABLM/~P' 3.812 5461 J4098 ~ PATCH HES 3.8" OD PATCH 24.8' LONG W/2.375" ID SET 8~9~2002 2.375 8729 ~6294 ~ NIP 'Camco 'DB' Nipple NO GO 3.750 2.313 8928 ~6443 ~ PKR HES PACKER 2.313 X 2.205 XN NIP SET 8/9/2002 8928 ~6443 ] PLUG 2.313" XN PLUG SET IN PKR 811912002 0.000 Note LEAK found, 5475' NIP (8729-8730, 0D:3.833) PKR (8928-8929, 0D:3.958) Per[ (9072-9086) Per[ (9100-9120) Per[ (9191-9201) Re: Kuparuk 30-19 Patch Subject: Re: Kuparuk 30-19 Patch Date: Mon, 29 Oct 2001 10:59:19 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: NSK Problem Well Supv <n1617@ppco.com> Yes, Jerry I will. It is all but done, but I need to write a little bit of text to satisfy a request in here. Tom NSK Problem Well Supv wrote: > Tom: I finally got word from Halliburton the patch and packer/landing > nipple assemblies have arrived for Kuparuk well 30-19 (monobore). We will > be scheduling the work to be done soon, possibly this week. I have not yet > received the approved 10-403 for this work. Do you think you can get that > approval out to me? Thanks/. > Jerry Dethlefs > Phillips Problem Well Supervisor Sr. Petroleum Engineer t Alaska Oil and Gas Conservation Commission 1 of 1 2~7~02 1:51 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program_ Pull tubing _ Variance _X Pedorate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 907' FNL, 3330' FEL, Sec. 22, T13N, R9E, UM At top of productive interval 1080' FNL, 337' FWL, Sec. 27, T13N, R9E, UM At effective depth At total depth 1356' FNL, 5030' FEL, Sec. 27, T13N, R9E, UM 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service__X (asp's 525584, 6021910) (asp's 523914, 6016175) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Kuparuk Unit 8. Well number 30-19 9. Permit number / approval number 197-050 10. APl number 50-029-22753 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summar Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 121' SURF. CASING 5285' LINER 4287' Size 16" 7-5/8" 4-1/2" 9415 6823 9262 6702 feet Plugs (measured) feet feet Junk (measured) feet Cemented 304 sx AS I 344 sx ASLW, 439 sx Class G, 60 sx AS I 340 sx Class G Measured Depth 121' 5350' 9407' 6816' True vertical Depth 121' 4024' Perforation depth: measured 9072'-9086',9100'-9120',9191'-9201' true vertical 6554'-6565', 6576'-6592', 6647'-6655' Tubing (size, grade, and measured depth 4-1/2", 12.6#, L-80 Tbg @ 5120' MD. Packers & SSSV (type & measured depth) BAKER 'SABLM/ZXP' @ 5120' MD. CAMCO 'DB' NIPPLE NO GO @ 507' MD. RECEIVED JUN 2. 7 2001 Alaska 0i! & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation [ 15. Status of well classification as: June 11,2001 I 16. If proposal was verbally approved Oil __ Tom Maunder 6/11/01 Name of approver Date approved [ Service 17. I hereby certify that the foregoing is true and correct to the best o! my knowledge. SignedJera/d'-~-"'~~------'-C. Deth/efs ~~ Title: Problem Well Supervisor FOR COMMISSION USE ONLY Gas __ WAG Suspended__ Questions? Call Jerry Dethlefs 659-7224 · Conditions of approval: Notify Commission so representative may witness,~ I Appr°valn°,"~//'-/x'~ .~ Plug integrity __ BOP Test _ Location clearance _ , - Mechanical Integrity Test _.~ Subsequent form required 10- . , ~ 'Oommissionor Approved b~ order of the Commission ' " ORIGINAL SIGNED Form 10-403 Rev 06/15/88 · Return to: Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 30-19 SUNDRY NOTICE 10-403 VARIANCE REQUEST 06/23/01 The purpose of this Sundry Notice variance request is twofold; for approval to patch repair the monobore casing/tubing to stop a leak, and to clarify Mechanical Integrity Test (MIT) requirements for the 30-19 monobore completion. The requirements were determined in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 2001. The terms for future MIT's modify and supersede the conditions sent in a letter to ARCO Alaska, Inc., from the AOGCC (Blair Wondzell) dated May 2, 1997. Kupamk well 30-19 is a monobore injection well classified as a "failed MIT" due to the construction of the wellbore (i.e., the packer is not set within 200' of the perforations). Extensive portions of the casing/tubing cannot be monitored from the surface so communication or leak problems may go undetected. On 02/10/01 an IBP was set in the well for performing an AOGCC required MIT; the test failed. Diagnostics and leak detect logging (Borax/PNL) found a leak in the monobore casing/tubing @ 5475'. The leak must be repaired before water injection may commence in the well. In addition, the existing landing nipple is set too high (343' md, 260' tvd) to meet AOGCC criteria for testing (< 200' from perforations). A new landing nipple will be set ona packer Within the 200' t~ interval so that standard wireline-set plugs may be used for MIT testing. See the attached --o."~ proposed patch and landing nipple setting procedure. Approval of the patch and landing-nipple plans are required prior to repair of the well. The repair will provide the mechanical integrity necessary for water injection to commence. Approval of the MIT testing requirements will specify future AOGCC expectations for mechanical integrity. ACTION PLAN From this date forward 30-19 will be subject to the following requirements: 1. After receipt of approval from the AOGCC set the landing nipple and packer, then set the tubing/casing patch. See the attached proposed procedure. 2. Perform an AOGCC witnessed MIT-tubing to the new landing nipple @ 8930' md (6278' 3. Commence water-injection only (no gas injection allowed); 4. Perform an MIT-IA every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); Submit monthly reports of daily tubing & IA pressures and injection volumes; Shut-in the well and notify the AOGCC should M1T's or injection rates and pressures indicate communication problems. visor 06/23/01 General Well Work Request Form Well: ...3...O....Z.1...9' .......... Type (inj/prod)..[.n.j ...... Date: 6/15/01 From: Phone/Pnge 7224 / 909 DSE: McConnell/Petash GWWRvl 1 .~.~ klm 11/OS/DO Well Naint:. ~',1 C..h..e.c...E....A...F...C.. Job Scope: [ Tubing/Casing Pat:ch ~ ............ Distribution Paper E-mail Wells (2) PE Supv. DS Lead DSE ATO-370 Wells Supv. Proc Bk CPF Supv. Budget Category: Capital or Expense: ...E..x..~.~.n...s..e. Property Code/AFC: 230DS36OL/K85329 Estimated Cost: NOB: Job Types: Slickline E Line Coil Tubing Other Run Dummy Gun/Patch ,e,J [RA Tracer Log ~ lRemove Zce Plug I~1 [Gauge Tbg I~1 ~ 'l Justification Monobore injector requires State MIT every 2 years. Existing NoGo nipple @ 343 ft above top ped. State requires test plug to be set at a maximum 200 ft above the top perfs. Previous test identified leaking collar at 5475 ft. Cost for setting additional nipple on a packer for future SL use is approximately the same as one-year of an Eline IBP. Describe the objectives of this job and order of importance: Set a packer with a 2.25" nipple at 8930 ft (142 ft above the top perfs), Set a retrievable patch across the leaking collar at 5475 ft. Procedure $1ickline: Eline: $1ickline: Drift to 9072 ft (top of perfs) with a 3.72" x 10' dummy packer Drift to 5550 ft with a 3.78" x 15' dummy patch Set a Halliburton Perma Series production packer (3.72" OD, 2,375" ID) with a 2.25" nipple threaded on t~ bottom of the packer @ 8930 ft (142 ft above the top of perfs). Reference log SWS CBL 4/13/97 Set a Halliburton DWP 4-1/2" retreivable patch (10 ft) across the collar at 5475 ft. Set depths 5470-5480' Reference log RST Borax Leak Detect log 6/4/01. Set a TrP in the 2,25" nipple at 8972 ft, MIT - pressure test tubing to 3000 psi for 30 min. Needs to be witnessed by AOGCC - contact PW$ x7224 Pull 1-rP post MIT PHILLIPS Ala l(a, Inc. A Subsidiary ol= PHILLIPS PETROLEUM COMPAHY NIP (507-5O6, -- OD:4.500) TUBING -- (0-5120, OD:4.500, ID:3.833) KRU 30-19 SLEEVE -- (5068-5O69, OD:4.500) SURF. -- CASING (0-5350, OD:7.625, Wt:29.70) PKR -- (5120-5121, OD:6.151) LINER (5120-9407, 0D:4.500, Wt:12.60) NIP (8729-873O, 0D:4.500) Perf (9072-9086) Perf (9100-9120) Perf (9191-9201) 30-19 APl: 1500292275300 i Well Type: ,' I~NJ_ Angle @ TS:139 deg_~ 8942 _SSSV_ T~vj3e:_~NIPPLE ~ _Odg C~_~tion: 4~7~i1997 ,.i---~--_-~_~(~1~-~_~!~_~3-~_(~_-~i-~4_-1_~-~__~.-~i Annular Fluid: / i _. Last W/_O~j. Rev Reason: LT~ag fill ~ ImO Reference Log~ ................ .i Ref Log Date:l Last Updat~e~6-)'~2/--2-~01-- ........ Last Tag: i 9262 ! TD: t.9415 ffKB Last Tag Date:l 2/9/2001 I Max Hole Angle:', 56 deg ~ 2509 : Casing_String - ALL STRINGS Desc~i~i-ion ......... -~ ~ize ! Top 1Bottoml TVD CONDUCTOR ~ 16.000 ~ 0' / 121 121 I 62.50 SURF. CASING I 7.625 0 j 5350 4024 ~- 29.70 -~---L-8-~ 12.60 [--C--~6--1 ....... LINER [ 4.500 5120 I 9407 [ 6816 Tubing String - TUBING ...... ~- ...... I ...... -'1'~ .... -~ Bottom / TVD I-'-~,N-~--~[--~-~I'~--] Thread 4.500 j 0 ~ 5120 .~ 3875 j_ 1~0~~8~_~ NSCT R-2 Perorations ~,~m~ .... Inte~al ~D ' ~-'~ --S~ ~'~ ~'-~-- ~ Comment 9072-9086 6554-6565 / A-3 / /14 ] 6 1411311997~lP~RF'~3-3/8"H~~;60deg / / ~ ~ ~ ~.__[phasi~g ........ 9100-9120 6576-6592 / A-2 / /20 ~ 6 /4/13/1997~ IPERFI3-3/8"HSDCsgGun;60deg /_~_ / / ~ / ~ /phasing 9191-9201 6647-6655 / A-1 / /10 ~ 6 ~4/13/1997I IPERF13-3/8"HSDCsgG~60deg / / / ~ ~ ~ ~phasing Other {plug~, e~., etc.)- JEWELRY - s07 ~C_J--'~'~P -~~~---- I'~ -~-~1 ~E~ Bake~ r~[~, Sliding Sleeve: ~ ~ --3.81~ 5120 3875 PKR Baker 'SABLM.ZXP' 3.812 8729 6294 NIP Camco 'DB' Nipple NO GO 3.750 General Notes "Date '1 Note _6/4/2001 I LEAK fo~d~ ~475' MD SENT BY:ARCO ALASKA ; 5- 1-99 ; 3:51PM ; K PS/WELLS/CNST/PROJ~ ., ARCO Alaska, Inc, Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 30-19 Monitoring Report z S O T CHOKE N A OR DATE E T % -- ---- 907 276 7542 SI DATA GAS WATER GAS C 7" 10" LIFT INJ INJ H M O AMB CSG CSG VOL VOL VOL R I D FTP FTT TEI4P PSI PSI MSCF BBLS I~ISCF $ N E 04/01 A SW 100 2867 59 -21 800S 0 0 1432 0.000 0000 0 04/02 A SW 100 2857 61 -13 800S 0 04/03 A SW 100 2850 61 -8 800S 0 04/04 A gW 100 2850 60 -11 900S 0 04/05 A SW 100 2850 58 -9 ~00S 0 04/06 A SW 100 2856 58 -4 950S 0 0 1366 0.000 0000 0 0 1358 0.000 0000 0 0 1299 0,000 0000 0 0 1347 0,000 0000 0 0 13~3 0,000 0000 0 04/07 A SW 100 2862 64 2 950S 0 04/08 A SW 100 2862 65 1 950S 0 04/09 A SW 100 2865 65 -5 950S 0 04/10 A SW 100 2867 63 -9 950S 0 04/11 A SW 100 2865 62 -8 950S 0 0 1368 0,000 0000 0 0 1354 0.000 0000 0 0 1352 0.000 0000 0 0 1332 0.000 0000 0 0 1317 0.000 0000 0 04/12 A SW 100 2866 61 -10 9508 0 04/13 A SW 100 2865 61 -16 950S 0 04/14 A SW lO0 2850 61 -13 9b0S 0 04/15 A ~ 100 2874 60 -6 950S 0 04/16 A SW 100 2870 61 2 950S 0 0 1320 0.000 0000 0 0 1308 0,000 0000 0 0 1289 0,000 O000 0 0 1363 0.000 0000 0 0 1240 0.000 0000 0 04/17 A SW 100 2808 65 6 950s 0 04/18 A SW 100 2847 64 11 950S 0 04/19 A SW 100 2848 60 8 950S 0 04/20 A SW 100 2844 58 8 950S 0 04/21 A SW 100 2845 63 3 950S 0 0 981 0,000 0000 0 0 1280 0.000 OOO0 0 0 1228 0,000 0000. 0 0 1213 0,000 0000 0 0 1215 0.000 0000 0 04/22 A SW 100 2848 65 -6 950S 0 04/23 A SW 100 2848 63 -4 950S 0 04/24 A SW 100 2805 65 -7 950S 0 04/25 A SW 100 3839 65 -5 ~50S 0 04/26 A SW 100 2837 63 -6 950S 0 0 1207 0.000 0000 0 0 1189 0,000 0000 0 0 1164 0,000 0000 0 0 1133 O.O00 000O 0 0 1128 0.000 0000 0 04/27 A SW 100 2834 61 -4 950S 0 04/28 A SW 100 2831 62 0 950S 0 04/29 A SW 100 2830 62 3 9505 0 04/30 K SW 100 2818 63 19 9508 0 0 1133 0,000 0000 0 0 1115 0,000 0000 0 0 1112 0.000 0000 0 0 1037 0,000 0000 0 Faxet ko Blair Wou4s®11, Sta~e of Alaska (276-7542) on 5;1/99. ARCO Alaslm, Inc. is a 8ubsidla~/of All~llc Rlohfletd Commny .SENT BY:ARCO ALASKA ' 3-9-99 ; 9'O1Al~I ; KPS/WELLS/CNST/PROJ+ ARCO Alaska, Inc, i" Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 30-19 Monitoring Report z s O T CHOKE N A OR 907 276 7542'# 5/ 7 -o5o DATE E T % -- ---- SI DA'I'A GAS WATER GAS C 7" 10" LIFT AMB CSG £:SG VOL VOL VOL R I D FTP FTT TEMP PSI PSI M$CF BBLS MMSCF S N E 02/01 k OI 100 4049 93 -38 450S 0 0 02/02 A GI :1.00 4039 90 -33 450S 0 0 02/03 k GI :£00 a00:l, 84 -23 450S 0 0 02/04 A GI 100 4079 9~. -30 450S 0 0 0 0.672 0000 0 0 0_033 0000 0 0 0_229 0000 0 0 1.044 0000 0 02/05 A GI 100 4071 85 .... 35 4508 02/06 A GI 100 4063 82 -36 4508 02/07 A GI 100 4066 83 -31 450S 02/08 A Gl 100 4038 66 -38 400S 02/09 A OI 100 4052 64 -45 400S 0 0,584 0000 0 0 0.356 0000 0 0 0,54]. O000 0 0 0.3o~ 0000 0 0 0.459 0000 0 02/10 A GI 100 3714 5S -43 400S 02/11 A GI 100 3780 46 02/12 A GI 100 3985 75 ~10 4005 02/13 A GI 100, 4024 94 -15 250S 02/14 A GI 100 4030 102 -15 250S 0 0.i37 00O0 0 0 0,067 0000 0 0 0.300 0000 0 0 0.464 0000 0 0 0-438 0000 0 02/15 A CI !00 4057 105 '-19 250S 0 0 02/16 A Gl 100 4072 104 -15 250S 0 0 02/17 A GI 100 4088 95 -17 250S 0 0 02/18 A GI 100 4074 97 -4 250S 0 0 02/19 A GI 10O 4069 104 -3 250S 0 0 0 0.696 0000 0 0 0.768 0000 0 0 0.797 0000 0 0 0.417 0000 0 0 0.29'9 0000 0 02/20 A GI lO0 4059 107 -7 250S 0 0 03/31 A GI 100 4071 109 -10 250S 0 0 03/32 A OI 100 4072 107 -5 250$ 0 0 02/23 A G:£ 100 4064 102 -13 250S 0 0 02/24 A G~ 100 4068 96 -14 250S 0 0 0 0,395 0000 0 0 0,572 0000 0 0 0,535 0000 0 0 0,4'19 0000 0 0 0.505 O00O 0 02/25 A GI 100 4069 109 -6 560S 0 0 02/26 A G~ 100 4062 106 -10 560s 0 0 02/27 A GI 100 4066 108 -10 560S 0 0 02/28 A GI ].00 4067 101 -16 560S 0 0 0 0,~43 0000 0 0 0.295 0000 0 o 0.605 0000 0 0 0.409 0000 0 Faxe~ to Blair Wondzell, State o£ Alaska (276-~542) c~ 3/8/99. M4R 0 9 7999 Alaska Oil & ~as Cons. Anchorage C°rn~ission PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 04/07/99 RUN RECVD 97-050 7971 97-050 CBT/GR/CCL 97-050 DGR/EWR4-TVD ~PERRY MPT/GR/RES/ROP ~/9256-9260 ~L~4031-6822 3,4 05/07/97 FINAL 05/16/97 FINAL 05/14/97 97-050 DGR/EWR4-MD ~5360-9415 97-050 MWD SRVY LR/SDERRY 0-9415 97-050 7682 ~CHLUM PDC/GR 97-050 SRVY CALC -~DRILEX 0-9415. FINAL 05/14/97 05/14/97 1 05/16/97 06/09/97 10-407 ~OMPLETION DATE @ &//~/~ DAInY WEnL 0PS R @~ /~/~ ?/ TO ~ /~ /¢2/ Are dry ditch samples required? yes ~_And received? Was the well cored? yes ~.~Ana!ysis & description received? Are well tests required?ly?s ~_~Re. ceived? ye~r-~' Well is in compliance ~ Initial COMMENTS T D BOX .... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 910' FNL, 1949' FWL, Sec. 22, T13N, R9E, UM At top of productive interval 1080' FSL, 337' FWL, Sec. 27, T13N, R9E, UM At effective depth 1302' FSL, 268' FWL, Sec. 27, T13N, R9E, UM At total depth 1363' FSL, 249' FWL, Sec. 27, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 9415 6823 6. Datum elevation (DF or KB) RKB 41 feet 7. unit or Property name Kuparuk River Unit 8. Well number 30-19 9. Permit number/approval number 97-50 10. APl number 50-029-22753-00 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 9 31 2 true vertical 6742 feet Junk (measured) None feet Casing Length Structural Conductor 8 0' Surface 5 31 9' Intermediate Production 4287' Liner Perforation depth: measured 9072'-9086', true vertical 6554'-6565', Size 16" 7-5/8" 4.5" Cemented Measured depth 304 SX AS I 121 ' 344 Sx ASLW & 5 3 5 0' 439 Sx Class G & 60 Sx AS I 340 Sx Class G 9 4 0 7' 9191'-9201' 6647'-6655' 9100'-9120', 6576'-6591', True vertical depth 121' 4024' 6817' Tubing (size, grade, and measured depth) 4.5", 12.6#/ft., L-80 @ 5120' Packers and SSSV (type and measured depth) Packer: Baker SABLM/XLP @ 5120'; SSSV: None, nipple @ 507' 13. stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 5/15/97 Intervals treated (measured) 9072'-9086', 91 00'-9120', 91 91 '-9201' Treatment description including volumes used and final pressure Pumped 98.8 Mlbs of 20/40 and 12/18 ceramic proppant into formation, fp was 3809 psi 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 700 Subsequent to operation (flowback) 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 225 232 276 700 183 16. Status of well classification as: Oil Gas Suspended Service H20 Inj 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,.~ '~~J~,~,~ Title Wells Superintendent Form 1/OZ~l.~ Re/0"13(~5"/I~!8 - - ' / SUBMIT IH DUCLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT '~' K1(30-19(W4-6)) WELL JOB SCOPE JOB NUMBER 30-19 FRAC, FRAC SUPPORT 0514972017.4 DA~-E DAILY WORK UNIT NUMBER 05/15/97 FRACTURE STIMULATE A SAND DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 1 (~) Yes O NOI (~) Yes O NO DS-YOKUM JORDAN FIELD AFC~ CC~ DALLY COST ACCUM COST Signed ESTIMATE 998670 230DS36OL $88,61 7 $88,617 Initial Tb¢l Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1317 PSI 0 PSI 329 PSI 0 PSll 0 PSll 0 PSI DALLY SUMMARY A SAND FRAC COMPLETE. 98800 LBS PROP IN PERFS, 1108 LBS PROP LEFT IN PIPE. TIME LOG ENTRY 06:00 MIRU DS FRAC UNIT. TGSM. PT SFC EQUIPMENT TO 9700 PSI OK. 08:54 PUMP BREAKDOWN AND FLUSH. ISIP 2054. 10:36 PUMP DATAFRAC AND FLUSH. ISIP 2215. 12:27 PUMP A SAND FRAC AND FLUSH. TOTAL PROP IN PERFS 98,800 LBS. TOTAL PROP LEFT IN PIPE 1,108 LBS. INITIAL TREATING PRESSURE 5630 PSI. FINAL TREATING PRESSURE 3809 PSI. 16:00 RDMO Anchorago SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $5,500.00 $5,500.00 ,. DOWELL $79,517.00 $79,517.00 LR-I'LE RED $3,600.00 $3,600.00 -- TOTAL FIELD ESTIMATE $88,617.00 $88,61 7.00 ARCO Alaska, Inc. Post Office Box 10036u Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 6, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 30-19 (Permit No. 97-50) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 30-19. If there are any questions, please call 263-4183. Sincerely, ~ ~~-~--~.~_ D. K. Petrash Drilling Engineer Kuparuk Drill Site Development ORIGINgL DKP/skad P E'¢EIVED ,ltJH 9 1997' 0il .& 6as Cons. Commiss~, Anchorage .... STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION ~,OMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG "i. '~;tai'~ 0i W'~ll Classification of ServiCe Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water Injection 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 97-50 '~3. '~,dci~:ess ........ 8. APl Number P. O. Box 100360, Anchorage, Alaska 99510 50-029-22753 4. Location of well at surface 7%:~:-.=-'~::: ~v -. ~--------,----~ 9. Unit or Lease Name - Kuparuk River Unit 910' FNL, 1949' FWL, Sec. 22, T laN, R9E, UM At top of productive interval ~ . i 10. Well Number 1080' FNL, 337' FWL, Sec. 27, T13N, R9E, UM ; V~i3;:.- ~ 30-19 At total depth i .--/~.-~.__¢. ! i 11 Field and Pool 1363' FNL, 249' FWL, Sec. 27, T13N, R9E, UM ..................... ~ Kuparuk River i5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Rig RKB 41', Pad 23'I ADL 25520, ADL 2556 !12. Date Spudded i13. Date T.'D. l~eached I f4. d~'{6"co~'p., susie., o~ Ab'&nd.115."Water depth, if offshore 116. No] of Ccrn~ietibns'- .. 3/3.0/97 i 4/5(97... I... 4/13/97 I N/AMSLI ... One .. 17. Total Depth (MD+TVD)] i8: Plug Back Depth (MD+TVD)I19: Directional SurveYl20: Depth where SSSV set~21. ThiCkness Of permafrosl ........... 9___4!__5_ ...... _6_823__ F-Il 9312 6742 F-ri [~Yes [~No I N/A MDl __ !650' ~Ap_p~0__x_~! 22. Type Electric or Other Logs Run GR/Res, GR/CCL/CBT 23. CASING, LINER AND CEMENTING RECORD CASING .... SE-FFING DEPTH I HoLE ' " ._ ......... .... iiii75-C1717-- ;W8- --1 SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.58# H-40 Surf. I 121' I 30" 304 SxAS I 7.625" 29.7# L-80 S6'ff. '~350' 9.875" 344 Sx ASLW, 439 sx Class G, 60 sx AS 4.5" 12.6# L-80 .... Su-ff. --- -§-4d?-; ~:-?~" .... 34b--~-~--i3-i~-~--~ ............................................................................ 4.5" Camco DB nipple with a 3.75" NoGo at 8729' (_+100' MD above top future perf) 24. perforationS open t~ ProdUction (MD+TVD of Top and ~otton~' ~'5.' ...... TuBiNG RECORD and interval, size and number) SiZE DEPTH SET (MD) PACKER SET (MD) 5120' MD TVD MD TVD ....................................................................................................................................... 9072'-9086' 6554'-6565' 6 spf 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 9100'-9120' 6576'-6591' DEPTH INTERVAL (MD)'] .... A~10t~ &"KI~I"D OF-MATERIAL USED' ' 6 spf 9072'-9086' 98800¢ prop in perfs, 1108# prop left in pipe 9191'-9201' 6647'-6655' 9100'-9120' 6 spf ...... ~)'1 ~-;I ~)-20-~-; ................................................................... 27. ' ...... PRoDt~CTioN TEsT ' Date First Production [l~leti~'od Of OPeratiOn (FloWing; gas lift, 'etc~i ............... i Water Injection ! Date of Test iHours Tested PRODUCTION FOR OIL-BBL IGAs-MCF WATER-BBL CHOKE SIZE i GAS-OIL RATIO [ TEST PERIOD" ¢iS-~-T~iiS-ii~iCa~-i-~g---P-F~-~-~-¢;~ibk, Lci~L-A-~5 -; -OW:i~i~L .............. ~,~-:f~-8~ ................ W~;:(~-:-¢-8-£- ........................................... ~ ................................................... OIL GRAVITY-APl (CORR) Press. i ~24-H..OUR RATE ........ 28. CORE DATA Brief description of lithology, porosity, fracture'~i"~.'ppa'~ent"~lips and presence of oil, gas or water. Submit core chips. ORIGINAL NasNa .0il & 6~s Cons, Anohorage Form 10-407 Rev. 07-01-80 Submit In Duplicate Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Top Kuparuk C 8942' 6454' THIS WELL IS ON REGULATORY APPROVAL. IT IS Bottom Kuparuk C 8984' 6486' CONSIDERED AN MIT FAILURE DUE TO THE LACK Top Kuparuk A 9059' 6544' OF A CASING ANNULUS OUTSIDE OF THE ENTIRE Bottom Kuparuk A 9202' 6655' 4.5" INJECTION STRING. I ANNULUS LEFT OPEN- FREEZE] FI~bTE~TI~.~'ELL Anchorage 31; List of Attachments " Summary of Daily Drilling Repeals, Su~eys i32. I hereby ~ify t~t ~e foregoing is true and correct to the best of my knowledge Title D~LCI~G ~~~& Date ~ ~(~ Prepared By Name/Number: ............ 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 5/2/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:30-19 RIG:PARKER 245 WELL ID: AK8725 TYPE: AFC:--AK8725 AFC EST/UL:$ 1010M/ 1210M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:03/30/97 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-22753-00 FINAL:04/07/97 03/29/97 (D1) TD: 121' (121) SUPV:DCL DAILY:$ 03/30/97 (D2) TD: 1371' (1250) SUPV: DCL DAILY:$ 03/31/97 (D3) TD: 5057' (3686) SUPV: DCL DAILY:$ 04/01/97 (D4) TD: 6360' (1303) SUPV: DCL/GRW DAILY: $ 04/02/97 (D5) TD: 5360' ( 0) S UP V: GRW DAILY: $ 04/03/97 (D6) TD: 7520' (2160) S UP V: GRW DAILY: $ 04/04/97 (D7) TD: 8415' (895) S UP V: GRW DAILY: $ 04/05/97 (DS) TD: 9415' (1000) SUPV: GRW DAILY: $ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move rig from 30-20 to 30-19. NU diverter system. 30,000 CUM:$ 30,000 ETD:$ 0 EFC:$ 1,040,000 MW: 9.2 VISC: 63 PV/YP: 18/24 APIWL: 12.8 DRILLING @ 2600' Accept rig at 23:00 hrs. 3/30/97. Drill from 121' to 1371'. Run Gyro. 83,712 CUM:$ 113,712 ETD:$ 140,430 EFC:$ 983,282 MW: 9.2 VISC: 52 PV/YP: 15/20 APIWL: 6.8 WIPERTRIP Drill from 1371' to 3508'. POOH. Light swabbing. Drilling from 3508' to 5057'. 83,115 CUM:$ 196,827 ETD:$ 374,655 EFC:$ 832,172 MW: 9.4 VISC: 44 PV/YP: 14/14 APIWL: 7.6 N/U BOPE Drill from 5057' to 5360'. Tight and swabbing from 3600' to 1700'. Hold safety meeting. Run 7-5/8" casing to 5350' Pump cement. 167,130 CUM:$ 363,957 ETD:$ 541,196 EFC:$ 832,761 MW: 0.0 VISC: 42 PV/YP: 14/ 8 APIWL: 20.0 DRILLING @ 5750' Pump cement. CIP @ 0237 hrs. Test all BOPE to 300/3000 psi. Drill ES cementer. RIH to clean out cement to 5176' 77,819 CUM:$ 441,776 ETD:$ 401,035 EFC:$ 1,050,741 MW: 9.2 VISC: 37 PV/YP: 10/ 8 APIWL: 8.4 DRILLING @ 8050' Drill cement to 5348' shoe and 10' of new cement and 20' of new hole to 5380'. Run LOT, EMW = 14.8 ppg. Drill from 5380' to 7520'. 95,722 CUM:$ 537,498 ETD:$ 703,784 EFC:$ 843,714 MW: 10.4 VISC: 42 PV/YP: 15/15 APIWL: 6.4 DRILLING @ 8600' Drill from 7520' to 8031' Lost pump pressure. Drill from 8031' to 8415'. 82,326 CUM:$ 619,824 ETD:$ 829,229 EFC:$ 800,595 MW: 10.7 VISC: 49 PV/YP: 20/19 APIWL: 4.4 DRILLING @ 8600' Drill from 7520' to 8031'. Lost pump pressure. Drill from 8031' to 8415'. 81,085 CUM:$ 700,909 ETD:$ 0 EFC:$ 1,710,909 Date: 5/2/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/06/97 (D9) TD: 9415' ( 0) SUPV:GRW DAILY:$ 04/07/97 (D10} TD: 9415' ( 0) SUPV:GRW DAILY:$ 04/08/97 (Dll) TD: 9415' ( 0) SUPV:GRW DAILY:$ MW: 10.7 VISC: 47 PV/YP: 20/17 APIWL: 4.6 CEMENTING 4.5" CASING Run 4.5" casing. 69,621 CUM:$ 770,530 ETD:$ 0 EFC:$ 1,780,530 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIGGING DOWN Finish running 4.5" casing to 9704'. Pump cement. CIP @ 0632 hrs. Set packer. Freeze protect well. N/D BOPE. Set packoff. Test packoff. Laydown drillpipe. 160,200 CUM:$ 930,730 ETD:$ 0 EFC:$ 1,940,730 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Finish laying down drillpipe. Release rig at 04:00 hrs. 4/8/97 to move to DS 3K-27. 125,954 CUM:$ 1,056,684 ETD:$ 0 EFC:$ 2,066,684 End of WellSummary for Well:AK8725 KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(30-19(W4-6)) WELL JOB SCOPE 30-19 PERFORATE, PERF SUPPORT DATE DAILYWORK 04/13/97 RUN CBT & PERFORATE "A" SANDS DAY OPERATION COMPLETE ] SUCCF~%E 1 YES S Initial Tbg Press I Final Tbg Press I Initial Inner Ann 0 PSI 850 PSI 0 PSI DAILY SUMMARY I JOB NUMBER 0412972006.7 UNIT NUMBER KEYPERSON SUPERVISOR SWS -BAILEY BLACK Final Irmer Ann [ Initial OuterI Final Outer AnnAnn 0 PSI 0 PSI 0 PSI RUN CBTE F/9240 - 6500' ELM. SHOWS GOOD BOND. PERFORATE F/9072 - 9086' ELM, 9100 - 9120' ELM & 9191 - 9201' ELM W/3- 3/8" HSD DP @ 6 SPF PHASED 60 DEG. TIME LOG ENTRY 07:45 MIRU SWS (BAILEY & CREW). CHG OUT LINE F1 CBT. ELECTRICAL PROBLEMS W/SWS COMPUTER, TROUBLESHOOT & FIX. CUT .22" LINE & BUILD .46" ROPE SOCKET F/CBT. MU CBT TOOL STRING (CENT/CBTE/CENT/FLEX/FLEX~3R/TCC/CCL) TL-51,7". TGSM - TRIPLEX SAFETY / WEATHER/J JOB OVERVIEW. PT BOPE TO 3000 PSI. 12:30 RIH W/CBTE TO 9240' ELM. RUN CBTE BOND LOG F/9240' - 6500' ELM. LOG SHOWS GOOD BOND. POOH W/CBTE. 17:00 OOH W/CBTE. RD CBTE & CHANGE BACK TO .22" LINE. 19:00 MU GA#1 (10' 3-3/8" HSD/CC'L). PT & R1H TO 9205' ELM. TIE IN TO 4/13/97 SWS CBT & CBTE RUN. PERFORATE F/ 9191' - 9201' ELM W/3-3/8" HSD DP @ 6 SPF PHASED 60 DEG. SAW SURFACE INDICATION. POOH W/GA#1. 21:30 OOH W/GA#1. MU GA#2 (20' 3-3/8" HSD/CCL). PT & RIH TO 9200' ELM. TIE IN & PERFORATE F19100 - 9120' ELM W/ SAME GUNS AS ABOVE. POOH W/GA#2. 23:45 OOH W/GAg2. MU GA#3(14' 3-3/8" HSD/CCL). PT & RIH TO 9205' ELM. TIE IN & PERFORATE F/9072 - 9086' ELM W/ SAME GUNS AS ABOVE. POOH W/ GA#3. 02:00 OOH. RD SWS. 02:45 OFF LOCATION. TURN OVER TO PRODUCTION. , lonobore Tubingless/,,jector Single-Trip System M. Gen V 4-1/2" fluted tubing hanger and pup, NSCT, for monobore casinghead L. Tubing, 4-1/2", 12.6#, L-80, NSCT to surface K. 4-1/2" CAMCO 'DB' landing nipple with 3.813" ID No-Go profile set at +/- 500' MD. 6' L-80 handling pup made-up on top and 6' 4-1/2" L-80 flow coupling on bottom. J. Tubing, 4-1/2", 12.6#, L-80, NSCT to _+500' MD. I. 4-1/2" Baker 'CM' sliding sleeve w/3.813" Camco 'X' selective profile (ran in closed position). H. 1 joint 3-1/2", 9.3#, L-80 EUE 8rd Mod tbg G. Baker SABLTM/ZXP packer with anchor set 100'-200' MD inside casing shoe. 7-5/8" surface casing shoe TOC _+1000' above top formation 'C' Sand 'A' Sand F. Tubing, 4-1/2", 12.6#, L-80, NSCT to surface casing shoe. E. 4-1/2" CAMCO 'DB' landing nipple with 3.75" ID No-Go profile set _+100' above topmost perforation. D. Tubing, 4-1/2", 12.6#, L-80, NSCT. A. to C. Baker float shoe and collar with three cement shoe joints. dkp 3/27/97 i i i i SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-84585 Sidetrack No. Page 1 of 3 , Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK RIVER UNIT Well Name & No. 30-PAD/30#19 __ Survey Section Name SPERRY SUN BHI Rep. iiii i i ii i i i i ii iiii I WELL DATA Target TVD (IT) Target Coord. N/S Slot Coord. N/S -910.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 1949.00 Magn. Declination 27.960 Calculation Method MINIMUM CURVATURE I Target Direction (DD) Buil~Walk\DL per: lOOff~ 30m~ lOm~ Vert. Sec. Azim. 196.67 Magn. to Map Corr. 27.960 Map North to: OTHER .......... SURVEY DATA ............... '-- t Survey Incl. I Hole I Total Coordinate Build Rate Walk Rate I Survey , Course Vertical . Build (+) Right (+) i Comment Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Type (F'r) - {DD) (DD) (FT) (Fl) (F-r) {Fl') Per mO F'r) Drop (-) Left (-) MWD 0.00 0.00 0.00 0.00 0.00 0.00 0,00 TIE IN POINT ! -- 30-MAR-97 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8'MACH I C-^KO-1.4 DEG. 30-MAR-97 MWD 180.00 1.25 45.00 59.00 180.00 -0.57 0.46 0.46 2.12 2.12 ****GYRO**** 30-MAR-97 MWD 269.00 1.50 28.00 89.00 268.97 -2.58 2,17 1.69 0.53 0.28 ****GYRO**** "] 30-MAR-97 MWD 359,00 2.50 348.00 90.00 358,92 -5.44 5.13 1.83 1.84 1.11 ****GYRO**** I 30-MAR-97 MWD 450.00 4.00 335.00 91.00 449.77 -9.55 9.95 0.08 1.83 1.65 ****GYRO**** 30-MAR-97 MWD 530.00 6.00 309.00 80.00 529.47 -13.23 15.11 -4.35 3.72 2.50 -32.50 ****GYRO**** --. 30~MAR-97 MWD 640.00 6.50 287.00 110.00 638.83 -15.45 20.55 -14.77 2.21 0.45 -20.00 ****GYRO**** 30-MAR-97 MWD 723.00 t 8.25 257.00 83.00 721.17 -12.53 20.58 -25.07 5.02 2.11 -36.14 ****GYRO**** I 30~MAR-97 I MWD 832.45 11.49 234.38 109.45 829.03 -0.01 12.46 -41.60 4.56 2.96 -20.67 i 30-MAR-07 MWD 926.71 13.97 228.17 94.26 920.97 17.13 -0,60 -57.71 3.00 2.63 -6.59 30-M^R-07 MW~ ~ O1 ~.58 16.~8 225.00 02.85 1 O10.51 3~.40 -17.48 -75.50 3.05 2.92 -3.32 30-MAR-97 ! MWD 1111.22 19.96 219.65 91.66 1097.52 64.39 -38.82 -94.81 4.03 3.58 i -5.93 I I -' 30-MAR-97 I MWD 1202.52 22.45 219.32 91.30 1182.63 94.83 -64.31 -115.80 2.73 2.73 -0.36 31 -MAR-97 MWD 1296.32 24.08 216,45 93.80 1268.80 129.36 -93.56 -138.52 2.12 1.74 -3.06 . :~1-MAR-97I MWD 1389.94 t 26.33 215.24i 93.62 13.53.51 167.02 -125.89 -161.85 2.47 2.40 -1.29i ~ c:_. ~" 31-MAR-97 1 MWD, 1484.98 26.89 , 214.28 95.04 1438.48, 207.49 -160.86 -186.12 0.74 0.59 , -1.01 ! I ~31-MAR-97 { MWD 1578.05 i 28.40 211.70 93.07 1520.92 I 248.93 -197.09 -209.60 2.07 1.62 -2.77 ~.~ I ~ ~ '~' ';'~ ~ 31 -MAR-97 MWD 1671.94 31.45 208.88 93.89 1602.29 ! 294.45 -237.54 -233.17 3.58 3.25 -3.00 31 -MAR-97 MWD 1763.91 32.87 207.64 91.97 1680.15 342.40 -280.66 -256.34 1.70 1.54 -1.35 31 -MAR-97 MWD 1858.13 35.04 203.65 94.22 1758.31 394.36 -328.10 -279.08 3.30 2.30 -4.23 31 -MAR-97 MWD 1954.17 38.45 201.38 96.04 1835.26 451.51 -381.18 -301.01 3.82 3.55 -2.36 __. 31 -MAR-97 MWD 2048.82 41.58 200.04 94.65 1907.74 512.21 -438.10 -322.51 3.43 3.31 -1.42 31 -MAR-07 MWD 2142.18 44.39 198.76 93.38 1976.03 575.78 -498.14 -343.63 3.15 3.01 -1.37 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK RIVER UNIT Well Name & No. 30-PAD/30#19 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (F'n Target Coord. N/S Slot Coord. N/S -910.00 Grid Correction 0.000 Depths Measured From: RKB ~, MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 1949.00 Magn. Declination 27.960 Calculation Method MINIMUM CURVATURE Target Direction (oD) Buil~Walk\DL per: lOOft~ 30m0 lOm~ Vert. Sec. Azim. 196.67 Magn. to Map Corr. 27.960 Map North to: OTHER ,~ SURVEY DATA I I Total Coordinate IBuild Rate I Walk Rate Survey Survey Incl. Hole I Course Vertical Date Tool Depth Angle Direction/ Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) I Right (+) Comment Type (FT) (oD) (DD) (FT) (FO {FT) (ET) (Per mO F'r) Drop (-) Left (-) 31-MAR-97. MWD 2235.21 47.07 197.96 93.03 2040.96 642.36 -561.36 -364.60 2.95 2.88 44.86 8'MACH 1c-AKo-1.2 DEG 31-MAR-97 MWD i 2326.32 50.09 195.91 91.11 2101.23 710.66 -626.54 -385.06 3.43 3.31 -1.15 I 31-MAR-97 MWD 2418.30 53.95 196.03 91.98 2157.83 783.15 -696:06 . -405.59 4.26 4.20 -0.96 31 -MAR-97 MWD 2508.90 55.69 194.38 90.60 2210.03 857.17 -767.51 -425.00 2.43 i 1.92 -1.82 31-MAR-97 MWD 2787,13 53.39 194.84 278.23 2371.43 1083.63 -986.79 -482.15 0.84 I -0,83 0,17 I 31 -MAR-97 MWD 3061.75 51.13 194.17 274,62 2539.51 1300.63 -1197.02 -536.55 0,85 I -0.82 -0.24 31 -MAR-97 MWD 3343.25 48.84 193.91 281.50 2720.49 1515.98 -1406.16 -588.86 0.82 -0.81 -0.09 31-MAR-97 MWD 3613.99 52.00 193.66 270.74 2892.98 1724.36 -1608.79 -638.57 1.17 1.17 -0.09 31 -MAR-97 MWD 3889.15 49.36 194.41 275.16 3067.32 1936.98 -1815.29 -690.16 0.98 -0.96 i 0.27 i 31 -MAR-97 MWD 4168.74 47.35 194.56 279.59 3253.10 2145.75 -2017.57 -742.41 0.72 ! -0.72 I 0.05 31-MAR-07 MWD 4446.37 50.19 192.94 I 277.63 3436.07 I 2354.24 -2220.37 -791.97 1.11 1.02 -0.58 31-MAR-97 i MWD 5003,85 { 50.42 i 194.02 278.77 3799.35 2776.34 -2631.79 -889.51 0.77 0.74 0.30 03-APR-97 MWD 5550.66 48.82 190,56 267.19 41 56.51 3189,26 -3035,75 -979.90 0.64 0.01 -0.86 4 3/4'MACH 1XL-AKO-1.2 DEG. , 03-APR-07 I MWD 6201.77 46.98 195.05 I 280.8E~ 4593.52 3671.41 -3498.73 i: -1!!4.55 1.32 ! -0.27 -1.75 03-APR-07, MWD[ 6757.03 [49.24 193.23, 278.34 4973.95 4075.48 -3889.81 -1217.13 1.49 1.39 -0.74 03-APR-97 MWD 6942.44 [ 48.54 195.25 i 185.41 5095.87 4215.03 -4025.20 -1251.48 0.90 -0.38 1.09 03-APR-97 MWD 7216.44147.771 192.82 274.00 5278.67 I 4418.91 -4223.19 -1301.00 0.72 -0.28 -0.89 04-APR-97 MWD 7491.95 48.40 195.34 275.51 5462.74 4623.68 -4422.01 -1350.89 0.72 0.23 0.91 04-APR-97 MWD 7769.73 I 48.35 193.30 277.78 5647.26 4831.13 4623.18 -1402.24 0.55 -0.02 -0.73 04-APR-97 8049.26 ~46.97 1 94.52 279.53 5835.53 5037.49 -4823.74 -1451.88 0.59 -0.49 0.44 ii i i i iiiiiiiii i i i ii I l ll.iilCl ' SURVEY CALCULATION AND FIELD WORKSHEET JobNo. 0450-84585 Sidetrack No. ~ Page 3 of 3 . Company ARCO ALASKA, INC. Rig Contractor & No. PARKER - 245 Field KUPARUK RIVER UNIT Well Name & No. 30-PAD/30#19 Survey Section Name SPERRY SUN BHI Rep. _ WELL DATA Target TVD ~FT} Target Coord. N/S Slot Coord, N/S -910.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL0 SS~ Target Description Target Coord. EJW Slot Coord. E/W 1949.00 Magn. Declination 27.960 Calculation Method MINIMUM CURVATURE Target Direction (DD) Builc~Walk\DL per: lOOft~ 30m0 lOmr'] Vert. Sec. Azim. 196.67 Magn. to Map Corr. 27,960 Map North to: OTHER SURVEY DATA .... Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (k-r) (OD) (OD) (k-r) (F'r) (FT) (FT) (Per 100 FT) Drop (-) Left (-) 04-APR-97 MWD 8328.23 48.08 192.61 278.97 6023,92 5242,93 -5023.74 . . -1500,11 0,64 0.40 -0,68 4 3/4'MACH IXL-AKO-1,2 DEG, 05-APR-97 MWD 8603,93 48,37 1 93,06 .275,70 6207,59 5448,08 -5224,21 -1545,79 O, 16 0,11 O. 16 .., -- 05-APR-97 MWD 8695,62 45,45 1 93,81 91.69 6270.23 5514,92 -5289,33 . ~1561,33 3,24 --3.18 0.82 .,, 05-APR-97 MWD 8786.87 42,90 194.68 91,25 6335,67 5578,44 -5350,96 -1576,97 2,87 -2.79 0,95 05-APR-97 MWD 8880,00 39,35 195,65 93.13 6405,81 5639,66 -5410,08 -1592,97 3,87 -3.81 1.04 --, 05-APR-97 MWD 9063,71 39.48 197.56 183.71 6547.74 5756,29 -5521.84 -1626.30 0.66 0.07 I 1.04 ..... 05-APR-97 MWD 9157.34 38.74 197.34 93.63 6620.39 5815.35 -5578.19 -1644.01 0.80 -0.79 -0.23 05-APR-97 MWD 9340.03 38.03 196.97 182.69 6763.59 5928.79 -5686.58 -1677.48 0.41 -0.39 -0.20 PROJECTED TO TD 05-APR-97 MWD 9415.00 38.03 196.97 74.97 6822.65 5974.97 -5730.75 -1690.96 0.00 0.00 0.00 CLO.DIST=5975'AZl-- 196.44 i , I _ I C] F! I I--I--I ~ G WELL LOG TRANSMITTAL To: State of Alaska May 14, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 30-19, AK-MM-70084 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 30-19: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-22753-00 2"x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22753-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 5/12/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11013 Company: Field: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS Tape 30-19 (~'.,i')-~)%'~ '~.d--"-/(~'~'~.~ 97199 CBT/GR/CCL(PDC) 970413 I 1 1 ,, Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I~t I I__1__1N G May 12, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 30-19 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 30-19 Tie in point 0.00', interpolated depth at 9,415.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company SPERk_ -SUN DRILLING SERVICES ANCHOR,AGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER LTNIT/30-19 500292275300 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 1/97 DATE OF SURVEY: 040697 MWD SURVEY JOB NUMBER: AK-MM-70084 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -65.00 180.00 179.98 114.98 269.00 268.95 203.95 359.00 358.89 293.89 450.00 449.74 384.74 0 0 1 15 1 30 2 30 4 0 N .00 E .00 .00N .00E N 45.00 E .69 1.39N 1.39E N 28.00 E .53 3.10N 2.62E N 12.00 W 1.84 6.06N 2.77E N 25.00 W 1.83 10.88N 1.01E .00 -1.73 -3.72 -6.60 -10.71 530.00 529.44 464,44 640.00 638.79 573,79 723.00 721.13 656.13 832.45 828.98 763.98 926.71 920.92 855.92 6 0 6 30 8 15 11 29 13 58 N 51.00 W 3.72 16.04N 3.42W N 73.00 W 2.21 21.48N 13.84W S 77.00 W 5.02 21.51N 24.14W S 54.38 W 4.56 13.39N 40.66W S 48.17 W 3.00 .34N 56.77W -14.39 -16.61 -13.69 -1.17 15.96 1019.56 1010.46 945.46 1111.22 1097.47 1032.47 1202.52 1182.57 1117.57 1296.32 1268.74 1203.74 1389.94 1353.43 1288.43 16 40 19 57 22 27 24 4 26 19 S 45.09 W 3.05 16.55S 74.57W S 39.65 W 4.03 37.89S 93.87W S 39.32 W 2.73 63.37S 114.86W S 36.45 W 2.12 92.62S 137.58W S 35.24 W 2.47 124.94S 160.91W 37.24 63.23. 93.66 128.20 165.85 1484.98 1438.40 1373.40 26 53 1578.05 1520.90 1455.90 28 14 1671.94 1602.33 1537.33 31 27 1763.91 1680.18 1615.18 32 52 1858.13 1758.34 1693.34 35 2 S 34.28 W .74 159.92S 185.17W S 31.70 W 1.94 196.04S 208.60W S 28.88 W 3.73 236.40S 232.11W S 27.64 W 1.70 279.52S 255.27W S 23.65 W 3.30 326.96S 277.99W 206.31 247.64 293.05 341.00 392.96 1954.17 1835.29 1770.29 38 27 2048.82 1907.77 1842.77 41 34 2142.18 1976.06 1911.06 44 23 2235.21 2041.00 1976.00 47 4 2326.32 2101.27 2036.27 50 5 S 21.38 W 3.82 380.04S 299.94W S 20.04 W 3.43 436.96S 321.44W S 18.76 W 3.15 497.00S 342.56W S 17.96 W 2.95 560.22S 363.53W S 16.91 W 3.43 625.40S 383.99W 450.11 510.80 574.38 640.96 709.26 2418.30 2157.86 2092.86 2508.90 2210.05 2145.05 2787.13 2371.43 2306.43 3061.75 2539,49 2474.49 3343.25 2720.45 2655.45 53 57 55 41 53 23 51 7 48 50 S 16.03 W 4.26 694.91S 404.52W S 14.38 W 2.43 766.36S 423.93W S 14.84 W .84 985.61S 481.07W S 14.17 W .85 1195.81S 535.47W S 13.91 W .82 1404.92S 587.77W 781.75 855.76 1082.19 1299.16 1514.48 3613.99 2892.93 2827.93 3889.15 3067.27 3002.27 4168.74 3253.04 3188.04 4446.37 3436.01 3371.01 4725.08 3617.82 3552.82 52 49 47 50 48 0 21 20 11 21 S 13.66 W 1.17 1607.55S 637.47W S 14.41 W .98 1814.05S 689.07W S 14.56 W .72 2016.31S 741,31W S 12.94 W 1.11 2219.11S 790.87W S 13.19 W .66 2424.84S 838.61W 1722.86 1935.48 2144.23 2352.71 2563.49 ORIGINAL SPERk_ -SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/30-19 500292275300 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 1/97 DATE OF SURVEY: 040697 MWD SURVEY JOB NUMBER: AK-MM-70084 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5003.85 3799.25 3734.25 50 25 S 14.02 W .77 2630.48S 888.40W 2774.78 5283.47 3980.42 3915.42 48 47 S 12.87 W .66 2837.58S 937.94W 2987.38 5550.66 4156.38 4091.38 48 49 S 10.58 W .65 3034.42S 978.79W 3187.66 5920.91 4403.08 4338.08 47 44 S 19.97 W 1.91 3300.49S 1051.26W 3463.35 6201.77 4593.39 4528.39 46 58 S 15.05 W 1.32 3497.39S 1113.44W 3669.81 6478.69 4785.11 4720.11 45 22 S 15.30 W .58 3690.21S 1165.73W 3869.52 6757.03 4973.81 4908.81 49 14 S 13.23 W 1.49 3888.46S 1216.01W 4073.86 6942.44 5095.72 5030.72 48 32 S 15.25 W .90 4023.85S 1250.36W 4213.41 7216.44 5278.50 5213.50 47 46 S 12.82 W .72 4221.81S 1299.87W 4417.26 7491.95 5462.55 5397.55 48 24 S 15.34 W .72 4420.62S 1349.76W 4622.02 7769.73 5647.06 5582.06 48 20 S 13.30 W .55 4621.77S 1401.11W 4829.45 8049.26 5835.32 5770.32 46 58 S 14.52 W .59 4822.31S 1450.75W 5035.80 8328.23 6023.69 5958.69 48 4 S 12.61 W .64 5022.30S 1498.97W 5241.22 8603.93 6207.37 6142.37 48 22 S 13.06 W .16 5222.77S 1544.65W 5446.37 8695.62 6270.00 6205.00 45 27 S 13.81 W 3.24 5287.89S 1560.19W 5513.21 8786.87 6335.44 6270.44 42 54 S 14.68 W 2.87 5349.52S 1575.83W 5576.74 8880.00 6405.58 6340.58 39 20 S 15.65 W 3.87 5408.63S 1591.83W 5637.96 9063.71 6547.51 6482.51 39 28 S 17.56 W .66 5520.40S 1625.16W 5754.58 9157.34 6620.16 6555.16 38 44 S 17.34 W .80 5576.74S 1642.87W 5813.64 9340.03 6763.36 6698.36 38 1 S 16.97 W .41 5685.13S 1676.33W 5927.07 9415.00 6822.41 6757.41 38 1 S 16.97 W .00 5729.31S 1689.81W 5973.26 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 5973.31 FEET AT SOUTH 16 DEG. 25 MIN. WEST AT MD = 9415 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 196.67 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 9,415.00' MD SPERk_-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/30-19 500292275300 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 1/97 DATE OF SURVEY: 040697 JOB NUMBER: AK-MM-70084 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -65.00 .00 N .00 E .00 1000.00 991.70 926.70 12.67 S 70.64 W 8.30 2000.00 1870.80 1805.80 407.07 S 310.34 W 129.20 3000.00 2500.73 2435.73 1149.19 S 523.70 W 499.27 4000.00 3139.47 3074.47 1895.52 S 710.00 W 860.53 8.30 120.90 370.07 361.26 5000.00 3796.79 3731.79 2627.60 S 887.68 W 1203.21 6000.00 4456.39 4391.39 3355.64 S 1070.55 W 1543.61 7000.00 5133.83 5068.83 4065.46 S 1261.70 W 1866.17 8000.00 5801.71 5736.71 4787.45 S 1441.72 W 2198.29 9000.00 6498.33 6433.33 5481.78 S 1612.94 W 2501.67 342.68 340.40 322.56 332.12 303.37 9415.00 6822.41 6757.41 5729.31 S 1689.81 W 2592.59 90.92 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERR_ SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/30-19 500292275300 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 1/97 DATE OF SURVEY: 040697 JOB NUMBER: AK-MM-70084 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -65.0 65.00 65.00 .0 165.02 165.00 100.0 265.05 265.00 200.0 365.11 365.00 300.0 0 .00 N .00 E 0 .00 N .00 E 0 1.16 N 1.16 E 0 3.01 N 2.57 E 0 6.32 N 2.71 E .00 .00 .00 .02 .02 .05 .03 .11 .07 465.30 465.00 400.0 565.75 565.00 500.0 666.39 665.00 600.0 767.40 765.00 700.0 869.27 865.00 800.0 0 11.85 N .46 E 0 18.39 N 6.32 W 0 22.05 N 16.85 W 0 19.29 N 30.56 W 0 8.77 N 46.76 W .30 .19 .75 .45 1.39 .64 2.40 1.01 4.27 1.87 972.27 965.00 900.0 1076.81 1065.00 1000.0 1183.51 1165.00 1100.0 1292.23 1265.00 1200.0 1402.85 1365.00 1300.0 7.49 S 65.25 W 29.25 S 86.47 W 57.76 S 110.26 W 91.28 S 136.59 W 129.62 S 164.21 W 7.27 3.00 11.81 4.54 18.51 6.70 27.23 8.72 37.85 10.63 1514.81 1465.00 1400.0 1628.54 1565.00 1500.0 1745.84 1665.00 1600.0 1866.30 1765.00 1700.0 1992.47 1865.00 1800.0 171.06 S 192.77 W 217.14 S 221.20 W 270.83 S 250.72 W 331.30 S 279.87 W 402.58 S 308.63 W 49.81 11.95 63.54 13.73 80.84 17.29 101.30 20.46 127.47 26.17 2126.78 1965.00 1900.0 2270.88 2065.00 2000.0 2430.44 2165.00 2100.0 2606.38 2265.00 2200.0 2776.35 2365.00 2300.0 486.87 S 339.09 W 585.35 S 371.57 W 704.34 S 407.23 W 844.36 S 443.93 W 977.25 S 478.85 W 161.78 34.31 205.88 44.10 265.44 59.55 341.38 75.95 411.35 69.97 2943.06 2465.00 2400.0 3102.41 2565.00 2500.0 3259.00 2665.00 2600.0 3411.49 2765.00 2700.0 3568.90 2865.00 2800.0 1106.21 S 512.85 W 478.06 66.71 1226.50 S 543.22 W 537.41 59.35 1343.35 S 572.52 W 594.00 56.59 1455.10 S 600.17 W 646.49 52.49 1573.16 S 629.10 W 703.90 57.40 3729.61 2965.00 2900.0 3885.65 3065.00 3000.0 4038.78 3165.00 3100.0 4186.44 3265.00 3200.0 4336.75 3365.00 3300.0 1695.35 S 659.06 W 764.61 60.71 1811.48 S 688.41 W 820.65 56.04 1923.78 S 717.28 W 873.78 53.13 2028.94 S 744.58 W 921.44 47.66 2137.82 S 771.73 W 971.75 50.32 SPERR~ SUN DRILLING SERVICES ANCHOILAGE ALASKA PAGE ARCO ALASKA, INC. KUPARUK RIVER UNIT/30-19 500292275300 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/ 1/97 DATE OF SURVEY: 040697 JOB NUMBER: AK-MM-70084 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4491.65 3465.00 3400.00 2253.01 S 798.66 W 1026.65 54.90 4645.58 3565.00 3500.00 2366.99 S 825.05 W 1080.58 53.93 4796.08 3665.00 3600.00 2476.50 S 850.72 W 1131.08 50.50 4950.10 3765.00 3700.00 2590.29 S 878.37 W 1185.10 54.02 5107.05 3865.00 3800.00 2707.65 S 907.67 W 1242.05 56.95 5260.06 3965.00 3900.00 2820.41 S 934.02 W 1295.06 53.01 5411.88 4065.00 4000.00 2931.78 S 959.41 W 1346.88 51.82 5563.75 4165.00 4100.00 3044.09 S 980.63 W 1398.75 51.87 5714.66 4265.00 4200.00 3154.28 S 1005.66 W 1449.66 50.91 5864.22 4365.00 4300.00 3260.84 S 1037.43 W 1499.22 49.57 6012.74 4465.00 4400.00 3364.55 S 1073.52 W 1547.74 48.52 6160.11 4565.00 4500.00 3468.01 S 1105.33 W 1595.11 47.38 6306.73 4665.00 4600.00 3571.50 S 1133.36 W 1641.73 46.61 6450.06 4765.00 4700.00 3670.55 S 1160.35 W 1685.06 43.33 6594.08 4865.00 4800.00 3770.69 S 1187.06 W 1729.08 44.02 6743.57 4965.00 4900.00 3878.56 S 1213.67 W 1778.57 49.49 6896.05 5065.00 5000.00 3990.30 S 1241.21 W 1831.05 52.48 7047.08 5165.00 5100.00 4099.50 S 1270.98 W 1882.08 51.04 7196.35 5265.00 5200.00 4207.31 S 1296.57 W 1931.35 49.27 7345.15 5365.00 5300.00 4314.74 S 1321.07 W 1980.15 48.80 7495.64 5465.00 5400.00 4423.28 S 1350.49 W 2030.64 50.49 7646.25 5565.00 5500.00 4531.98 S 1379.88 W 2081.25 50.60 7796.72 5665.00 5600.00 4641.40 S 1405.75 W 2131.72 50.47 7946.20 5765.00 5700.00 4749.39 S 1431.86 W 2181.20 49.49 8092.75 5865.00 5800.00 4853.09 S 1458.72 W 2227.75 46.55 8240.38 5965.00 5900.00 4958.51 S 1484.70 W 2275.38 47.63 8390.06 6065.00 6000.00 5067.20 S 1509.01 W 2325.06 49.68 8540.16 6165.00 6100.00 5176.34 S 1533.87 W 2375.16 50.10 8688.45 6265.00 6200.00 5282.90 S 1558.97 W 2423.45 48.30 8826.71 6365.00 6300.00 5375.33 S 1582.69 W 2461.71 38.26 8956.84 6465.00 6400.00 5455.55 S 1604.97 W 2491.84 30.13 9086.37 6565.00 6500.00 5534.13 S 1629.51 W 2521.37 29.53 9214.83 6665.00 6600.00 5611.08 S 1653.59 W 2549.83 28.46 9342.11 6765.00 6700.00 5686.36 S 1676.71 W 2577.11 27.29 9415.00 6822.41 6757.41 5729.31 S 1689.81 W 2592.59 15.47 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS r'~ I=! I I_1_ I IM G S ~ I::! L~ I ~- ~:: S WELL LOG TRANSM1TT~ To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. 0 Atm.: Loft Taylor 3001 Porcupine Dr. / 0- Anchorage, Alaska 99501 0~ ~ ~~h'~'~ MWD Formation Evaluation Logs 30-19, AK-MM-70084 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ylm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22753-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 21. 1997 Mike Zanghi, Drlg Engr Supv ARCO Alaska Inc. P O Box 100360 Anchoragc, AK 99510-0360 ac~ Wcll No. Company Permit No. Surf Loc Btmholc Loc Kupamk River Unit 30-19 ARCO Alaska. Inc. 97-5O 910'FNL. 1949'FWL. Sec 22. TI3N. R9E. UM ~, , 1_ 39 FNL. 237'FWL. Scc 27. TI3N. R9E. UM Dcar Mr Zanghi' Encloscd is thc approvcd application for pcrmit to drill thc above rcfcrcnccd wcll. Thc pcmut to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd by law from othcr govcmmcntal agcncics, and does not authorize conducting drilling opcrations until all other rcquircd pcmutting dctcrminations arc madc. Blowout prcvcntion cquipmcnt (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035. Sufficicnt notice (approximatcly 24 hours) of thc BOPE tcst pcrfom~cd bcforc drilling below thc surfacc casing shoe must bc given so that a rcprcscntativc of thc Commission may xvitncss thc test. Noticc may bc givcn by' contacting thc Commission pctrolcum ficld inspcctor on thc North Slopc pagcr at 659-3607. David Chairman BY ORDER OF THE COMMISSION dlf/cncl c: l)cpt of Fish & Game, l labitat Sccticm - w/o cncl l)ept of I(nvironmcntal (_'onscrw~tion - xx'/o cncl STATE OF ALASKA AL/-,..,KA OIL AND GAS CONSERVATION COMMIS,..,.JN PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil X Re-Ently [~ Deepen ~ Service E] Development Gas ~ Single Zone X Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. Ricj RKB 41'; Pad 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracje, AK 99510-0360 ADL 25520, ALK 2556 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 910' FNL, 1949' FWL, Sec. 22, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1151' FNL, 296' FWL, Sec. 27, T13N, RgE, UM 30-19 #U-630610 At total depth 9. Approximate spud date Amount 1539' FNL, 237' FWL, Sec. 27, T13N, R9E, UM 3/24/97 $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 30-09 9348' MD 1151' @ TD feet 11.7' @ 500' feet 2560 6819' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 47.9° Maximumsudace 2386 psig At total depth (TVD) 3600 psig 18. Casing program Setting Deplh size Specifications Top Botlom Quantity of cement Hole Casing Weight Grade Coupling Length MD TV• MD TVD (include stage data) 24' 16' 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875' 7.625' 29.7# L-80 LTC 5226' 41' 41' 5267' 4030' 820 Sx Arcticset III & HF-ERW 410 Sx Class G 6.75' 4.5' 12.6# L-80 NSCT 9307' 41' 41' 9348' 6819' 250SxClassG Top 1000' above Kuparuk 19. To be completed for Redrill, Re-entry. and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface ~ ~ i-.~ Intermediate ~' ~'~¢~ ~ i '~ ~ Production Liner Perforation depth: measured [~i,¼;. true vertical 20. Attachments Filing fee X Properly plat [~] BOE,,SJ~tc_.,h~.,Y~. Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis - [] Seabed report [-~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best ef my knowledge Signed (~~.&;~.%o~_.._ F-CC. IV~.~AI~(~|,| Title [~e,o~. Supv. Date Commission Use Only ,erm~N~:t~,mbe~..~:::::~ I*"' number I*,,row, date See cover letter for --' 50- O ~.~ --. ~ ~ '~ ~.~ other requirements Conditions of approval Samples required ~ Yes '~ No Mud logrequired ['~ Yes ~ No Hydrogen sulfide measures ~' Yes ~ No Directional survey required "~ Yes ~--~ No Required working pressure for BOPE E] 2M ~ 3M E] 5M ~ 10M E] 15M Other: by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 30-19 , . . . . o . . . Note: 10. 11. Note: 12. 13. Move in and rig up Parker #245. Install diverter system.- Drill 9-7/8" hole to 7-5/8" surface casing point (5,267')according to directional plan. Run and cement 7-5/8" casing, using stage collar placed at the base of permafrost, and light weight lead cement. Install and test BOPE to 3000 psi. 'Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test, maximum pressure allowed 16.0 ppg EMW. Drill 6-3/4" hole to total depth (9,348') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" NSCT long string with Baker annular packer. Hydraulically set annular packer 150' inside surface casing shoe to provide annular isolation. If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Pressure test casing to 3500 psi. ND BOPE and install production tree. As a dedicated injector, cased hole cement bond Iogs_(SL:T-J or CBT.) will be run to establish isolation after the cleanout is completed, but prior to perforating. Shut in and secure well. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. DRILLING FLUID PROGRAM Well KRU 30-19 Spud to 9-5/8" surface casing Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids 9.0-10.0 15-25 15-35 50-80' 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 10.9 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 2,386 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 30-19 is 30-09. As designed, the minimum distance between the two wells would be 11.7' @ 500' MD. Drillin~l Area Risks: Risks in the 30-19 drilling area include lost circulatiop and high pressure,s in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 4-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 3-3/4" hole, and run a 3-1/2" FJ or 2-7/8" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.9 ~ will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 30-19 Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 30-19 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. 30-19 will not be permitted for annular pumping as the annular isolation packer does not allow for this operation. ARCO ALAS~, Inc. Pad 30 19 slot #19 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE Baker Hughes INTEQ REPORT Your ref : 19 Version #2 Our ref : prop1782 License : Date printed : 12-Mar-97 Date created : 21-Aug-96 Last revised : 12-Mar-97 Field is centred on nFO 16 18.576,w150 5 56.536 Structure is centred on nFO 28 24.450,w149 48 25.1 Stol location is n70 28 15.498,w149 47 27.803 Slot Grid coordinates are N 6021908.494, E 525584.113 Slot local coordinates are 910.00 S 1949.00 E Projection type: alaska - Zone 4, Spheroid: Clarke o 1866 Reference North 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 wel[path Closest approach with 3-D Minimu~ Distance method Last revised Distance M.D. Diverging from M.D. PGMS <O-8137'>,,14,Pad 30 2?-Aug-91 174.7 100.0 875.0 PGMS <O-9195'>,,18,Pad 30 27-Aug-91 275.0 200.0 200.0 PGMS <O-9263'>,,17, Pad 30 2?-Aug-91 249.9 100.0 2520.0 Pr~s <O-8351'>,,16A,Pad 30 27-Aug-91 180.1 1875.0 1875.0 PMSS <5107-8184'>,,16,Pad 3O 27-Aug-91 180.1 1875.0 1875.0 PGMS <O-9450'>,,15,Pad 30 27-Aug-g1 138.5 1275.0 1275.0 PGMS <O-7950'>,,13,Pad 30 27-Aug-91 151.0 0.0 950.0 PGMS <O-7005">,,12,Pad 30 27-Aug-91 124.9 300.0 875.0 PGMS <O-7803'>,,11,Pad 30 27-Aug-91 99.9 100.0 100.0 PGMS <O-8830'>,,10,Pad 30 27-Aug-91 53.4 1115.2 1115.2 PGMS <O-Tg16'>,,9,Pad 30 27-Aug-91 11.7 500.0 500.0 PGMS <O-7770'>,,8,Pad 30 2Z-Aug-91 30.2 525.0 525.0 Pr.~IS <O-8148'>,,?,Pad 30 27-Aug-91 53.5 550.0 550.0 PGMS <O-81T2'>,,6,Ped 30 2?-Aug-91 84.7 575.0 575.0 PGMS <O-8840'>,,5,Pad 30 27-Aug-91 101.9 601.0 8650.7 PGMS <O-8984'>,,4,Pad 30 2?-Aug-91 130.? 600.0 600.0 PGMS <O-9140'>,,3,Pad 30 2?-Aug-91 162.4 525.0 525.0 PGMS <O-10420'>,,2A,Pad 30 2?-Aug-91 189.4 200.0 200.0 PMSS <203-5?18'>,,2,Pad 30 2?-Aug-91 183.9 525.0 525.0 Pr.~Is <O-917'5'>,,1,Pad 30 2?-Aug-91 214.4 500.4 500.4 20 Version #'5,,20,Pad 30 12-Mar-97 60.0 200.0 200.0 For: D PETRASHi ARCO ALASKA, Inc. Structure : Pad 30 Field : Kuparuk River Unit Well : l g Location : North Slope, Alaska 196.67 DeE Az (5763' TO TARGET) ***Plane of Proposal*** 2000 I <- West (feet) 1500 1000 500 I I I I 400 800 1200 1600 2000 -~ 2400 2800 .+-- ¢'"h 3200 · -- 3600 4000 4400 I 4800 5200 5600 6000 6400 6800 7200 RKB Elevation: 64' KOP 1'VD=500 TMD=JO0 DEP=O 3.00 BEGIN TURN TO TARGET 15/0=500 TMD=500 DEP=2 6.95 8.86 I 1.2.5 13.88 15.63 19.46 DLS- 3.00 dee per 100 ft 22.33 25.22 28.14 31.07 34.02 .39.93 B/ PERMAFROST TVD=1664 TMD=1765 DEP=428 45.86 EOC TV0=1884 TM0=2068 OEP=636 EST. SURFACE LOCATION: 910' FNL, 1949' FWL SEC. 22, T13N, R9E Begin Turn to Tan Base Permafrost EOC Top Ugnu Sands Top West Sok Sands Base West Sok Sands 7 5/8 Casin( T/ UGNU SNOS TV0=2679 TM0=3253 DEP=1515 MAXIMUM ANGLE 47.87 DEG T/ W SAK SNDS TV0=3388 TMD=4310 DEP=2 TARGET LOCATION: 1151' FNL, 296' FWL SEC. 27, T13N, RgE TARGET Companion T. Sands TVO=6559 B/ W SA~ SNOS TVD=3830 TMD=4969 DEP=2787 TMD=9008 DEP=5763 Base HRZ Tt~n-~'~=-~ n~-,~ =,-mo ~",.'"~ SOUTH=5521 le Oro,~ 7 5/8 CSG PT TVD=4050 .... - ........ o,.,uu ,,l>~,,x WEST=1653 ) ~ TARGET - A3 Interval (EOD ~ Bose Kuporuk Sands % I 1539' FNL, 237' FWL I ~ t SEC. 27. T13N, RgEI CAMPANIAN T SNDS TVD=5821 TMD=7957 DEP=4988 8/ H~3 TMD=8477 DEP=5388 BEGIN ANGLE DROP TV0=6276 TMD=8615 DEP=5491 K-1 MARKER TVD=6280 TMD=8621 DEP=5495 T/~8 TMD=8771 DEP=560¢ T/ UNIT C TVD=6468 TM0=8887 DEP=5684 T/ UNIT B TVD=6500 TMD=8931 DEP=5712 T/ UNIT A TVD--6551 TMD=8998 DEP=5757 ~ v.,, TARGET - A3 INT (EOB) TvD=6559 TMD=9008 DEP=5763 '~¢2'17 B/ KUP SNOS TVD--6666 TMO=g148 0EP=5853 40 DEG I i t I I I I I I I I I I i i i i i i ~ i ! ~ i I I I I I 400 800 1200 1600 2000 2400 2800 5200 .3600 4000 4400 4800 5200 5600 6000 Vertical Section (feet) -> Azimuth 196.67 with reference 0.00 N, 0.00 E from slot #19 0 ] 500 Az 0 5OO Ia00 1500 2000 ~ o 2500 3000 ?~ I 3500 V 4000 4500 5000 5500 6000 8O 40 20 20 80 120 160 180 2OO 220 240 260 280 ~oo <- West (feet) 240 220 200 180 1 §0 140 120 1 O0 80 60 40 20 0 20 40 60 I I I I I I I I ~3700 ~300 ~ ~500 1500 5100 1400 1300 go0/ ,, ,' / /' / 1000,"' ,,"1200 ,' 1100,/ / / / / / / / / / 1200/ / / / " 2900 / , 3O00 ; ,, / 1300/ / , ,' / / / / / ,' , / / 400/ lO0 2100 600 .~ .......... 2600 70q,./' .," 2800 8og,'" ., 3000 80 60 40 20 L 20 1100 1000 900 60 3200 I 80 )t 0 2300 ~400 ~ ~00 250 Od 150 2700 120 I I ~40 V 160 ~ 18O 700 200 900..,,.~ / 220 / 1000..Q~''''~ / /,/~ 240 2~0 580~'~~°Uu , , · ] i I i i 2~o 220 200 1so 1~o ~,,o ,~o' ,;o' & ' ~'o ,4 ~'o ~) 2'o ,4 ~o <- West (feet) [c,~ ~,-~ For: D PL~RASItl ~3~ ~e~ ~ 3-1.l~-9 7 ~ I At, CO ALASKA, Inc. Structure : Pad 50 Well : 19 Field : Kuporuk River Unit Location : North Slope, Alaska <- West (feet) 400 580 360 A40 ~20 ~00 280 260 240 220 200 180 ~ 60 140 ~ 20 ~ gO J , i i : i i ; · 320 i 540 360 ~ 580 ~ ! 400 --~ 420 ~ ~40 4 ~ 460 1 r-- ~ 480 -I a ~oo q I v i 520 4 540 J 560 1 580 4 600 l 620 q 640 q 660 j 1600 1700 / .~00 1800 / ! / / ! / / / / / / / ,, / / / / / / / ,, / / / / / / / / / O0 2000 <- Wesf (feet) 300 320 6800..~./ f 340 360 380 400 42O t a40 460 --,i- 480 ~- 500 I [- k 520 540 L 560 580 600 620 640 660 KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 3 2 DO NOT SHUT IN DIVERTER AND VALVES AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE 4. 20'- 2000 PSI DRILLING SPOOLWITH TWO 10' OUTLETS. 5. 10' HCR BALL VALVES WITH 10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20' - 2000 PSI ANNULAR PREVENTER EDF 3/10/92 7 , 6 5 4 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"- 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 1 3-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR 13 5/8" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER 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 BO-I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVESTO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY C(:X;KS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NOTE: PRIOR TO DRILLING OUT OF THE INTERMEDIATE CASING SHOE THE BOP STACK TEST WILL BE CONDUCTED AS DESCRIBED ABOVE, BUT WILL BE TESTED TO 5000 PSI HIGH. ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL ALSO BE TESTED TO 250 PSI LOW. WELL PERMIT CHECKLISTco. / . _o .~,,L %~Lg~ ./~_~ 3 O- / ~ PROGAAM: expr'l dev~redrln servE] wellbore segFI ann dis[:) para reqE] ADMINISTRATION ENGINEERING 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ..... N 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party ............. . N 10. Operator has appropriate bond in force ........ ' N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. Can permit be approved before 15-day wait.' ...... N REMARKS APPR D E 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y ~ 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 abndnmnt been approved. 22. Adequate wellbore separation proposed .......... ~ N ~ 23. If diverter required, is it adequate .......... ~ N ~ 24. Drilling fluid program schematic & equip list adequate .~/ N 25. BOPEs adequate .................... ~ N 26. BOPE press rating adequate; test to ~-~ psig.~ N 27. Choke manifold complies w/A_PI RP-53 (May 84) ...... (J/ N g~'/ 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ O N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... /. Y N 34. Contact name/phone for weekly progress reports . . W . . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~1 mcm Comments/Instructions: HOWldlf- A:\FORMS\chekiist rev 01/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. I I I I I I I I I I I I I I I I I I I e e Memory Multi-Finger Caliper "...' Log Results Summary lfì,<f\¡J\L\{ l (.-o~ Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska¡ Inc. November 9, 2005 6037 1 4.5" 12.6 lb. L-80 Tubing & Liner Well: Field: State: API No.: Top Log IntvI1.: Bot. Log Intvl1.: ,,1Q,4Ø. Kuparuk Alaska 50-029-22753-00 Suñace 8,912 Ft. (MD) \S'" -bSO Inspection Type: Co"osive & Mechanical Damage Inspection COMMENTS: ~~ S\)S-~'( \ 4\)~ ~(J~-(:)S' This caliper data is tied into the IIDB" Nipple @ 8,729' (Driller's Depth). This log was run to assess the condition of the 4.5" tubing and.lipt¡!(with respect to corrosive and mechanical damages. The.4.5D tubmgappears in good condition·l.'.itÞI .~t'Ìtftð'~!d~~age, with no wall penetratioœ.inexcess of 15%. The 4.5" liner logged appears to be in good to fair'OOndition with respect to corrosive damage. A 32% walt pene1ration is recorded in short joint 175.3 located below the patch (5,487'). The damage recorded in the liner appears in the forms of scattered pitting, lines of corrosion and a few areas of general corrosion. No significant areas of cross-sectional wall loss are recorded throughout the tubing and liner interval logged. Deposits are recorded in the interval between joints 255 and 286 (7,900' - 8,912') ofthe liner, with no significant I.D. restrictions in this interval. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WALL PENETRATIONS: Line of Corrosion ( 32%) Jt. 175.3 @ 5,487 Ft. (MD) Line of Corrosion ( 30%) Jt. 212 @ 6,616 Ft. (MD) Line of Corrosion ( 30%) Jt. 277 @ 8,604 Ft. (MD) Line of Pits ( 29%) Jt. 276 @ 8,563 Ft. (MD) Isolated Pitting ( 28%) Jt. 281 @ 8,725 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions other than the Patch (2.38") are recorded throughout the tubing and liner logged. ~^N~~f.[) .., Ie I Field Engineer: D. Cain Witness: C. Fitzpatrick I Analyst: M. Tahtouh ProActive Diagnostic Selvices, rne. ¡ P.O. 80:< 1369, Stafford, TX 77497 Phone: (281) IX (888) 565-9085 Fa:<: (281) 565-1369 E-mail: PDS«¡)memorylog.com Prudl"loe Bay Field Office Phone: 659-2307 Fa,,: (907) 659-2314 RECEIVED NOV 1 6 Z005 AJ@fkl ail & Gas Cons. commission Anchorage I I I Well: Field: Company: Country: 30-19 Kup<uuk ConocoPhillips Alaska, Inc. USA I - - --------------~~~ [~LJ_~¡~g;- 4N50~~OD Weight 12.6 ppf Grade & Thread L-80 I ---~~-~~--~- Penetration ami Metal Loss (% wall) I penetration body metal loss body 200 I 150 100 I 50 I 10; 10 I to 10% 10 to 20% 20 to 40 to over 4CYYÒ 85% 85% I total = 297) 20 0 0 000 I Damage (body) 80 I 60 40 I 20 o I Isolated pitting genera! ImE' nng hole / JOSS corrosion (011'0510n CüiTOSlon ¡ble hole Number of 'oints damaged (total = 83) 64 6 13 0 o I I PDS Report Overview Body Region Analysis Survey Date: rool Type: rool Size: No. of Fingers: Nom.ID 3.958 ins Nom. Upset 4.5 ins ^^^^^~....~,,-- penetration body o o Bottom of Survey = 286 Analysis Overview page 2 I I November 9, 2005 MFC 24 No. 99628 169 24 Upper len. 1.2 ins Lower len. 1.2 ins ---_.^-^.._-,........~~ Damage Profile (',/" wall) metal loss body 50 100 48 98 148 192 242 I I Pipe: Body Wall: Upset Wall: Nomina! I.D.: I I I I I I I I I I I I I I Correlation of Recorded Damage to Borehole Profile 4.5 in 12.6 ppf 1.-80 0.271 in 0.271 in 3.958 in ') r.- ~.) 50 75 100 125 150 Qj 175 ...Q E ::; z 20D '») !':" ~~.) 250 275 286 0 I Bottom of Survey = 286 I I Well: Field: Company: Country: Survey Date: 30-19 Kuparuk ConocoPhiUips Alaska, Inc. USA November 9, 2005 Appro,. roo! Deviation Appro" Borehole Profile 50 Damage Profile (Yo wall) / rool Deviation (degrees) 4 756 1521 2290 3054 3819 4587 5397 .¡.; u... c ..c 6220 ...., Q.. (!J 0 6980 7747 8516 8886 100 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SHEET Pipe: Body WaU: Upset WaU: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in 30-19 Kuparuk ConocoPhiliips Alaska, Inc. USA November 9, 2005 Well: field: Company: Country: Survey Date: --~-~ joint Jt. Depth Pen. Pen. ppn. Mp Ld Min. Damage Profile No. (Ft.) Body I.D, Comments (%waU) I (Ins.) (Ins.) 0 50 100 .1 1 U 0,00 I I 3.93 PUP I I 4 U CLOO 1 I 3.94 2 35_ U 0.01 i I 3.92 3 66 U 0.01 i I 3.92 4 96 U 0.01 i I 3.93 5 127 0 0.01 ) I 3.93 6 159 U 0.01 :; ) 3,92 _:L._. ......... 1 90 U 0,00 ¡ -~ ...J.. 92 __J5...._ 221 u . 0.01 2 ) 3,94 ~..._-~._." U I J 9 ') '" ') 0.00 3.94 ....J.... 10 282 0 OJ)I :; ;> 3.94 3 .8 osits I 344 ! 0.01 ;> 3.92 I 375 0.ü1 ) 406 I 0.00 I 437 I 0,01 I 1 468 1 0.01 I) PUP I' ) 473 0 U 3,81 DB Nipple I 3 474 0.01 I 3.84 Flow 1 480 0.01 ) 3.92 I 17 511 0.01 J }8!i ~.. 541 0 0.01 I 3.92 ...J.2... _ 5/2 0 CU)l J 3.93 20 603 0 0.01 J 3.92 .. .21.. .. .. . E04.. I) 0.01 1 3.92 .. 22 ..... 664 0 CLOI ) 3.93 23 694 U 0.01 I 3.92 24 725 0 0.01 I 3.91 25 756 0 0.01 ) 3.92 26 787 U 0.01 :; :2 3.92 27 818 0 OJ)l 4 :2 3.92 28 848 0 0.00 I ) 3,91 29 879 0 (101 :I I 3.94 30 910 0 0.01 ;> I , 3.92 31 940 0 0.00 ;> 3.92 32 971 I 0.01 4 I 3.92 33 1002 ( 0,01 -: ) 3.91 34 1032 U 0.01 :I I 3.92 35 1063 I 0,01 3 ) 3.92 36 1093 0 Q,Ql 'j ¡ 3.93 -,.., 1123 ( 0.01 . ... 2 ) 3.93 .)J 38 1154 I 0.01 5 I 3.87 ~ 39 1185 0 0.ü1 3 ) 3.91 40 1216 C 0.01 3 I 3.94 41 .1247 0 0.01 5 1 3.93 ~ ~- _12}7 0 0.01 :I I 3.91 4-' 1310 0 0.01 3 I 3.84 J ~~_____'M.____~_____~______________.__~~_____~___ 44 1340 0 0.00 I ;> 3.93 45 1371 0 0.01 3 I 3.93 46 1401 (I 0.01 3 ) 3.92 Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION S EET Pipe: Body Wall: Upset Wall: Nomina! I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 30-19 Kuparuk ConocoPhíHips Alaska, Ine. USA November 9, 2005 I Pel Pen. ;\1eLII ---~ .. ~^^^-~_.~- Joint Jt. Depth Pen. ~E I Damage ProtÎle No, (Ft.) '1 Body I. Comments (%wall) ( ! (Ins,) (Ii 0 50 100 47 1431 n 0.03 12 2 . 3.82 Shallow nittim" fill 48 1459 n 0.01 II I 3, ~¿~? I-- 49_ ~1490 ._ n 0.01 2 ) 3.92 50 1521 !ì 0.01 2 ...L _¿93^.~.. ¡.... 51 1551 I i 0.01 2 4 . 3.92 ~ ') 1583 n om I¡ ) __l92~._ .)- ~~.~-- ~.~- 1--- 53 1613 n om 4 :> 3.92 54 1644 n 0,01 3 I 3.94 ~~.- 55 1675 n 0.01 ') :> 3,03 56 1706 om 3 I 3.90 I 57 1736 0 = ¡ ..2.89 58 1767 0 ) 3.93 _ 59~ ~1797 n 0.01 2 3.90 60 18)7 Ii 0.01 2 3.93 1858 0 0.01 I 3.91 1889 n 0.01 ') 3.84 1920 n 0.01 :> 3.92 1950 n om ') 3,92 65 1981 0 0.01 3.92 66 2012 n 0.01 3.93 67 2043 0 0,01 4 3.91 68 2073 0 0,01 - 3.92 I 69 2106 (1 001 { '\ gq .. 0 2 3,92 70 2137 0.01 ~ -. 71 2JJill.~ 0 0.01 -I 3.94 ~ 11- ~. 72 2199 0,00 .. :> ...1.9 1 _LL. 2229 ( 0.01 4 3.93 74 2260 1 0.00 4 3.92 75 ...l.2 9º 1 iW.L , 3.59 '~~7 6- 'J .. 232) ¡ 0.01 3.92 ..........77. 2354 i 0.01 3.94 78 2384 , i 0.01 3.94 . ...12....... 2414 0.00 3.92 .. 80 2445 ¡ 0.00 3.88 81 2475 1 0.01 3,90 ._~-~~.~ II 52 2504 ¡ 83 25-1') i 84 2566 i 85 2595 i 86 2625 i 0.01 ) ..3.9L 87 2656 0 0.01 { 3.92 58 2687 n 0,01 3 ) "';'Q4 89 2717 0 0.01 S ) ...3.90. 90 2747 n 0.02 7 :> 3.92 II . i ) ~ ~--~-~-~---------~------~~ .._----~. ..~~~- 91 2777 II .. om 3.03 92 2808 '~'II- 0.01.. ,-~ I 3.93 _.~...... 93 2839 n om 2 ) 3.93 CJ4 2869 . II 0.01 I ) 3.92 95 2900 n 0.02 ...~~. 3.90 II 96 2931 n 2 ... .JtOl 3.93 Body Metal Loss Body Page 2 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION S EET Pipe: Body Wail: Upset Wail: Nominal 1.0.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in Well: Field: Company: Country: Survey Date: 30-19 Kuparuk ConocoPhiHips Alaska, Ine. USA November 9, 2005 I It. Depth Pe, Pen. Mf'tal ~^^~- "--~~ ~ ^^^^~^ Damage Profile joint Pen. Min. I No. (Ft.) { J¡he! Body !.D. Comments (%wall) ( : (Ins.) (Ins.) 0 50 100 2962 I D \ ¡ -.--.-- 97 0.ü1 3.83 ..~-,-^- ~~M~___ 98 2991 I D 0.01 4 ) 3.90 99 3Q23 \ 0.ü1 ) ) 3.94 100 3054 \ 0.00 I \ iff) 01 3084 í OJ}! ¡ I L9') 3116 ±=it= . 0.01 ) ) 3.91 - M'_ , ._-~~.- 3147 0.00 1 3.94 ... . 3178 D _().01 2 ¡ 1.89 3208 D 0.00 1 ) 3.92 ~,-_.- .~J 06....... 3238 () 0.01 ) I 3.94 .~.~.~...- D I .~,-,--,-,....,-- . .. .................-- 107 1268 0,00 3.95 108 3299 D 0.01 I 3.94 -. ~~ .~-- 109 3310 D 0.01 I 3.94 110 3361 .. D 0.01 I 3.95 3392 )l ) 3.94 I 3423 )l 3 3.92 3453 I )0 ) 3.91 3485 )1 I 3.94 3515 0.01 ) 3.96 _J1.f.2... ,')44 . 0.ü1 ¡ 3.95 ~._~------ JIZ 3572 0.01 ! 3.95 I m_._._ m_....__ 118 3603 0.01 ) 3.95 ...--- 119 3634 0.01 I 3.95 --'-'~... ~-,---- .. 120 3665 Q.ü1 ++ . 3,94 I---~ -- ----- --~._.,-,------- 121 1f>96 \ JWI 3.94 -.--- -. . p7 3726 D 0.01 1 3.91 D ! .. 123 3757 0.01 3.95 D I m___._.__n_ 124 3788 0.01 3.95 ~.. .. --.- 125 3819 n O.O.L 1 3.95 D I ~----- '_"_m_'_'__ ~ 126 3851 0.01 3.95 127 3881 n 0.00 3 3.93 128 3913 n 0.01. ~I 3."5 ~29 \I .. - ..--.-, 3943 0.01 3.88 3973 \I _m____ .~ 130 0.01 .. 3.9L 1 40¡),\ \I 0. ...-..,.----- - ....-- 1 4012 D OJ .i L 4065 () O. 1 1 4095 ( OJ ¡ 1 4126 () OJ I 136 4157 ( 0.ü1 I 3.91 ----~---------- I 137 4187 ( 0.ü1 'I I 3.96 . ---,~-- . _.~.------ 138 4218 () 0.02 B I 3.92 iii! 139 .. 4249 ( 0.01 " I 3~~15 ~._- 140 4280 () 0.02 7 2 3.90 !If! 141 4310 \I 0.00 1 ) 3.90 I 142 4342 \I 0.01 ) I ,\.94 143 4372 () 0.ü1 ) ) 3.94 144 4404 () 0.ü1 :¡ I 3.85 145 4433 () 0.02 8 ) 3.90 !II LJ 4f>. 4464 D CLOO ) ) 3.96 Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION SH Pipe: Body Wall: Upset Wall: Nominal I.D.: 4.5 in 12.6 ppf L-80 0.271 in 0.271 in 3.958 in 30-19 Kuparu k ConocoPhillips Alaska, Inc. USA November 9, 2005 Well: Field: Company: Country: Survey Date: Joint Jt. Depth Pen Pen. Pen. !¡/¡et:1 Min. Damage Profile No. (Ft.) I Body IÜ Comments (%wall) (II I (Ins.) (Ins.) 0 50 100 147 4495 n 0.02 ( I I 3.91 148 4526 0 0.02 I 3.92 149 4557 0 0.03 I >'.96 Shallow nittil1\2'. ~ 4587 0 0.02 I 3.96 151 4618 0 0.01 I 3.95 ..152.... 4648 0 CUB 10 3.96 I!iIi 153 4679 0 0.03 10 I I 3.92 I!iIi 154 4709 U CUB 13 I _~?~'l4 Shallow nittimL I!iIi 155 4741 U 0.04 14 2 3,96 Shallow nittimL I!iIi 156 4771 I) o,l):f 10 I 3.97 I!iIi -- -- 157 4802 U n.Ol 3 --¡- :t.'lL 158 4833 I) 0.02 B 2 3.95 II! 159 4864 I) 0.01 3 ¡ 3,94 160 4895 I) 0.04 15 I 3.94 Shallow nittilh:!. 11II 161 4926 II 0.04 15 I 3.91 I Shallow nittim:!. II! e- 162-- 4954 I I) 0.02 8 1 3,92 I II! I 163 4985 I 0.03 12 4 3.92 Shallow Dittim,. (S I 164 5017 U 0.01 4 I 3.95 ...JJ,4.1 _ ~ t¡ 0.00 1 I 3.94 PUP -~,~ 0 I) 0 Slidilh:! Sleeve ..l04.2_ 5054 ... 0 3.81 ~()_4.1 _21129. 0.01 \ I 3,92 PUP 165 5065 ( ~1- 14 2 3.94 Shallow nittill\:!. 165.1 5096 I 3.93 PUP 11II 165.2 5106 0 0 I 0 3.81 PACKER I ...l65.3 5113 I I· I 3.96 PUP 166 5122 0 ¡ 3.95 1 st loint of 4.5 Liner 167 5152 0 ~ ~._..... ¡ 3.95 168 5183 0·11 I 3.94 Shallow Dittim~. 169 521~L 0.04 ') ],95 Shallow nitting. 5244 0.04 4 3.94 Shallow Ditting. 0.04 ¡ ;L9.Þ_ Shallow pitting. I 0.04 ¡ u.~:i.92. Shallow Ditting, I. 0.03 í 3,88 Shallow Dittim:t Lt. DeDosits. í Shallow Ditting, ---~ __~m'______"._........."_ . L ( 0.05 3.95 7 ¡ O. 15 2 3.95 Shallow Ditting. ~ 1 75. I O. )I ~6 I SIom' It 175. U 2.3ST PATCH "175.3 U O. )9 2 3.97 I Short It. Line corrosion. II 176 II O. 15 8 ___..3.96 -or Line of shallow corrosion. 177 5521 I) 0.02 II 3..96.. ___ 178 5551 0 0.02 í 3.96 179 5582 ) 0.01 3.95 180 5614 I 0.03 10 'j 3.88 181 5643 j 0.01 I 3.90 182 5674 ) 0.03 I 3,87 11II 183 5704 U 0.02 2 :'L90 11\I 1ST>, 3 .. n ') ~ -~ - Slnllow Ditting. 11II 184 0.03 I 3.97 185 5764_ {I 0.02 3.94 11\I I 186 5795 () CLOI -- 3,95 187 - 5826 () 0,01 3.90 Body Metal Loss Body Page 4 I I I I Pipe: Body Wall: Upset Wall: NominaILD.: Joint No, t Depth F (Ft) I I I I I I I I I I I I I I ~ I PDS REPORT JOINT TABULATION SH 45 in 11,6 ppf L-80 0.271 in 0.271 in 3,958 in Pen, ppn. :\!¡p !;ì 1 Body (Ins,) 11 0.02 9 :: +-¿fflt+-~fu o 0,01 4J o OJ)1 5 I o OD310 1 11 (UJl 3 1 11 OJBIO ¡ o . 0.02' 91 o 0,0311 I I 0,03 9 2 I 0.01 -. 4 2 (UBI I 0.01 3 1 (102 8 ¡ g:;.~1.r±t± 0.ü1 4 1 0.0518 2 0.ü1 ¡ O,(J2 0.02 0.04 0.02 0.08 0.03 OJ) 1 0,()4 0.03 0.04 (t03 0.03 0.03 0.04 0.03 0.03 0.0413 0.0413 0.0311 0,041.1 o JJ3 H) 0.04 17 0.0414 0.03'~~1 0 0.0415 0.03.10 0,0414 (104 13 (10414 0.0310 ~. () () I) II () () ¡) ¡\ I) I) II o \I II \I II o 3.93 ....3.92 ) .1.2.Q 3·(F 3.90 ~. 3.93 3.93 3.92 3,92 3,Q3 Min. I.[). (Ins.) Well: Field: Company: Country: Survey Date: 30-19 Kuparuk ConocoPhillips Alaska, Inc. USA November 9, 2005 Comments 3,95 3.94 .~._._ 3.97 3,98 3. 3. 3. 00 Shallow pitting. 3,91 3.94 ').96 Shallow- n¡ttinQ..··--~ 3,95 3.96 Line corrosion, 3,96 3.97 3 ~2L .21ElIlmYJ:¡ittirl&.._. 3.95 3.93 3.% 3,94 3.<:)8 .97 Shallow pitting. .90 .95 .87 .93 .95 4 1) HI II 4 13 1\1 1 1 1 ¡ .; ) 2 i 1 I ¡ ..1 '2 2 1 .1. i :2 4 ¡ 2 2 3.93 3.91 3.89 3.94 3.93 3.97 3.94 3.95 3,% 3.95 3,95 Shallow pitting. SI1allowJ)itting. ShaIl9.\iY.J2Ítting. _~___ Shallow nitting,-__.~____ la ow n ttiml. la ow n ttiml. la ow n It ng, la ow Dining. Shallow oittilw. Shallow oittiml. 5.b.allow pi t!ÍlliL...... ---~----------- ~~~ ~-~--- Line shallow corrosion. Shallow oittimz. Shallow oittiml:. Page 5 Damage Profile (%wall) o 50 100 !III I I II 1&1 1&1 !III .~ II. !III" !III !III" fII! !III" !III !III" !III .L 188 5857 189 5887_ --.l:)JL _ 5916 191 5947 192 5976 193 6006 194 6037 J 9L. --º()66~ ~J96_~ 6096 197 6126 198 61?J'> 199 61 89 200 6220 201 6251 ,202 6282 203 6313 204 6343 205 6373 206 6405 207 6435 11 208 6466 I _209 6496 \I __210 6527 I _411._ ..6557 11 212 6586 I 213 6617~' I 214 6648 {) 215 6678 {) 216 6709 \I 217 6740 {) 218 6770~ {) 219 6801 {) I 220 6831 {) 22 1 6860 222 6891 223 6922 224 6952 225 6980 2. 7012 2. 7042 2. 7073 2 7104 230 7134 23 7166 232 71% 233 7227 234 7258 235 7288 236 7317 237 7348 Body Metal Loss Body I PDS EPORT JOINT TABULATION S I Pipe: 4.5 in 12.6 ppf L-80 Well: 30-19 Body Wall: 0.271 in Field: Kuparuk Upset Wall: 0.271 in Company: ConocoPhil!ips Alaska, Inc. I NominaILD.: 3.958 in Country: USA Survey Date: November 9, 2005 I I loint )t Depth Pen. Pen. PI'n. ,\1et11 Min. Damage Profile No. (Ft.) pset Body !.D. Comments ('10 wall) C I (Ins.) (Ins.) 0 50 100 i I 238 7379 _____'1 0,03 3 3.96 'rJ,() 7409 0 0.03 I ) 3_88 ___ ___51Bllow Dittim!.. 74n 7419 (I 0.03 I ) 3.96 n ~,~^ 241 7471 I 0.04 3 _.J5>l Shallow Ditting. I 242 7~02 I. 0.02 q ) 3,91 ~--^- I 243 7531 ( 0.03 I ¡ 3_9.3 244 7564 I 0.03 I I 3.97 245 7594 0,03 !. ìa[lg}y_ Ditting. I 246 7624 , 0.03 lallqw _Ditting. , I 247 7655 0.04 3.9L Shallow pitting. __n___ 2411 7685 0.03 3.95 Shallow Iili!iDK____ ~-~-~----- 249 7717 ( 0.03 3.96 Shallow Ditting. 250 7747 , 0.04 3.93 Shallow pitting, Lt Deposits. I 25! 7778 ( 0.05 3.90 Shallow pitting. Lt DelH)sits, 252 7808 0.04 3.95 ,_Jlltl! 1M. Lt. -.. 25'i 7839 (I o,m w 3.94 Lt. Deposits. I 254 7870 () 0,0'1 ! 3.92 Shallow pitting. I I 2' 7900 (I 0.04 3.94 Lt. Deposits. 2' 7930 C 0.04 16 ) 3_92 Shal low C ittinQ. U. 2' 7960 () 0.04 14 ¡ 3JJ8 I t. r )pnnsit" I 2' 7991 () 0.04 15 ) I .:1.9l1. Shn low 'I ittil1Q. I t. bnn ik 259 802! () O.OQ__ 20 4 3.90 Iso!atf'd II ittinQ. I t. )pnn"it" I 260 8053 () 0.04 1'1 4 ;-\.92 Shallow nittinQ. I t. I )pnnsit" 1------- 261 ~I 8084 0 0.04 14 ) 3.89 Shallow nittim:!_ I t. I )pnn"it" 262 14 (I 0.06 22 (I 3.96 Isolatf'd nittinQ. 263 45 (I 0.07 27 ) 3,95 Isolated pitting. Lt. Deposi~__.. I 264 8176 () 0.05 20 4 3.94 Isolated pitting. ._~-~...._._..~- 265 §207__ 0 0,04 13 ) 3,94 .5hallow pitting. Lt. Depo~i~'__n i----26(:, 8238 I) CL04 14 3 3.94 Shallow nittinQ. , I I 267 I ~~.....~ 0.07 17 3 3.97 Line 0 : nits I 268 83001 0.06 II ) 3.94 Line 0' nits. Lt. I 269 _ 8. 0.06 14 ) 3.96 Line o· Dits f----"'-,,-- 270 8. ) 0.06 3 3.94 Line or Dits 271 8.1 0.05 3 3.95 Shallow DittinQ. Lt. DeDosits. I 27( 0.04 3,9ï Shallow DittinQ. Lt. f)nnn"ik 27 0,07 .21 3.93 Isolated nittinQ. Lt. f)nnn"ik 27L (I 0.05 I 3.94 Shallow nitting. Lt IJpnn"ik >7' 0.04 3.87 Shallow Dittí,w. 27( 0.08 3,88 Line of QÌts. Lt. Deposits. 277 0,08 --- 4 3.93 Line corrosiQD. 278 R('()(' 0.07 ¡ 3.94 Line corrosion. Lt. Deposits. R6'17 4 Lt. - 279 0.06 3.89 Line of nits. ¡pnn",r<; 280 8667 0.07 _4 3.93 Line corrosion. Lt. Deposits. ~--- ~^ ^^^~---- 281 8699 0.08 3.96 Isolated pitting. ~~^ ^ 281.1 8729 0 3.75 DB NiDDle 21'12 8730 0.06 'I 3 3.90 Isolated pitting. Lt. DeJ2.Q.~its.____ 2R'i 8760 0.05 9 + 3.83 Shallow corrosion. Deposits. -_.__.^_._~ 284 8792 0.06 '! 3.82 Corrosion. Lt. DeDosits. 284.1 8823 ¡ OJ}7 '5 3 3.81 Flow CouDlim!. Corrosion, Lt DeDO$its. 2R4.2 8839 ¡ 0,04 ') 3.78 FlownC;;oupling Shallow corrosion. Lt. DeDosits, Body Metal Loss Body Page 6 I I I I Pipe: Body Wall: Upset Wall: Nominall.D.: I PDS REPORT JOINT TABULATION SHEET 4.5 in 12.6 ppf 1.-80 0.271 in 0.271 in 3.958 in I Joint No. I I I I I I I I I I I I I I I Min. I.D. (Ins.) 3.81 .3.81 Well: Field: Company: Country: Survey Date: Page 7 30-19 Kuparuk ConocoPhillips Alaska, Ine. USA November 9, 2005 Comments . Damage Profile l (%wall) o 50 ¡ 00 Body Metal I.oss Body .. .. .. .. .. Well: Field: Company: Country: Tubin : .. .. 30-19 Kuparuk ConocoPhillips Alaska, Inc, USA 4,5 ins 12.6 p f L-80 Cross Section Tool speed ~ 52 Nominal 10 ~ 3.958 Nominal 00 ~ 4.500 Remaining wall area ~ 98 % Tool deviation ~ 51 0 .. .. .. .. .. .. .. .. .. PDS R rt Cross S ons Survey Date: Tool Type: Tool Size: No. of Fingers: November 9, 2005 MFC 24 No. 99628 1.69 24 at depth 5487.21 7 ft Finger 3 Penetration ~ 0.088 ins Line of Corrosion .09 ins ~ 32% Wall Penetration HIGH SIDE ~ UP Cross Sections page 1 .. .. .. ------ ------- ------ PDS Report ross Secti ns Well: Field: Company: 30-19 Kuparuk ConocoPhillips Alaska, Inc. Survey Date: Tool Type: Tool Size: No, of Fingers: November 9, 2005 MFC 24 No, 99628 1,69 24 Cross Section Joint 212 6616.177 Tool speed'" 50 NominallD = 3.958 Nominal OD = 4.500 Remaining wall area = 99 % Tool deviation = 61 Q Finger 3 Penetration = 0.082 ins Line of Corrosion 0,08 ins = 30% Wall Penetration HIGH SIDE UP Cross Sections page 2 I KRU 30-19 I 'W" 130··ft9i API: 500292275300 Well Tvpe: INJ Anale (rI) TS: 39 dM Ii'ñ 8942 SSSVTvpe: NIPPLE OriQ Completion: 41811997 AnQle @ W: 38 dea @ 9415 Annular Fluid: LastWIO: Rev Reason: PULL PLUGS ~ RefloCl Date: Last Uodate: 1013012005 NIP (507-508. TD: ~.. 00:4.500) TUBING (0-5120, 00:4.500. Oescri Size - ...~ Bottom NO Wt Grade Thread 10:3.833) UK 16.000 0 121 121 62.50 H-40 SURF. CASING 7.625 - 0 5350 4024 29.70 L-80 LINER 4.500 5120 9407 6816 12.60 L-80 I Tl.ibindSt,.il"[ci'..'I·:UI:SINli:i:: i Size 1 Top 1 Bottom I NO 1 Wt 1 Grade 1 Thread SLEEVE 4.500 0 1 5120 I 3875 1 12.60 1 L-80 1 NSCT R-2 (506&-5069. / 00:4.500) Interval TVD lone Status Ft SPF Date I TYDEI CommElnt SURF. CASING 9072-9086 6554: 6565 A-3 14 6 411311997 IIPERF 13-3/8" HSD Csg Gun: 60 deg (0-5350. ---- "_.." 1 1 phasino 00:7.625. 9100 - 9120 6576 - 6592 A-2 20 6 411311997 IPERF 3-3/8" HSD Csg Gun: 60 deg Wt2970) 1 phasina ~:9201 ~- 6647 - 6655 A-1 10 6 4/13/1997 IPERF 3-3/8" HSD Csg Gun: 60deg-~ Inh,,"inn /êâûiô,êt1 ;,í,.I;¡'IM¡;:¡:c 'M PKR OeDth ND Tves ID (5120-5121. 00:7.000) 507 1- '507 NIP Cameo 'DB' GO 3.813 H SLEEVE Baker 'CM' Sliding Sleeve: Closed 9/10/97 3.813 LINER 3875 PKR Baker 'SABLMIZXP' 3.812 (5120-9407, 4098 PATCH HES 3.8" OD PATCH 24.8' LONG W/2.375" ID SET¡¡¡9/2oo2 2.375 00:4.500, Wt12.60) NIP Cameo 'DB' Nipple NO GO ._"~. _..~"" M~'___ 3.750 8928 1 6443 PLUG PLUG set 8/1812002 0.000 8928 1 6443 PKR HES PACKER XN NIP::it: ö/>j/:ðJU¿ 2.313 1 iNÎ:itê$ Dats Note _.._~~, 6/4/2001 LEAKfound @ 5475' MD (PATCHED) 8114/2005 EXTERNAL CASING PATCH INSTALLED AT BOTTOM OF CASING MANDREL HANGER. SLEEVE PATCH: 27" LONG x 8", X65 PIPE 1917/2005 CASING lEAKVERlF¡l:õD @5513' ~ ~..,---~"~"'-- PATCH ~- -...-... ~ (5461-5486, 00:3.500) NIP (8729-8730, 00:3.833) PKR -~. (892&-8929, 00:3.958) Pelf .---.. ."- (9072-9086) ---.. ~_.. ...--. I~· ---~ I--- -.. f..-~ ---- __nW Pelf ~- -~ 1 (9100-9120) ..-_.. f..-.. _.~ 0-...... ..-... .~... ~ ... ~ :::=:=: Pelf ~. (9191-9201 ) ..- ~.. ----- ~ -- ~_.. --.- - -.. - I I I I I I I I I I I I I I I I I Date_OI-o3 -- * ALASKA COMPUTING CENTER * . * . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 30 - 19 FIELD NAME : KUPARUK RIVER UNIT BOROUGH · NORTH SLOPE STATE : ALASKA API NT]ZVI~ER : 50-029-22753-00 REFERENCE NO : 97199 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: **** REEL HEADER **** SERVICE NA~IE : EDIT DATE : 97/05/ 7 ORIGIN : FLIC REEL NAIVE : 97199 CONTINUATION # PREVIOUS REEL : CO~NT : ARCO ALASKA INC, KUPARUK, 30-19, API #50-029-22753-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97199 CONTINUATION # : 1 PREVIOUS TAPE : COf~4~NT . ARCO ALASKA INC, KUPARUK, 30-19, API #50-029-22753-00 TAPE HEADER KUPARUK RIVER UNIT CASED HOLE WIRELINE LOGS WELL NAME: 30 - 19 API NUMBER: 500292275300 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUmbERGER WELL SERVICES TAPE CREATION DATE: 7-MAY-97 JOB NUMBER: 97199 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: RANDY BLACK SURFACE LOCATION SECTION: 22 TOWNSHIP: 13N RANGE: 9E FNL : 910 FSL : FEL: FWL: 1949 ELEVATION (FT FROM MSL O) KELLY BUSHING: 65. O0 DERRICK FLOOR: 65. O0 GROUND LEVEL: 23.10 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 7. 625 5350. 0 29. 70 2ND STRING 4. 500 5120. 0 12. 60 3RD STRING 4 . 500 9407.0 12.60 PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: NONE LDWG CURVE CODE: NONE RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH $ REMARKS: THIS IS THE PDC LOG FOR THIS WELL. THE DATA WAS LOGGED ON CBT 13-APR-97. NO DEPTH SHIFTS WERE APPLIED TO THIS DA TA . $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE ' FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE AKIMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: ! DEPTH INCREMENT: 0.5000 FILE SO?4MARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9218.0 6493.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: NONE PASS NUMBER: BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH ....... REMARKS: THIS IS THE CLIPPED DATA FROM THE CBT GR (PDC) LOGGED 13-APR-97 BY SCHLUMBERGER. NO DEPTH SHIFTS APPLIED. LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 100736 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH GR GAPI 100736 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CR LB 100736 O0 000 O0 0 1 1 1 4 68 0000000000 CCL GR V 100736 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9255.000 GRCH. GR -999.250 TENS.GR 5085.000 CCL.GR DEPT. 9000.000 GRCH. GR 61.281 TENS.GR 4470.000 CCL.GR DEPT. 8000.000 GRCH. GR 88.625 TENS.GR 4085.000 CCL.GR -999.250 O. 082 -0.104 DEPT. 7000.000 GRCH. GR 71.750 TENS.GR 3605.000 CCL.GR -0.029 LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: DEPT. 6493.000 GRCH. GR 78.063 TENS.GR 3365.000 CCL.GR -0. 031 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 0 O1 CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH STOP DEPTH 9255.0 6493.0 GRCH $ LOG HEADER DATA DATE LOGGED: I 3 -APR- 97 SOFTWARE VERSION: 44.2 TIME LOGGER ON BOTTOM: 1300 13-APR-97 TD DRILLER (FT) : 9250.0 TD LOGGER (FT) : 9255.0 TOP LOG INTERVAL (FT) : 6493.0 BOTTOM LOG INTERVAL (FT) : 9255.0 LOGGING SPEED (FPHR) : 1800.0 DEPTH CONTROL USED (YES/NO): NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: GR GA~A RAY $ SGC-50 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 5350.0 5350.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : SEAWATER/DIESEL 2.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): RE~ARJfS: TIED IN TO SPERRY EWR4 LOG DATED 4/6/97. CENTRALIZATION WAS POOR IN 4 1/2" TUBING WITHOUT GEMCO CENTRALIZERS (UNAVAILABLE). ONE TRANSMITTER WAS W~, BUT CUSTOMER ELECTED TO LOG WITHOUT CHANGING SONDES SINCE THE VDL WAS GOOD AND SHOWED THE TOP OF CEMENT. TOP OF CEMENT WAS AT 7200'. CEMENT DATA: 10 BBLS SPACER FOLLOWED BT 340 SACKS OF CLASS G W/ 3~ D053, .12% D800, .8~ D065, 1.5% SO01, .1 GPS $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 $ 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELM CODE (HEX) DEPT FT 100736 O0 000 O0 0 2 1 I 4 68 0000000000 GR PS1 GAPI 100736 O0 000 O0 0 2 1 1 4 68 0000000000 TENS PS1 LB 100736 O0 000 O0 0 2 1 1 4 68 0000000000 CCL PS1 V 100736 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9267.000 GR.PS1 80.750 TENS.PSI 2045.000 CCL.PS1 DEPT. 9000.000 GR.PS1 61.281 TENS.PSi 4470.000 CCL.PS1 DEPT. 8000.000 GR.PS1 88.625 TENS.PSI 4085.000 CCL.PS1 DEPT. 7000.000 GR.PS1 71.750 TENS.PSi 3605.000 CCL.PS1 DEPT. 6487.000 GR.PS1 80.188 TENS.PSI 3340.000 CCL.PS1 -0.076 0.082 -0.104 -0. 029 O. 037 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 7-MAY-1997 11:34 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 7 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NA~E : EDIT DATE . 97/05/ 7 ORIGIN : FLIC TAPE NAME : 97199 CONTINUATION # : 1 PREVIOUS TAPE CO~ENT : ARCO ALASKA INC, ICUPARUK, 30-19, API #50-029-22753-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 7 ORIGIN : FLIC REEL NAME : 97199 CONTINUATION # : PREVIOUS REEL : COf~IENT : ARCO ALASKA INC, KUPARUK, 30-19, API #50-029-22753-00 Sperry-Sun Drilling Services LIS Scan Utility Mon May 05 10:45:35 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT 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: ~L: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING MWD RUN 3 AK-MM-70084 P. SMITH D. LUTRICK MWD RUN 4 AK-MM-70084 P. SMITH G. WHITLOCK 22 13N 9E 910 1949 .00 65.00 23.10 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30-19 500292275300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 05-MAY-97 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9.875 7.625 5350.0 6.750 9415.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 2 ARE DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUNS 3 AND 4 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR/SGRC) UTILIZING GEIGER MUELLER TUBES DETECTOR AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9415'MD, 6822'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 (RESISTIVITY SENSOR). $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 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 FET RPD RPM RPS RPX GR ROP $ START DEPTH 5339 0 5339 0 5339 0 5339 0 5339 0 5339 0 5339 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 5339.0 5345.0 6531.5 6537.5 6533.0 6540.5 6537.5 6545.0 STOP DEPTH 9361 5 9361 5 9361 5 9361 5 9361 5 9354 5 9416 0 EQUIVALENT UNSHIFTED DEPTH 674 675 710 710 715 720 721 745 771 777 7781 7907 8039 8045 8097 8137 8170 8265 8321 8364 8366 8369 8386 8389 8391 8393 8398 8408 8410 8415 8417 8425 8427 8428 8430 8472 8474 8495 8496 8574 8657 8679 8680 8691 8705 8711 8749 8750 8782 8783 8806 8828 8830 8848 8856 8857 8862 8920 8921 8980 9045 9060 9073 9074 9 0 0 0 1 5 3 0 6 0 9 0 0 0 1 5 1 0 7 0 5 5 5 0 0 0 0 .5 5 5 5 5 0 5 5 5 5 5 .5 .5 .5 0 0 5 0 5 0 0 5 0 5 0 5 5 5 0 0 0 0 5 0 0 0 0 0 5 0 0 0 0 5 5 0 5 6754.5 6755.5 7105.0 7107.5 7160.5 7213.5 7214.5 7455.0 7714.0 7782.5 7787.0 7910 5 8041 5 8046 0 8098 5 8138 0 8172 0 8269 0 8323 5 8366 0 8367 5 8370 5 8387 5 8390 5 8393 0 8394 5 8399 5 8409 0 8411 0 8416 5 8418 0 8426 0 8427 5 8429 5 8430 5 8473 5 8475 0 8495 5 8497 0 8574 5 8659 5 8680 5 8681 5 8693 5 8706 5 8712 0 8750 5 8751 5 8783 0 8784 5 8807 0 8829 5 8831 0 8849 0 8857 0 8858 5 8862 5 8920 5 8921 5 8979 5 9045 0 9060 0 9073 0 9074 5 9086 9095 9103 9104 9117 9118 9139 9144 9199 9201 9416 5 · 0 0 5 5 5 5 0 .5 .5 .0 MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: 9086 5 9095 5 9103 5 9104 5 9117 5 9118 5 9139 5 9143 5 9199 0 9201.0 9415.5 BIT RUN NO MERGE TOP MERGE BASE 3 5360.0 8032.0 4 8032.0 9415.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHM~ 4 1 68 RPD MWD OHM~ 4 1 68 FET MWD OHN~ 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 Mean DEPT 5339 9416 7377.5 ROP 7.8512 615.413 175.202 GR 35.0647 516.761 107.981 RPX 0.4355 2000 3.60297 RPS 0.5403 2000 4.09521 RPM 0.1388 2000 4.73456 RPD 0.7255 2000 6.08896 FET 0.1155 50.4591 1.0793 Nsam 8155 8155 8032 8046 8046 8046 8046 8046 First Reading 5339 5339 5339 5339 5339 5339 5339 5339 Last Reading 9416 9416 9354.5 9361.5 9361.5 9361.5 9361.5 9361.5 First Reading For Entire File .......... 5339 Last Reading For Entire File ........... 9416 File Trailer Service name ............. STSLIB.001 Service'Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 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 ....... 97/05/05 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: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 5345.0 5345 0 5345 0 5345 0 5345 0 5345 0 5345 0 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: 7977 7977 8032 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 STOP DEPTH 7970 5 7977 5 7977 5 7977 5 5 5 0 04-APR-97 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DEPII 2.17f MEMORY 8032.0 5360.0 8032.0 47.0 49.2 TOOL NUMBER P0694SP4 P0694SP4 6.750 6.8 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S) : MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.20 37.0 9.5 6OO 8.4 4.700 3.010 5.200 4.700 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 RPX MWD 3 OHMM 4 1 68 8 3 RPS MWD 3 OHMM 4 1 68 12 4 RPM MWD 3 OHMM 4 1 68 16 5 RPD MWD 3 OHM~ 4 1 68 20 6 FET MWD 3 OHMM 4 1 68 24 7 ROP MWD 3 FT/H 4 1 68 28 8 44.5 First Name Min Max Mean Nsam Reading DEPT 5345 8032 6688.5 5375 5345 GR 35.0647 153.195 102.318 5252 5345 RPX 0.4355 2000 3.69974 5266 5345 RPS 0.5403 2000 4.46608 5266 5345 RPM 0.1388 2000 5.51511 5266 5345 RPD 0.7255 2000 7.53426 5266 5345 FET 0.1155 50.4591 0.843246 5266 5345 ROP 9.2578 615.413 217.043 5375 5345 Last Reading 8032 7970 5 7977 5 7977 5 7977 5 7977 5 7977 5 8032 First Reading For Entire File .......... 5345 Last Reading For Entire File ........... 8032 File Trailer Service ~na,me.~ ........... oiSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 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 ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR RPX RPS RPM RPD FET ROP $ 7971.5 7978 5 7978 5 7978 5 7978 5 7978 5 8034 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: 9361 9361 9415 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAm94ARAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): STOP DEPTH 9354 0 9361 0 9361 0 9361 0 0 0 5 05-APR-97 ISC 4.88/4.96 CIM 5.46/SP4 5.03/DEPII 2.17f MEMORY 9415.0 8032.0 9415.0 38.0 48.4 TOOL NUMBER P0694SP4 P0694SP4 6.750 6.8 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.20 37.0 9.5 6OO 8.4 3.400 1.720 3.600 3.100 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 AAP I 4 1 68 4 2 RPX MWD 4 OHN~ 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 OHMM 4 1 68 28 8 56.1 Name DEPT GR RPX RPS RPM RPD ROP FET Min 7971.5 36 3263 1 2649 1 2088 1 1259 1 2563 7 8512 0.39 Max Mean Nsam 9415.5 8693.5 2889 516.761 118.773 2766 34.0872 3.40565 2766 30.735 3.37925 2766 25.1217 3.24526 2766 24.2598 3.34228 2766 305.273 94.0519 2764 13.1617 1.52809 2766 First Reading 7971 5 7971 5 7978 5 7978 5 7978 5 7978 5 8034 7978.5 Last Reading 9415.5 9354 9361 9361 9361 9361 9415.5 9361 First Reading For Entire File .......... 7971.5 Last Reading For Entire File ........... 9415.5 File Trailer ~ t. Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/05 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Reel Trailer Service name ............. LISTPE Date ..................... 97/05/05 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File