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Home My WebLink About186-165MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 18, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Josh Hunt P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3K-12 KUPARUK RIV UNIT 3K-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/18/2025 3K-12 50-029-21655-00-00 186-165-0 W SPT 6540 1861650 1635 2850 2850 2850 2850 140 150 150 150 4YRTST P Josh Hunt 5/9/2025 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3K-12 Inspection Date: Tubing OA Packer Depth 520 2020 1970 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitJDH250510092317 BBL Pumped:1.2 BBL Returned:1 Friday, July 18, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 99 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.07.18 13:55:58 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r1�7 5'L DATE: Tuesday, May 11, 2021 P.I. Supervisor '\ �I�Lf SUBJECT: Mechanical Integrity Tests ConocaPhiuips Alaska, Inc. 3K-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 3K-12 Petroleum Inspector Type Inj Src: Inspector TVD 650 -Tubing Reviewed By: 2900 - P.I. Sup" J92— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-12 API Well Number 50-029-21655.00-00 Inspector Name: Lou Laubenstein Permit Number: 186-165-0 Inspection Date: 5/4/2021 - Insp Num: macol.zlosososlTol Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-12 Type Inj w ° TVD 650 -Tubing 2900 - z9oo - z9oo- 290o - PTD 1861650 Type Test SPT jTest psi 1635 - IA 550 2000 - 1950 _ 1950 - BBL Pumped: 1.4 'BBL Returned: 1.4 OA 300 - 300 300. =30D - Interval 4YRTST , P/F P Notes: Tuesday, May 11, 2021 PaLe I of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 3 ( -7 DATE: Friday,May 19,2017 P.I.Supervisor I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 3K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry U I NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-12 API Well Number 50-029-21655-00-00 Inspector Name: Lou Laubenstein Permit Number: 186-165-0 Inspection Date: 5/16/2017 Insp Num: mitLOL170516170325 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-12 Type InjTVD 6540 Tubing 2800 2800 2800 " 2800 PTD 1861650 - !Type TestTest psi 1635 IA 660 2010 1955 - 1955 ' BBL Pumped: 1.3 ' BBL Returned: 0.9 OA 140 160 - 160 160 " Interval 4YRTST PAF P Notes: r s ® 1 ) 1':'1 Friday,May 19,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg 7 DATE: Wednesday,May 15,2013 P.I.Supervisor 1\61' 7 117(l3 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-12 FROM: Bob Noble KUPARUK RIV UNIT 3K-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry ;e= NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-I2 API Well Number 50-029-21655-00-00 Inspector Name: Bob Noble Permit Number: 186-165-0 Inspection Date: 5/12/2013 Insp Num: mitRCN130513071243 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-12 • 'Type Inj W :TVD 6540 • i IA 610 I 2010 1960 .'l 1950 ■ PTD 1861650 ' Type Test,SPT Test psi 1635 ' � OA 50 60 - ' 60 60 - I' 2 Interval i4YRTST J1P� F P � ,Tubing� 2930 0 2930 1 2930 2930 - Notes: SCANNED FEB 2 0 2014 Wednesday,May 15,2013 Page 1 of 1 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log: 3K-12 Run Date: 7/31/2010 August 4, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-12 Data in LAS format, Digital Log Image files 50-029-21655-00 Cement Bond Log 50-029-21655-00 .:._ 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.woo AUG 1 ~ 2010 Date: Signed: • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record /Perforating Record: 3K-12 Run Date: 7/20/2010 July 30, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21655-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 ~b to' C `~ q~~° v~ ~ °~ Signed: • SEAN PARNELL, GOVERNOR James Ohlinger Wells Engineer ConocoPhillips Alaska, Inc. ~~~,~~~ ykN ~~ .~ ~~J;; J„~ P.O. Box 100360 Q ~~ ~ ~// Anchorage, AK 99510 ~ U Re: Kuparuk River Field, Kuparuk Oil Pool, 3K-12 Sundry Number: 310-202 Dear Mr. Ohlinger: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, /_ ~j Daniel T. Seamount, Jr. /~ Chair DATED this ~ day of July, 2010. Encl. STATE OF ALASKA ALASI,IL AND GAS CONSERVATION COMMISSI~ APPLICATION FOR SUNDRY APPROVALS 1,~~-~ 20 AAC 25.280 1. Type of Request: Abandon "" Plug for Redrill F~rforate New Pool ~ Repair w ell "` Change Approved Program ""` Suspend ~""'` Plug Perforations ~t'I° F~rforate Pull Tubing ~ sion Time Exte n C~perationalShutdown ~` Re-enterSusp. Well "", Stimulate ~" Altercasing ~ Q / Other:/-"R~ ~v"~4nr~" 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ploratory ~ 186-165 3. Address: % Stratigraphic "%~ Service 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 ~,D ~% ~- f 50-029-21655-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes N o 3K-12 9. Property Designation: 10. Field/Pool(s): ~ ADL 25629 ~ Kuparuk River Field /Kuparuk Oil River Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Deptn MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7770 ~ 6977 ~ 766T 6892' Casing Length. Size MD ND Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 3941 9.625 3978' 3887' PRODUCTION 7720 7 7754' 6965' Perforation Depth MD (7472'-7469', Perforation Depth ND (ft): 6732'-6746', Tubing Size: Tubing Grade: Tubing MD (ft): 7506'-7536', 7542'-7543', 7549'-7550', 7556'-7561' 6760'-6785', 6790'-6791', 6796'-6796', 6801'-6805' 3.5 L-80 7444 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - 4782- 7" 26#, "FHL" RETRIEVABLE PACKER MD= 7240 ND= 6541 PACKER -BAKER "F-1", 7" PRODUCTION PACKER MD= 7430 ND= 6697 SAFETY VLV - SLB TRMAXX-CMT SCSSV 'X' Profile MD= 1841 ND= 1841 12. Attachments: Description Sumrery of PI-oposal ~ 13. Well Class after proposed work: Detailed Operations Program ~"" BOP Sketch J` Exploratory " Development ~ ~ (Ser~ce -~' ~ ,3v` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/9/2010 Oil 1-/ Gas WDSPL r Suspended ' 16. Verbal Approval: Date: WINJ ~ ~'' ~0 GINJ ~ WAG ~`~ Abandoned Commission Representative: GSTOR SPLUG ~"~' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Printed Name James Ohllrlger Title: Wells Engineer ///~ t %?~~/d D t Signature v Phone: 265-1102 o e a C mmi i n nl Sundry Number: ~`O ~~ Conditions of approval: Notify Commission so that a representative may witness Plug Integrity "' BOP Test ~ Mechanical Integrity Test ~""` Location Clearance R C 11~~ `,C 111 .L~.~`"~'~ 41 L..°" Other: JAN a~ (~ L71(~ Subsequent Form Required: /O ..- ~,/ b `{ r Alaska Qel €~ ~i~& ~Ali~, Corrltr+~r^'': APPROVED BY p ~ ~ Approved by: COMMISSIO R THE COMMISSI Date: ,~,lo Form 10-403 Revised 1/2010 7 j-)6 Submit in Duplicate ~ ORIGINAL .-~~~~~ • ConocoPh i l l i s p P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 29, 2010 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: U ConocoPhillips Alaska, Inc. hereby submits a sundry to punch holes in the 3-1/2" tubing in the 3K-12 well. The perforations are being done as part of the pre-rig preparation for upcoming coiled tubing drilling (CTD) operations. The work is scheduled to begin in July 2010. The CTD objective will be to drill two A-sand lateral sidetracks. Permit to Drill applications for those laterals have been submitted separately. Attached to this Sundry application is an outline of job operations (including those of the CTD project). If you have any questions or require additional information please contact me at my office 907-265-1102. Sincerely, James Ohlinger Coiled Tubing Drilling Engineer ~(/~ ~ ~e~ t r ~ ~ NcT t ~£A ~ 1 7- /-/a • Permit to Drill Summary of Operations Cont. 3K-12L1/L1-01 KRU 3K-12L1, 3K-12L1-01 = 2.613") 16" 62# H-40 shoe @ 110' MD 9-5l6" 3F# J-SS shoe @ 3978' MD Proposed CTD Sidetrack Perts for Cement 7700 - 7310' Perts for Cement 7400' - 410' A-sand perfs 7472' - 7561' 9.3# L-80 EUE Srd Tubing to surtace Camco MMG GLM w/SOV @ 7166.40' MD Seal Assembly Locator (spaced out 3') Baker80-40 3-1R" EUE PBR ~ 7226.31 MD (XX" ID) Baker 476-7 26# FHL packer @ 7239.69 MD (XX" ID) XN Nipple ~ 7263.34' MD 80-40 3.5" EUE Bonded Seal Assembly wl Locator (spaced out 1') sr F-1 packer (dj 7430' MD (XX" ID) er 80-40 SBE @ 7433.31' MD w/ 2.813" Profile 3.5" EUE HES "X" profile nipple (~ 7440.33' MD EUE Box up Shear Out w/LEG Guide @ 7443.93' MD Top of Billet - 8700' 3K-12L1-01 WP01: TD - 10,450' 7" 26# J-55 shoe @ 7754' MD Page 6 of 6 6/29/2010 ~J • KRU 3K-12: Sundry -Summary of Operations Well History: Well 3K-12 is an A-sand injector, straddle completion well equipped-with 3-1/2" tubing (from surface to 7445' MD and a 7" production liner (from surface to 7754' MD). The well was recently worked-over to replace the 2-7/8" tubing with 3-1/2". Prior to the arrival of the CTD rig, the 3-1/2" tubing will be punched with pert guns to allow cement into the annulus of the 3-1/2" and 7". The existing A-sand perforations in the 3K-12 completion will be blocked with a composite bridge plug during the cementing. Then the cement and CBP will be milled out to allow the existing perforations to inject into the region of the mother-bore. The casing exit on this well will be via whipstocks set in the 3-1/2" tubing for a dual string exit. fo•+Cvf. Operational Outline ~,`Th 2 ~" S~h~ /~~*P~`~l '~~~~i~~cC~r~ '~~~~/~ - ,~~~~ ~ S~P~~ ~r~ ,reC'U~~. ~ r y.3 ~'~ r ~uh vim' Pre-CTD Work ~ '_/1 ~~ ~~~~, ~ ~ ~ ~ 1. Slickline: Dummy perf gun drift, tag fill ~' ~ 7/~Q 2. Coil: FCO to bottom of perfs ~ 7,561' RKB 3. E-line: Run GR/CCL jewelry log /tie-in log (6900' to 7500' RKB; K1 Marker at 6990'). Shoot holes in the 31/2" tubing 7300' - 7310' RKB, and 7400' - 7410'. 4. E-line: Set HES "FasDrill" composite bridge plug (CBP) @ 7423' RKB; CCL tie-in 5. Coil: Lay in cement plug from CBP up to the perf holes @ 7300' RKB. 6. Slickline: Tag TOC and PT to 1500 psi. 7. Coil: Drill out cement and Composite Bridge plug w/ special clearance bi-center bit. 8. Slickline: Run dummy whipstock g ja -202 9. E-line: Run slimhole CBL to evaluate cement behind the 3 %2" x 7" lo. O: Set BPV, prepare Wellsite for rig arrival r Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU BOPE and test 2. Set top of whipstock at 7,400' MD 3. Mi112.80" window at 7,400'; dual string exit 3-1/2" x 7" 4. 3K-12L1 Sidetrack a. Drill a 2.70" x 3" bi-center lateral to a TD of 10,450' MD b. Run the 23/8" slotted liner from TD to 8,700' MD. An aluminum liner top billet will be placed at 8,700' MD. s. 3K-12L1-O1 Sidetrack a. Kick off of the aluminum liner top billet at 8,700' MD b. Drill a 2.70" x 3" bi-center lateral to a TD of 10,450' MD c. Run the 23/8" slotted liner from TD to 7,390' MD, inside the 7" casing Post-Rig Work 1. Obtain SBHP 2. Flowback to tanks for well cleanup 3. Begin production 6/29/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, July 01, 2010 1:58 PM To: Schwartz, Guy L (DOA) Subject: RE: 3K-12 Pre-CTD "(PTD 186-165) James, Just realized you are not actually P & A 3K-12. You are using a flow thru whipstock so injection will continue into the motherbore. We will need to get the original well back to Injection status at some point. I will see what that will take sundry wise and get back to you. No hurry as of now. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 {office) 444-3433 (cell) From: Schwartz, Guy L (DOA) Sent: Thursday, July 01, 2010 1:24 PM To: 'Ohlinger, James J' Subject: RE: 3K-12 Pre-CTD *(PTD 186-165) Area of review... we need it for injectors. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ohlinger, James J [mailto:James.J.Ohlinger@conocophillips.com] Sent: Thursday, July 01, 2010 1:21 PM To: Schwartz, Guy L (DOA) Subject: RE: 3K-12 Pre-CTD *(PTD 186-165) Sorry, AOR? Schematic attached. The PTD should be coming shortly. From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, July 01, 2010 1:18 PM To: Ohlinger, James J Subject: 3K-12 Pre-CTD *(PTD 186-165) James, Do you have a schematic for the upcoming work on 3K-12??? Cartoon type is the best showing the new laterals too would be great. We need one included with all 403's and PTD's. (especially P & A wells ) On a side note .. an AOR should be completed for the new injector laterals for 3K-12 since they will extend away from the original wellbore. Current well class is an Development well since it is backflowing .. so you will see the correction when the 403 is sent back. The new S/T well laterals PTD can be submitted as Injectors of course. 7/1/2010 Page 2 of 2 Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) 7/1/2010 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 3K-12 Run Date: 5/28/2010 June 11, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21655-00 :.~ U PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-27; ~ ~f ~ rafael.barret ~.~' Date: e~ _. U ~ c, /$~' ~l05 f4/~5~.3 Signed STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS~1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Repair w ell ~ Rug Perforations ~'° Stimulate ~" Other [['"°'' Alter Casing `°` Pull Tubing F~rforate New Pbol °"` Waiver ~ Time Extension ~" Change Approved Program "' Operat. Shutdown "" Perforate ~""'" Re-enter Suspended Well '°` 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory 186-165 3. Address: Stratigraphic ~ Service .API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21655-00 7. Property Designation; 8. Well Name and Nurnf~er: ADL 25629 3K-12 9. Field/Pool(s): `~ Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 7770 feet Plugs (measured) None true vertical 6977 feet Junk (measured) None Effective Depth measured 7667 feet Packer (measured) 7240, 7430 true vertical 6892 feet (true verucal) 6541, 6697 Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 110 110' SURFACE 3941 9.625 3978 3887 PRODUCTION 7720 7 7754 6965 ~. ~~~~~~~~.., II i, , ~ €~ ~ _ RE~~IVED J U N ~ ~ 2 010 Pertoration depth: Measured depth: 7472'-7489', 7506'-7536', 7542'-7543', 7549'-7550', 7556'-7561' True Vertical Depth: 6732'-6746', 6760'-6785', 6790'-6791', 6796'-6796', 6801'-6805' A~8Sk8 01~ ~ ~~ Cens• Commission d~nichor~,ga Tubing (size, grade, MD, and TVD) 3.5, L-80, 7444 MD, 6709 TVD Packers & SSSV (type, MD, and TVD) PACKER - 4762- 7" 26#, "FHL" RETRIEVABLE PACKER @ 7240 MD and 6541 TVD PACKER -BAKER "F-1", @ 7430 MD and 6697 TVD SAFETY VLV - SLB TRMAXX-CMT (2.813" ID) SCSSV'X' Profile @ 1841 MD and 1841 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 10 389 341 -- 170 Subsequent to operation si 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory "" Development Service Well Status after work: Oil Gas " WDSPL "' Daily Report of Well Operations XXXX GSTOR WAG GASINJ WINJ " SPLUG "`, 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.o. Exempt: none Contact Er elso -4 3 Printed Name rik N o Title Drilling Engineer Signature ° hone: 263-4693 Date ~/y ~ " ~ ~ ~ ~ ~~~~ 0 , -' CEO '-°,~i e~ V ~-~" ~ Form 10-404 Revised 7/2009 RBDMS JBN 2 8 ypp~~ Submit Original Only CorttxoPhilleps HANGER.42 38-110 SAFEN VLV, - - t,841 GAS LIFT, ],1ss LOCATOR, - ],223 PBR, ],226 -~ AcKER, ],za6 - NIPPLE. ],263 -- SEAL ASSY, _ _ ],a2a PACKER. T,430-- --- SBE, ],633 - --' NIPPLE,],MO SOS, 7,444-- -- IPERF, ],482-T,683 IPERF,_ ,..__ 7,484-],985 IPERF, 7,486-] 48] ----- IPERF,__ -. T,506-7,507 , IPERF, ],512-],513 IPERF, ],542-].543 IPERF, ],549-],550 IPERF, ],556-],561 . KUP - 3K-12 ,.r_,. ,,.._.~...._,. I~e~., n....lo u nnn ITn Wellbore APUUWI '~. Fieltl Name lncl (°) MD (RKB) Well Status Act Bbn (RKB) 500292165500 KUPARUK RIVER UNIT I I ( PROD 37.78 4,700.00 7,775.0 Comment H25 (ppm) 'Date Annotat on End Date KB-Grd (R) 'i Rig R I se Data SSSV: TRDP -_ l (Last WO I. 5/30/2070 ~ 39.01 _-_ 71/12;7986 - notation Depth kK8 End Date Annotation ) Last Mod ... Entl Date Last Tag: SLM 7 6/9'2010 Rev Reason: WORKOVER, GLV C/O _ Imosbor 6/14!2070 ,508.0 LCasin Strin s Casing Description jString 0... String ID ... Top (kK8) Set Depth (f... Set Depth (ND) ... String Wt... String .. . String Top Thrd '.CONDUCTOR 16 15062 380 110.0 710.0 62.50 H-40 Casing Description String 0... String ID ... Top (RKB) Set Depth (t... Set Depth (ND) ... String V2f... String .. . String Top Thrd SURFACE 9 5/8 8.765 37-1 3,978.0 3 887.4 36.00 J-55 BTC Casing Description String 0... String ID ... Top (RK6) Set Depth (t... Set Depth (ND) ... String Wt... String .. . String Top Thrd PRODUCTION 7 6.151 34.0 7,753.9 6,9644 26.00 J-55 _ BTC _.. Tubing Strings _ escri lion P ... To Str n 9 9 P( ) .. iStr 0 ...'Str ng f... Set D Th 9D).. Str Se1 D 5 P ( P ( 9 'String Top Thrd TUBING z 992 419 31 Z 6 U 93 7 ~ 1 L-80 Srd EUE C~ ompletion Det ails Top Depth ~ r__i«vc, (ND) IRK61 Top Intl I°1 I no... ne«rl..tl..., comment NOmi... ID (in) Seal Assembly Locator (Spaced out 3') 80-40 3 112" EUE "PBR" Polish Bore Receptacle 4762- 7" 26#, "FHL" Retrievable Packer 2.813" X-Nipple 80-40 3-S"EUE Bonded Seal Assembly w/Locator Spaced out 1' Baker "F-1", 7" Production Packer installed w/E-line _- -- 80~Q, 4.75" Stub Acme Seal Bore Extension S.0", Bottom Sub, 4.75" Acme x 3.50" EUE 3S" w/ 2.813" Profle 35"EUE HES "X" Profle Nipple -- 3.5" EUE Box up Shear Out w! Leg Guide Perfora tions 8 ~,. Slots _ --- _ _ -- snm Top (TVD) Btm (FVD) Dens Top (RKB) Btm (RKB) (kK6) (ftK8) Zona Date lsn.., Type Comment 7,472 7,489 I 6,732.0 6,746.0 A-3, 3K-12 8/27/1992 4 0 RPERF 2 1/8"SilverJet, 0 tleg. ph - --.. _. 7,479 ___ 7,480 6,737.5 -_ 6,738.6 _.____.. A-3, 3K-12 1714/1987 1.0 -. ___.._- -_.. - IPERF 2 1/8" EnerJet 7,482 7,483 6,740 2 6,741.7 A-3, 3K-12 1/14!1987 1.0 IPERF SINGLE SHOT; 2 1/8" EnerJet 7,484 7,485 6,741 9 6,742.7 A-3, 3K-12 1/14/1987 1.0 ~ IPERF 2 1/8" EnerJet 7,486 7,487 6,743.5 6,744.4 A-3, 3K-12 111417987 i 1.O IPERF 2 1/8" EnerJet 7,506 7,507 6,760 2 6,761.0 A-3, 3K-12 7/14!1987 1 0 IPERF 2 7/8" EnerJet 7,506 7,536 6,760.2 6,784.8 A-2, 3K-12 1 8/27/1992 4.0 RPERF 2 1/8"SilverJet, 0 tleg. ph 7,512 7,513 6,765.1 6,765.9 A-2, 3K-12 1/14/1987 1.0 IPERF 2 V8" EnerJet 7,520 -7,521 6,771.7 6,772.5 A-2, 3K 12 - 7!74/1987 7.0 IPERF j 2 1l8" EnerJet 7,528 7,529 6,778.2 6,779.0 A-2, 3K-12 1114/1987 I 1.0 IPERF 2 1/8" EnerJet 7,535 7,536 6,784.0 6,7848 A-2, 3K-12 1/14/1987 1.0 IPERF 21/8"EnerJet 7,542 7,543 6,789.7 6,79QS LA-2, 3K-12 7/14/1987 1.0 IPERF 2 1/8" EnerJet ' 7,549 ! 7,550 6,795.5 6 796.3 A-2, 3K-12 ' 1/14/1987 1.0 IPERF 2 1!8" EnerJet ' 2556 7,561 6,801.2 6,805.3 A-2, 3K 12 11/14/1987 1 0 IPERF 2 118" EnerJet _---- Notes= General 8 Safety _ _ End Date Annotation _ - --- 8/23/7991 iNOTE: WORKOVER ' ~ NOTE~VIEW SCHEMATIC w/Alaska Schematic9.0 __ 6/5/2010 Port --- OD ~ Valve Lath Size TRO Run Model lIN _ Serv YPe YP (in) (psi) MMG 7 12 GAS LIFT DMY ~RK ~0 000 0.0 PRODUCTION, 34-] ]54 TD. ].]]5 3K-12 Pre and Post Workover Events WELLN. SUMMARY 3K-12 (PRE RWO) T-POT -PASSED. T- OT -PASSED. IC-POT -PASSED. IC- OT - Passed. FUNCTION TEST LDS's. MITOA -PASSED. 3K-12 TAGGED @ 7508' SLM, EST. 7527' RKB. MEASURED BHP @ 7517' RKB: 3377 PSI. COMPLETE. 3K-12 RUN STATIC GAUGES 1ST STOP 7517' RKB (30 MIN- 3446 PSI, 120.5 DEGF), 2ND GRADIENT STOP @ 7395' RKB (15 MIN- 3402 PSI, 127.6 DEGF). PULL 1.5" DMY @ 7294' RKB, LEAVE OPEN .COMPLETE 3K-12 ATTEMPT TO CUT 2.875" TUBING ON 3K-12. NORDIC #3 RIG CANNOT PULL THE TUBING. COULD NOT FINISH RCT CUT DUE TO MALFUNCTIONING SSSV. HAD TO ~--._.. POOH AND RD. SLICKLINE HAD TO LOCK OUT SSSV. 3K-12 ''**RIG JOB***LOCKED OPEN 2-7/8" TRDP-1A-SSA. PASSED THROUGH WITH Z-5 AND RAN FLAPPER CHECKER WITHOUT PROBLEM. 3K-12 MAKE SECOND ATTEMPT TO CUT 2.875" TUBING ON NORDIC #3 RIG 3K12. WERE UNABLE TO MAKE CUT YESTERDAY DUE TO SSSV NOT BEING LOCKED OPEN AND TOOLS UNABLE TO COME UP THROUGH SSSV. 3K-12 PERFORM A JUNK BASKET GAUGE RING (5.95") RUN TO WIRELINE TD WHICH WAS 7472'. FOLLOWED BY RIH WITH A BAKER #20 SETTING TOOL AND BAKER PERMANENT PACKER WITH SEALBORE (3.0" ID) AND SET @ 7430'. TOOL STROKED AND SET IN ONE MINUTE. BAKER HAND INDICATED A POSITIVE SET AFTER LOOKING AT HIS SETTING SLEEVE ON SURFACE. 3K-12 REPLACE SOV W/ DMY VLV @ 7166' RKB. IN PROGRESS. 3K-12 PRESSURE UP TBG TO SHEAR SOS, TAG @ 7508' SLM. SAMPLE OBTAINED. PERFORMED 30 MIN SBHPS @ 7517' RKB = 3618 PSI, 120 DEG F. 15 MIN GRADIENT STOP MADE @ 7395' = 3568 PSI. COMPLETE. 3K-12 T-POT (PASSED ), T-PPPOT (PASSED ) ion©coPhillips Time Log & Summary YYelNiew Web RepoRrng Report Well Name: 3K-12 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/20/2010 2:00:00 PM Rig Release: 5/30/2010 8:00:00 AM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 5/19/2010 2a hr Summary Rig Was Release to start Moving @ 1500 hrs. At Midnight the Rig was 1 mile passed CPF 2, Traveling toward 1Y- Intersections. 15:00 18:00 3.00 MIRU MOVE MOB P Move Nordic Rig 3 from 2T-17 to 2A-Pad 18:00 00:00 6.00 MIRU MOVE MOB P Rig is 1 mile Passed CPF 2, Headed to 1Y Intersection. 5/20/2010 Continue Moving Rig to 3K-Pad. MIRU on 3K-12. Spot Auxiliary equipment. Kill well. 22 bbls lost to formation. 00:00 03:00 3.00 MIRU MOVE DMOB• P Rig at 1Y-pad Intersection. 03:00 05:00 2.00 MIRU MOVE DMOB P Rig @ 1Q-Pad Pull off for Field Wide Crew Chan e. 05:00 07:00 2.00 MIRU MOVE OTHR P Standby With Crew For Field Wide Chan a Out. 07:00 14:00 7.00 MIRU MOVE DMOB P Moving Rig from 1Q-Pad to 3K-12. 14:00 16:00 2.00 MIRU MOVE PSIT P Spot over well and berm up, spot auxiliary equipment. Accepted Nordic Rig 3 @ 14:00 hrs on 5-20-10 16:00 16:30 0.50 COMPZ WELCTL SFTY P Held PJSM w/ Cameron and rig crew on Lubricatin out BPV. 16:30 17:30 1.00 COMPZ WELCTL MPSP P PU lubricator and lub out BPV, Lay down lubricator. U dated AOGCC 17:00 hrs. 17:30 20:30 3.00 COMPZ WELCTL OTHR P Set cuttings box and berm up. Install kill lines to 500 bbl Rain for Rent tank. 20:30 21:30 1.00 COMPZ WELCTL PRTS P Clear kill line with air, fluid pack line and PT @ 250/4,000 psi. Return call from AOGCC @ 21:30 hrs. 21:30 23:30 2.00 COMPZ WELCTL CIRC P Oren up well, 650 psi SITP, 980 psi SICP. Start reverse circ. w/ 10.2 ppg Naar/NaCI brine. ICP = 1,100 psi @ 3 bpm w/ FCP 530 psi. w/ 10.2 ppg returns at surface. Total pumped = 327 bbls. and Total recovered = 305. Shut down pumping ops. Lost to formation = 22 bbls 23:30 00:00 0.50 COMPZ WELCTL OWFF P Monitor well for flow - no flow. Page 1 of 9 r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 5/21/2010 24 hrSummarv Set BPV. ND Tree & Inspect Threads, replace 3 lock down screws.NU 11" Hydril stack. Started BOP test with on site AOGCC, tested BOPS @ 250/4,000 and Annular @ 250/3,500 psi. Had Problem with Hydraulic Choke. Sent to BOT machine sho for re airs. 00:00 00:30 0.50 COMPZ WELCTL MPSP P Set BPV 00:30 02:00 1.50 COMPZ WELCTL NUND P ND 3 1/8 5M CIW tree. Inspect lift threads -good, install test plug. Replace 3 lock down screws. Blank off SSSV control line. 02:00 05:00 3.00 COMPZ WELCTL NUND P NU 11" Hydril 5M stack. Gave AOGCC 2 hr notice for testing BOPE 0400 hrs. 05:00 14:00 9.00 COMPZ WELCTL BOPE P Fill stack, Function test and RU test equipment. Test BOPE Cad 250 / 4 000 si and Annular @ 250 ! 3,500 si. 14:00 15:00 1.00 COMPZ RIGMNT BOPE T Break out hydrualic choke and re lace stim and seat. 15:00 18:00 3.00 COMPZ RIGMNT BOPE T Unable to Make Choke Repairs on Locations. Ship Choke to BOT Machine Sho . 18:00 00:00 6.00 COMPZ RPEQPI OTHR P Load, Rack and Tally 3 1/2 Completion string in Pipe shed Unable to Make Choke Repairs on Locations. Ship Choke to BOT Machine Sho . 5/22/2010 Install Spare CHoke & Tested 250 / 4000psi. Mu &Unland Hanger, pulled 11' 40k / 115k work up & down, no movement.RU E-line, Unable to work tools up & down thru SSSV, rig down eline. Call out SL to lock out SSSV. 00:00 02:00 2.00 COMPZ RPEOPI OTHR P Load, Rack and Tally 3 1/2 Completion string in Pipe shed. Choke Valve Still @ BOT Machine Sho for re airs. 02:00 03:00 1.00 COMPZ RPEOPI OTHR P Load Control line spooler and 3 1/2" landing pups. Spare Choke Valve being shipped from Deadhorse to 3K- ad. 03:00 06:30 3.50 COMPZ WELCTL BOPE T Spare Choke Valve on Location. PU to Ri Floor and Install Valve. 06:30 07:00 0.50 COMPZ WELCTL BOPE T PT choke manifold ~ 250 / 4,000 psi ' - ood. 07:00 08:30 1.50 COMPZ WELCTL MPSP P Prepare and pull Test Plug and BPV. 08:30 09:00 0.50 7,347 7,347 COMPZ RPCOM OTHR P MU landing pups into hanger @ 26' from rig floor and BOLDS. Unland han er 40k and pull hanger 11' f/ 40k to 115k. Call out E line unit that was on stand b for ri 09:00 hrs. 09:00 10:30 1.50 7,347 7,347 COMPZ RPCOM CIRC P CBU (4,756 strokes) @ 3 bpm @ 410 psi. Lost 20 bbls during circulation. Page 2 of 9 ra • ''Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 10:30 11:00 0.50 7,347 7,347 COMPZ RPCOM OWFF P Monitor well for flow - No flow and no fluid level dro . 11:00 11:30 0.50 7,347 7,347 COMPZ RPCOM OTHR P Work stuck pipe f/ 50k to 115k (calculated string wt 85k = 50k + 35k block) ,work in 18 right hand turns w/ 2k max torque attempting to release RH release packer. No movement. Had 31" of strectch for 20k over ull f/ 80k to 100k. 11:30 15:00 3.50 7,347 7,347 COMPZ RPCOM ELNE P RU for E-line (Called for unit on standby forjob @ 09:00 hrs and Unit arrived @ 13:30 hrs.) Spot E line unit. 15:00 15:30 0.50 7,347 7,347 COMPZ RPCOM SFTY P Held PJSM w/ HES E line crew and ri crew on RU and SSSV in well. 15:30 17:30 2.00 7,347 COMPZ RPCOM ELNE P RU E line sheaves and lubricator w/ ack off. 17:30 18:00 0.50 COMPZ RPCOM ELNE P MU 1.688" OD tool string w/ radial cutter and Electromagnetic anchor s stem. 18:00 20:00 2.00 COMPZ RPCOM ELNE T RIH with E-Line down passed SSSV @ 1766' to 1790'. PUH to Drift back up passed SSSV and tool string hung up @ flapper valve on SSSV. Able to pump down tubing @ 4 bpm with rig pump and freed up tools. Call Town engineer and discussed next options. Decision was made to POOH with E-Line tools and have Slickline to Run tools to lock out SSSV. 20:00 22:00 2.00 COMPZ RPCOM SLKL T SLickline Onlocation.PJSM. Move & Re-Spot Rig Equipment. Spot Slickline E ui ment. 5/23/2010 Had Slick-line to Lock out SSSV. MU & RIH w/HES Radial Cutter, made tie-in with ccl and fire shot @ 7323'.Work pipe 115k to 50k no movement.RlH w/ ccl to verift cut, seen small kick @ cut depth. MU & Rlh w/ccl & Radial cutter, tie-in with ccl and made another cut 7328'. Confirm ood cut. RDMO E-Line. 00:00 02:00 2.00 COMPZ RPCOM SLKL T PU SLickline equipment to Rig Floor. MU Slickline tools, Lubricator, x-over, etc. 02:00 02:30 0.50 COMPZ RPCOM SLKL T RIH with Slickline for Drift Run 02:30 03:00 0.50 COMPZ RPCOM SLKL T MU Lockout tools to Lock out SSS 03:00 04:00 1.00 COMPZ RPCOM SLKL T RIH & Locked Out SSSV.POOH 04:00 05:00 1.00 COMPZ RPCOM SLKL T MU & Rlh with Slickline drift w/2.34" NO Go & 2.27" drift to confirmed SSSV is locked out. 05:00 06:00 1.00 COMPZ RPCOM SLKL T Rig down SLickline unit & E ui ment. 06:00 07:30 1.50 COMPZ RPCOM CIRC T RU and Reverse Circulation @ 3 bpm 330 si for 43 bbls. 07:30 08:00 0.50 COMPZ RPCOM ELNE T Spot E line unit 08:00 08:30 0.50 COMPZ RPCOM SFTY T Held PJSM w/HES Eline crew and ri crew. Page 3 of 9 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T Comment 08:30 09:45 1.25 COMPZ RPCOM ELNE T PU and MU lubricator and Radial cutter assy. PT lubricator to 1,000 si. - ood. 09:45 10:00 0.25 COMPZ RPCOM ELNE T RIH w/ cutter assy to 1,800' and pull back thru SSSV 1,766' - ood. 10:00 12:00 2.00 COMPZ RPCOM ELNE P RIH t/ 7,382' w/ cutter. Strip log up and verify depths. RIH past cut depth of 7,325', POOH to 7,307' w/ CCL and fire shot @ 7,324'. POOH, La down Eline a ui ment. 12:00 13:30 1.50 COMPZ RPCOM OTHR P Work pipe from 115k to 50k multiple times - no cut. 13:30 15:00 1.50 COMPZ RPCOM CIRC P Reverse circulate hole @ 5 bpm @ 880 psi -seen 20-25 bbls of 8.6 ppg produced fluid @ bottoms up. Condition hole to 10.2 ppg brine. Had a 95 bbl loss in 12 hr period and regained 9 bbls back in 1 hr of monitorin a ainst tri tank. 15:00 18:00 3.00 COMPZ RPCOM ELNE P RU and RIH w/ ccl to verify cut @ 7,330' seen small kick @ cut depth of 7,323'. POOH. 18:00 19:00 1.00 COMPZ RPCOM ELNE P OOH with E-Line. Rig Down tools. Ri Crew CO. 19:00 21:00 2.00 COMPZ RPCOM ELNE P RIH with 1.688-300 RCT & Correlate ~~? to GLM @ 7294'. CCL Stop depth=7310' !RCT cutter head @ 7328'. Seen good indication that RCT shot. 21:00 21:30 0.50 COMPZ RPCOM ELNE P Rig back E-Line tools. Pull 70k with ri & confirm tubin cut. 21:30 22:30 1.00 COMPZ RPCOM ELNE P Rig down E-Line Tools & Equipment from Ri Floor. 22:30 00:00 1.50 COMPZ RPCOM CIRC P Circulate Well Over to 10.5 ppg / NaCI / Naar 5/24/2010 Pulled tubing hanger to floor, spool control cable down to SSSV, recovering 30 control bands. Cont to POOH S/B 2 7/8" tubing.PU & MU Overshot & fishing assy. Rlh & locate stub @ 7320' DPM w/corrected RKB, Up wt=126k down wt=113k .Latch stub and started jarring @ 50k osw up to 75 osw.Made 10 jar hits & jar free. POOH and recovered 5' tb stub of 2 7/8" Parted at ra le . 00:00 01:00 1.00 COMPZ RPCOM CIRC P Completed rolling hole over to 10.5 brine. Monitor well for flow. 01:00 02:30 1.50 7,327 5,543 COMPZ RPCOM PULL P Pull TBG hanger to floor. Lay down TBG hanger and NEW 3 1/2 8rd pup jts used for landing jt. Continue to POOH, spooling control line for SSSV and lay down SSSV. RD Spooling unit Recovered a total of 30 control line bands. Page 4 of 9 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Gamment 02:30 05:00 2.50 5,543 0 COMPZ RPCOM PULL P Continue to POOH S/B 2 7/8 Tubing. Lay down 18.10' of 2 7/8 J-55 TBG stub -Clean cut -could see attem ted cut 3' +/-inside from run # TBG was stood back to reduce off bottom time for well control purposes. This TBG will be laid down after the Wireline set F-1 acker is in lace. 05:00 06:30 1.50 0 0 COMPZ RPEQPI OTHR P Change over from TBG equip. to DP e ui .Set wear rin . 06:30 08:00 1.50 0 321 COMPZ RPEQPI PULD P PU and MU 5.75" OD overshot w/ 2 7/8 Grapple and MCP (mill control packoff), Overshot extension, Drive sub, LBS, Fishing jar, 9-4.75" OD DC's, Intensifier to 312' - 321' w/ Corrected RKB 08:00 13:30 5.50 321 7,293 COMPZ RPEQPI PULD P PU and RIH w/ BHA #1 f/ 321' to 7,293' with 3 1/2 DP. 13:30 14:00 0.50 7,293 7,293 COMPZ RPEQPI OTHR P Gather Parameters @ 7,293': 126k up wt, 113k do wt, 120k ROT wt @ 10 ms w/ 2k free for ue. 14:00 15:00 1.00 7,293 7,325 COMPZ RPEQPI JAR P RIH and locate TBG stub @ 7,320' DPM w/ corrected RKB. Seen pump pressure increase, shut down pump and attempt to engage fish. No success. PU and rotate down to 7,319' -shut down rotating and slide over to 7,325'. pull 50k osw and bleed off jars. Pull to 100k osw. Cock jars and begin jarring @ 50 osw and work up to 75k osw and work up to 100k osw. Made approximately 2' and was not able to work the 2' back down, 10 jar hits later jar free with no drag or weight ain. 15:00 18:00 3.00 7,325 321 COMPZ RPEQPI TRIP P Lay down 2 jts of DP and POOH standing back 72 stands of DP. 126k u wt. to BHA. 18:00 19:00 1.00 321 7,325 COMPZ RPEQPI TRIP P POOH w/ BHA #1 -recovered 5' of 2 7/8 TBG stub -parted at ~I"i3R In P _ , small bottle neck. 19:00 00:00 5.00 7,325 7,325 COMPZ RPEQPI JAR P Rih & Located TBG stub @ 7325'. Seen good psi increase. Shut down pump and engage fish. Started jarring 75k osw to 80% osw. Rotate after every 10th jar hit. Rih Wt=115k / 126 Up Wt. Started Jarring. 200k on u hits & 225k strai ht ull. 5/25/2010 MU &RIH with Overshot bowl & Guide assy and Jar a Total of 75 times before parting a 4'-9" section of 2 7/8" tbg. MU & RIH w/Drag tooth shoe & washpipe down to top fill @ 7334', rotated down Lower sub section on to of acker 7351'. 'Page 5 of 9 r~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 01:30 1.50 7,325 7,325 COMPZ RPEQPI FISH P Jared on Fish a total of 75 hits. 200k jarring & 225k straight pull. Seen break over after 75 hits. 01:30 03:30 2.00 7,325 7,325 COMPZ RPEQPI CIRC P CBU with 10.5 ppg @ 2.50 bpm @ 200 si. 03:30 07:30 4.00 7,325 321 COMPZ RPEQPI TRIP P POOH, S/B DP to surface 07:30 08:30 1.00 321 0 COMPZ RPEQPI PULD P OOH. Remove Baker Fishing Tools, Recover another 4'.9" 2 7/8" Stub. The Overshot Bowl and Guide was wedge inside Extension Section.Top of stub now 7330'ft. 08:30 11:00 2.50 0 0 COMPZ RPEQPI PULD P Lay down fishing assy. 11:00 12:00 1.00 0 0 COMPZ RPEQPI SVRG P Service Top Drive. 12:00 15:00 3.00 0 0 COMPZ RPEQPI OTHR X Wait on Drag shoe & 5 3/4" OD wash pipe to was over the OEJ, long wait time due to poor roads condition to and from Deadhorse. 15:00 15:30 0.50 0 0 COMPZ RPEQPI PULD P MU BHA #3, 6"drag tooth shoe and 1 jt of 5 3/4" washpipe on 3 1/2" drill i e. 15:30 19:00 3.50 0 334 COMPZ RPEQPI TRIP P RIH w/Drill pipe & BHA #3 19:00 20:30 1.50 7,334 7,351 COMPZ RPEQPI DRVE P Tag @ 7324', Up wt=127k down wt= 113k,strack down 10k, tool drop down to top of fill at 7334'.Work down rotating to 7351', seen good psi increase @ profile, wt while rotating 120k. Continue washing up & down on stub down to profile @ 7351' @ 40 to 60 rpm, 52 SPM - (2.5 BPM) 210-220 si. 20:30 23:30 3.00 7,351 7,351 COMPZ RPEQPI CIRC P Circulate sweep around to surface, seen good heavy thick fluid @ shakers with a trace of fill. CBU, Blow down to drive. 23:30 00:00 0.50 7,351 6,260 COMPZ RPEQPI TRIP P POOH, S/B Drill Pipe. 5/26/2010 RIH & Pulled OEJ Section & 6' pup jt. RIH w/Washshoe & Washpipe and wash down over Slick-stick to top Packer 7354'.MU & RIH w/BHA #6 Overshot Bowl & Guide 3 1/4" Catch 00:00 03:30 3.50 6,260 334 COMPZ RPCOM TRIP P POOH, S/B Drill Pipe With BHA #3 03:30 04:00 0.50 334 0 COMPZ RPCOM PULD P L/D BHA #3. Had 1/2 gal of Fill inside Washover boot. 04:00 05:00 1.00 0 315 COMPZ RPCOM PULD P MU BHA #4, (Overshot Bowl & Guide 3 21/32" Gr. 05:00 07:30 2.50 315 7,284 COMPZ RPCOM TRIP P RIH w/ BHA #4 to 7284'. 07:30 08:30 1.00 7,284 7,284 COMPZ RPEQPI RGRP P Slip and cut drill line Page 6 of 9 `' Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 08:30 09:30 1.00 7,284 7,331 COMPZ RPCOM FISH P Continue in hole from 7284' to 7331'. Up wt 127K, Dwn wt 113K. Kicked on pump 1.5 BPM w/110 psi. Latched onto fish, pressure increased to 210 psi. Set dwn w/10K. PU and observed seals dragging w/slight overpull. Set back dwn w/20K. PU 20' to clear slick stick, monitored well. Loosing fluid at same rate confirming packer did not unset. BD TD. 09:30 13:30 4.00 7,331 0 COMPZ RPCOM TRIP P POOH from 7331' , LD OEJ, 6' pup jt and 5' piece of 2 7/8" tubing. Break down BHA. 13:30 14:00 0.50 0 334 COMPZ RPCOM TRIP P MU BHA #5 w/washshoe and wash i e. 14:00 16:30 2.50 334 7,338 COMPZ RPCOM TRIP P RIH w/BHA #5 to7338'. Up wt 113K dwn wt 127K ROT wt. 120K. Pumped at 2 BPM 190 si. 16:30 17:00 0.50 7,338 7,354 COMPZ RPCOM FCO P Lowered wash assembly down tagged @ 7353' washed down 1' to 7354', to in solid. To of Pkr . 17:00 21:00 4.00 7,354 0 COMPZ RPCOM TRIP P B/D TD,POOH. 21:00 22:00 1.00 0 0 COMPZ RPCOM PULD P OOH, UD BHA #5, Tools Loo Good 22:00 23:00 1.00 0 0 COMPZ RIGMNI OTHR P Change Out Hyd Hose on Spinner, and Air Relief Valve On Motor. 23:00 23:30 0.50 0 311 COMPZ RPCOM PULD P MU BHA #6 w/ Overshot Bowl & Guide 3 1/4" Catch 23:30 00:00 0.50 311 1,473 COMPZ RPCOM TRIP P RIH w/BHA #6. Depth @ Midnight 1473', RIH Wt= 60k, U Wt=60k. 5/27/2010 Able to Engage and pull packer set @ 7,365'. MU &RIH with 7" casing scraper down to 7450' and circulate hole clean. TOOH sidewa s. 00:00 02:00 2.00 1,473 7,337 COMPZ RPCOM TRIP P RIH To Top of Fish @ 7337', RIH WT=113k / UP WT=127k 02:00 03:00 1.00 7,337 7,330 COMPZ RPCOM FISH P Engage Packer Top, Set Down 10k, PUH to 150k, let jars fire, set back down & puh to 150k rotate 1/4 turn, work pipe up & down, puh to 175k, work up & down, rih again to 150 rotate 1/4 turn, puh to 175k work up & down, PUH to 200k, & packer pull free. Rlh and confirm acker is free. 03:00 05:00 2.00 7,330 7,330 COMPZ RPCOM CIRC P Circulate B/U. Seen small amount of Gas @ 181 bbls away. Continue Pumping B/U, Waiting On Good Mud Densit . 05:00 10:30 5.50 7,330 0 COMPZ RPCOM TRIP P POOH laying down fish. Recover slick stick, HRP-1 packer, 10' pup jt, D-nipple,l jt of 2 7/8" tuibng and shear out sub. 10:30 11:30 1.00 0 0 COMPZ RPCOM TRIP P Clean rig floor and tools. Clear out old completion equipment etc. from i e shed, re for runnin sca er. 11:30 14:30 3.00 0 7,450 COMPZ RPCOM TRIP P MU 7" casin scra er w/6 1/8" bit (BHA #7). RIH to7450', PU 10' to 7440'. Page 7 of 9 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 14:30 16:30 2.00 7,450 7,450 COMPZ RPCOM CIRC P . Established circulation, pump rate 2.5 BPM w/200 psi. Pumped 35 bbls Hi-Visc until hole clean. 16:30 00:00 7.50 7,450 300 COMPZ RPCOM PULL P POOH laying down 3 1/2"drill pipe. 5/28/2010 UD Drill Pipe & BHA #7. RU E-Line and RIH w/ 6 1/8" gauge ring down to 7472'. PU & RIH w/ F-1-Packer assy with CCL. Correlated and Set Packer top of Packer @ 7430', in middle of casing collar @ 7418' & 7441'. Ri off E-Line. MU & RIH w/ 2 7/8" Tb down to 7185', and TOOH sidewa s with tubin . 00:00 01:00 1.00 300 300 COMPZ RPCOM PULL P TOOH sideways. 01:00 01:30 0.50 300 0 COMPZ RPCOM PULD P Lay Down BHA #7. Call Out E-Line 01:30 02:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM, While draining stack. 02:00 04:00 2.00 0 0 COMPZ RPCOM NUND P Start Prepping stack for 11" x 7" OTIS connection. Unload Drill Collars from pipe rack.(E-Line On Location 03:00 04:00 05:30 1.50 0 0 COMPZ RPCOM NUND P PJSM w/HES a-line crew and rig crew. RU HES E-line. Test e ui ment. 05:30 08:00 2.50 0 0 COMPZ RPCOM ELNE P MU 6 1/8" gauge ring and RIH to 7472'. POOH, LD au a rin . 08:00 12:30 4.50 0 0 COMPZ RPCOM PACK P PJSM w/HES crew covering rig up of setting tool & packer. MU F-1 packer assy and running tool w/CCL. Correlated with Cement Bond Log and CTD log. Adjusted depths and set acker at 7430' to of ack r in the middle of casing collars at 7418' &7441'. POOH laying down setting tool. RD HES a-line equip. and load out. 12:30 15:00 2.50 0 0 COMPZ RPCOM NUND P ND shooting flange. NU riser and flowline. Fill hole, monitor well for 15 min. to confirm SOS did not shear, well was static. 15:00 17:00 2.00 0 7,185 COMPZ RPCOM TRIP P RIH w/ 2 7/8" Tbg to 7185' Up Wt= 70k Down Wt= 65k 17:00 00:00 7.00 7,185 0 COMPZ RPCOM PULD P TOOH, sideways w! 2 7/8" Tbg 5/29/2010 MU &RIH 3.5" Tubing w/ Upper Packer Assembly down to Lower Packer Assy @ 7437' .Located Seal Bore Assy, space out set FHL packer and space out Shear off PBR. TIH & Landed tubing Hanger.PT tbg 2500 psi for 15 mins & PT IA to 2500 si for 30mins.N/D BOPE, NU Tree ~ Tested re- rocedure. 00:00 00:30 0.50 0 0 COMPZ RPCOM PULD P Pull Wear Bushing, RU floor to 3.5" Com letion. 00:30 02:00 1.50 0 0 COMPZ RPCOM PACK P RU Completion Assembly. 02:00 11:30 9.50 0 7,437 COMPZ RPCOM PUTS P TIH w/ 3 1!2" Tubing & Completion. 5595'. RU spooler and control line to SSSV. Continue running in hole with completion to 7437' just above F-1 acker. Page 8 of 9 ~~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 11:30 13:00 1.50 7,437 7,437 COMPZ RPCOM CIRC P RU head pin. Displace well to corrosion inhibited seawater by pumping 10 bbls clean seawater, 205bb1s corrosion inhibited seawater, and 70 bbls clean seawater. Pum ed at 3 BPM wl725 si. 13:00 14:00 1.00 7,437 7,437 COMPZ RPCOM HOSO P Locate seal boree receptacle by running charge pump down tbg. while TIH. Turn off charge pump when pressure increased 15 psi. RIH to bottom out seal assy. PU neutral wt +1' and pressure up to 1800 psi and set FHL acker. 14:00 15:00 1.00 7,434 7,437 COMPZ RPCOM HOSO P PU 11 K overwt and sheared PBR above FHL packer. Spaced out positioning one full jt below tubing hanger. Space out left locator 3' above located position when landed. TIH and land tubin han er. RILDS. 15:00 17:00 2.00 0 0 COMPZ RPCOM PRTS P PT tubing to 2500 psi for 15 min. Bleed tbg to 1650 psi. PT IA to 2500 psi for 30 min (charted). Bleed IA to 0 psi followed tbg. to 0 pis. Pressure IA to 1850 psi and sheared SOV in GLM 7166'. 17:00 17:30 0.50 0 0 COMPZ WHDBO SEQP P Set H-BPV. PJSM, Crew Change Out. Off Hi hline Power 1900 hrs. 17:30 21:30 4.00 0 0 COMPZ WHDBO NUND P N/D BOPE. C/O VPR to 4 1/2" on BOPE. 21:30 00:00 2.50 0 0 COMPZ WHDBO DHEO P Called DSO, NU 3 1/8" 5m Tree. Pull 'H' BPV, Set Tree Test Plug. PT tree to 250/5000 psi. PT PO to 250/5000 psi. Tested Good. Pulled Test Plug.( Held Test for 30 mins 5/30/2010 00:00 00:30 0.50 0 COMPZ WHDBO THGR P PJSM, Pull BPV. 00:30 01:00 0.50 COMPZ RISER CIRC P R/U Circ Equipment. 01:00 02:30 1.50 COMPZ RISER CIRC P PJSM w/ LRS, RU LRS Equipment, Pump 70 bbls down IA Up Tbg @ 2 b m 600 is ICP / 800 FCP. 02:30 03:30 1.00 COMPZ RISER CIRC P Allow well to U-Tube for 1 hour. 03:30 04:00 0.50 COMPZ RISER RURD P RD Circulating Hoses. 04:00 04:30 0.50 COMPZ SURFEC SEQP P Set Type'H' BPV 04:30 08:00 3.50 COMPZ MOVE MOB P Start RDMO Operation. Wait On DSO Before moving off well. Clean cellar, around well site. Load tree for next well in cellar. Released Nordic 3 ri 08:00 hrs Page'9 of 9 • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cutting Torch: 3K-12 Run Date: 5/23/2010 May 27, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3K-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21655-00 r ;7 ~ k; ~ fftt'L PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@h~ilt v -- Date: t, i~f l~ ~i- e 1 ~ (o -" / ~J~ ~~~~ U Signed: v STATE OF ALASKA ALASl~IL AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~. operations Performed: Abandon ^ Repairwell ^ Plug Fbrforations ^ Stimulate ^ Other G WINJ to OIL Alter Casing ^ FUII Tubing Pbrforate New Fbol ^ Waiver ^ Time Extension ^ g pp g ^ Op ^ Perforate ^ Re-enter uspended We0 ^ Chan e A roved Pro ram ~ erat. Shutdown P" - '~ ~ ~ t4 2.Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 186-165 3. Address: Stratigraphic ^ Service ~ API Number: I •La P. O. Box 100360, Anchorage, Alaska 99510 50-029-21655-00 7. Propl~ty Designation: 8. Well Name and ber: ADL 25629 3K-12 9. Field/Pool(s): Kuparuk River Field /Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured ; 7770 feet Plugs (measured) None true vertical 6977 feet Junk (measured) None Effective Depth measured 7667 feet Packer (measured) 7365 true vertical 6892 feet (true verucal) 6644 C ollapse Casing Length Size MD TVD Burst ®® ` n ' ~ OR p "' 3978 9 5/8 3978 3887 (t~~1... SURFACE PRODUCTION 7754 7 7754 6965 Aleslta Oil $ Be: Lens. Corrtmissio Anchorage Perforation depth: Measured depth: 7472-7487 ; 7506-7536'; 7542-7543 ; 7549-7550 ; 7556-7561' - 680 5 ' True Vertical Depth: 6732-6744'; 6760-6785'; 6790-6791'; 6796-6796 ; 6801 cP ry ,, ~~ yy ,,„„ {{ hh Tubing (size, grade, MD, and TVD) 2-7/8", J-55, 7417 MD, 6687 TVD Packers & SSSV (type, MD, and TVD) PACKER - CAMCO'HRP-1-SP' PACKER @ 7365 MD and 6644 TVD TRDP - CAMCO'TRDP-1A-SSA' @ 1766 MD and 1766 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 373 750 2884 Subsequent to operation 3 285 2925 1286 456 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run E~loratory ^ Development ~ Sence [; .Well Status after work: Oil ~ Gas ^ WDSPL [~ Daily Report of Well Operations X GSTOR ^ WAG ^ GASINJ ^ WINJ ^ SPLUG ^ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt: 309-404 Contact Bob Christensen/Darrell Humphrey Printed Name obert D. Christensen Title Production Engineering Specialist Signature Phone: 659-7535 Date D1`~ ~ ~. to RBDMS JAN 2 0 ~0~ c~'1-~ 1~ ~ ZO•~~ Form 10-404 Revised 7/2009 5~~~~~ my • 3K-12 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/09/10 Well converted to production to releave pressure for drilling. Put on production at 1300 hours. ,~'~ KUP ~ 3K-12 iC~Q~ j"jf "14: ell Att ributes Max An le $ MD TD l AIdSkA ltn Welibora APIIUWI Fieltl Name Wall Statue Inc! (°) MD (ftNB) Act Btm (ftKB) . 500292 165500 KUPARUK RIVER UNIT INJ 37.1 8 4,700.00 7,775.0 Comment H25 (ppm) Data An notation Entl Data KB-Grtl (R) Rig Release Date "' __-- SSSV: TRDP Last WO: 8/2311991 39.01 11/12/1986 Wall Con -3K-1210 /11Q W93'.28.1 6 FM emalio -Ad uel Annotation Depth (HNB) Entl Oate Annotation last Motl By Entl Date Last Tag: SLM 7,558.0 10/9/2009 Rev Reason: Tag Fill Imosbor 11/11/2009 Casin Strin s String OD String ID Set Depth Set Deptl7 (TVD) String Wt String Casing D escription (in) tin) Top (ftKB) (RKB) (RNB) (Ibattt) Oratla String Top Thrtl CONDUC TOR i 6 15.062 0.0 110.0 110.0 62.50 H-00 SURFACE 9 & 8 8.765 0.0 3,978.0 3,887.4 36.00 J-55 CONDUCTOR PRODUCTION 7 6.151 0.0 7,754.0 6,964.5 26.00 J-55 , 170 Tubin Strin s String OD String ID Set Depth Bet Depth (TVD) String Wt String Tubing Deacriptlon Iinl lint Top (ftKB) (RNB) (RKB) (Ibs/ft) Dratle String Top Thrtl TUBING 27/ 8 2.441 0.0 7,417.0 6,686.7 6.50 J-55 EUESrdABMOD Other In Hole A ll Jewe l :Tubin Run 8 R etrievable Fish etc. SAFETY VLV, 1 ~~ Top Depth (TVD) Top Inc! Top (ftl(B) (RKB) (°) Deacriptlon Comment Run Dete ID (in) 1,766 1,766.0 0.29 S AFETY VLV Cameo TR DP-IA-SSA' 8/23/1991 2.312 7,294 6,585.4 34.45 G AS LIFT MA0002 7/8 X 1 1/2I1.5/DMY/TGI//Comment: STA 1 8!23/1991 2.347 SURFACE, 7,347 6,629.1 34.55 S BR Camco'OE J' SBR 8!2311991 2.312 3.978 7,365 6,643.9 34.56 P ACKER Camco'HR P-iSP' PACK ER &23/1991 2.347 7,383 6,658.7 34.56 N IPPLE Camco'D' N ipple NO GO 8/23/1991 2.250 GAB LIFT 7,417 6,686.7 34.58 S 0.S Baker 8/23/1991 2.441 , 7,z94 7,417 6,686.7 34.58 T TL 8/23/1991 2.441 Perfora tions & Siots Shot Top (TVD) Btm (TVD) Dana Top (RI(B) Bfm (RKB) (RKB) (RKB) Zone Date Iab... Type Comment 7,472 7,489 6,732.0 6,746.0 A -3, 3K-12 8!27/1992 4.0 RPERF 2 1/8"SilverJet, 0 deg, ph 7,479 7,480 6,737.8 6,738.6 A 3, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet seR. ],30 7,gg2 7,883 6,740.2 6,741.1 A -3, 3K-12 1/14/1987 1.0 IPERF SINGLE SHOT; 21/8" ErterJet 7,484 7,485 6,741.9 6,742.7 A 3, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,486 7,487 6,743.5 6,744.4 A -3, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet PACKER, 7,365 T a 7,506 7,507 6,760.2 6,761.0 A 3, 3K-12 111411987 1.0 IPERF 2118" EnerJet r t 7,506 7,536 6,760.2 6,784.8 A -2, 3K-12 82711992 4.0 RPERF 2 1/8"SilverJet, 0 deg. ph 7,512 7,513 6,765.1 6,765.9 A -2, 3K-12 1/14!1987 1.0 IPERF 2 1/8" EnerJet 7,520 7,521 6,771.7 6,772.5 A -2, 3K-12 1/14!1987 1.0 IPERF 2 1/8" EnerJet 7,528 7,529 6,778.2 6,779.0 A -2, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,535 7,536 6,784.0 6,784.8 A -2, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet N]PPLE, ],383 7,542 7,543 6,789.7 6,790.5 A -2, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,549 7,550 6,795.5 6,796.3 A -2, 3K-12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,556 7,561 6,801.2 6,805.3 A -2, 3K-12 1/14/1987 1.0 IPERF 21/8' EnerJet SOS, 7 417 TTL, 7,417 IPERF, 7,17&7 4B° RPERF, 7,172-7189 IPERF, 7,462-7,463 IPERF, 7,484-7,485 IPERF, 7,/88-7,487 IPERF, 7506-7,5°7 IPERF, 7,512-7,513 IPERF, 7,520-7.521 RPERF, 7,508-7 538 IPERF, 7,528-7.529 IPERF, 7,5357,536 IPERF, 7,542-7 543 IPERF, 7,51&7,550 IPERF, 7556-7,561 PRODUCTION, 7,75/ TD, 77]5 h , I Y �L , 66 a SEAN PARNELL, GOVERNOR L ALASKA OIL AND GALS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION atl ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 2 Anchorage, AK 99510 Re: Kuparuk River Unit, Kuparuk Oil Pool, 3K -12 16D Sundry Number: 309-404 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next 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, Daniel T. Seamount, Jr. Chair DATED this/ of December, 2009 Encl. Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit, NSK -69 PO Box 196105 ConocoFfiflfirps.- Anchorage, 6 99519 -6105 Phone: (907)659 -7535 Fax: 659 -7314 December 2, 2009 RECEIVED DEC 0 4 2009 Tom Maunder, P.E. Alaska Oil &Gas Cons. COmmISS10p Senior Petroleum Engineer Anchorage State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Maunder, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk Well 3K -12 from Water Injection Service to Oil Production service. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. for 3K -12 (PTD 186 -165). If you have any questions regarding this matter, please contact myself or Darrell R. Humphrey at 659 -7535. Sincerely, Robert D. Christensen Attachments STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon ❑ Suspend ❑ Operational Shutdown ❑ Perforate ❑ Waiver ❑ Other ❑✓ Alter casing ❑ Repair well ❑ Plug Perforations ❑ Stimulate ❑ Time Extension ❑ WINJ to Oil Change approved program ❑ Pull Tubing ❑ Perforate New Pool ❑ Re -enter Suspended Well ❑ Conversion 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 186 - 165 3. Address: Stratigraphic ❑ Service Q . 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21655 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line S. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes Ej NO ❑✓ 3K -12 9. Property Designation: 10. KB Elevation (ft): 11. Field / Pool(s): KupXmMR v. rtinir .14 /P I'Z epi RKB 69' • I Kuparuk River Unit / Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): o' 7711.E t _ 6 ��l 7 7 7667' 6893' Casing f -n Length ` ° . Size MD TVD Burst Collapse CONDUCTOR 110' 16" 110' 110' SURFACE 3909' 9 -5/8" 3978' 388T PRODUCTION 7685' 7" 7754' 6965' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tu Size: Tubing Grade: Tubing MD (ft): 7472'- 7561' 6732'- 6805 � /� - J -55 7417' Packers and SSSV Type: Packers and SSSV MD (ft) 12,. , 01 PKR = CAMCO "HRD -1 -SP" 7365' SSSV = CAMCO "TRDP -1A -SSA" 1766' 13. Attachments: Description Summary of Proposal ❑✓ 14. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory [] Development ❑✓ Service ❑ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Dec 23, 2009 Oil Gas ❑ Plugged ❑ Abandoned 17. Verbal Approval: Date: WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑ Commission Representative: 18. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: B. Christensen/ D. Humphrey Printed Name / ,-- ) R Obe D. Christen Title: Production Engineering Specialist Signature Phone: 659 -7535 Date Commission Use Onl Sund Numbe Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /0 - YU'y 1Q APPROVED BY by: ( MMISSIONER THE COMMISSION Date: rW!P om11% 0 evised 06/2006 " /� 'i�o� Submit in Duplicate /Z, re-I 3K -12 DESCRIPTION SUMMARY OF PROPOSAL • ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3K -12 from Water Injection service to Oil Production service for a period of time expected to be between 2 - 3 months. Conversion of this well is required to depressure the formation to allow safe CTD sidetrack operations of well 3K -12. Well 3K -12 was completed on November 12, 1986 as a standard single, providing pressure support in the Kuparuk A sands. The 9 -5/8" Surface casing (3978' and / 3887' tvd) was cemented with 980 sx AS IV and 320 sx Class "G" followed by 175 sx AS I. The 7" Production casing (7754' and / 6964' tvd) was cemented with 300 sx Class 'G" followed by 175 sx AS I. The injection tubing /casing annulus is isolated via Camco HRP -1 -SP 2 -7/8" x 7" Packer located @ 7365' and / 6644' tvd. An MIT -IA was last performed on 05/15/09; MITIA 2300 psi, 30 minutes, Passed An MIT -OA was last performed on 06/16/07; MITOA 1750 psi, 30 minutes, Passed KUP • 3K -12 C IOc(; Ihi fIps Well Attributes Max Angle & MD TD Alaska, Inc. Wellbore API /UWI Fhld Nertrs Well Shale Incl ( °) MD (RKB) Act Btm (rtKB) 500292165500 KUPARUK RIVER UNIT INJ 37.18 4,700.00 7,775.0 Comment H2S (pp-) Data Annohlion End Date KB -0rd (R) Rig Release Deb Weu Corm -3K -12 lone 3:28.16 PM SSSV: TRDP Last WO: 8/23 /1991 39.01 11112/1986 Schematic -"usl Annotation Depth (RKB) End Date Annotation Lasl Mod By End Dale Last Tag: SLM 7,558.0 10/9/2009 Rev Reason: Tag Fill Imosbor 11/11/2009 Casing Strings String OD String ID Sat Depth Set Depth (TVO) Siring Wt String Casing Description (in) (In) Top (RKB) (RKB) (MB) (Ibsflt) Grade String Top Third CONDUCTOR 16 15.062 0.0 110.0 110.0 62.50 H-40 SURFACE 95/8 8.765 0.01 3,978.0 3,887.4 36.00 J -55 PRODUCTION 1 71 6.151 0.01 7,754.0 6,964.5 26.00 J -55 CONDUCTOR, 710 Tubing Strings String OD String ID Set Depth Sat Depth ITVD) String Wt String Tubing Description tin) (In) Tap (RKB) (RKB) (RKB) (IDSR1) Grade String Top Third TUBING 1 2718 2.441 0.0 7,417.0 6,686.7 6.50 J -55 JEUE8rdASMOD SAFETY VLV Other in Hole All Jewelry: Tubing Run & Retrievable Fish etc. 7,766 47 Top Depth (TVD) Top Incl Top (Po(B) (RKB) (°) Description Comment Run Date 10 11.) 1,766 1,766.0 0.29 SAFETY VLV Camco7RDP- 1ASSA' 823/1991 2.312 7,294 6,585.4 34.45 GAS LIFT MACCO2 7/8 X 1 1 /2I1.5JDMY/TG/ // Comment: STA 1 8/2311991 2.347 SURFACE 7,347 6,629.1 34.55SBR Camco'OEXSBR 8/23(1991 2.312 3.918 7,365 6,643.9 34.56 PACKER Cemco'HRP -1SP' PACKER 8/2311991 2.347 7,383 6,658.7 34.56 NIPPLE Camco'D' Nipple NO GO 82311991 2.250 GAS L =i 7,417 6,686.7 34.58 SOS Baker 23/ 81991 2.441 1294 7,417 6,686.7 34.58 TTL 823/1991 2.441 Perforations & Slots Shot Top (TVO) I etm (TVO) Done Top(RKB) Btin(RKB) (RKB) (RKB) Zone Deto ph... Type Comment 7,472 7,4891 6,732.01 6,746.0 A -3, 3K -12 8/27/1992 4.0 RPERF 2 1/8 "SilverJet, 0 deg. ph 7,479 7,480 6,737.8 6,738.6 A3, 3K -12 1/14/1987 1.0 IPERF 21/8" EnerJet seR, 7.347 7,482 7,483 6,740.2 6,741.1 A3, 3K -12 1/1411987 1.0 IPERF SINGLE SHOT; 21/8" EnerJet 7,484 7,485 6,741.9 6,742.7 A3, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,486 7,487 6,743.5 6,744.4 A3, 3K -12 1/14/1987 1.0 IPERF 2 1 /8" EnerJet r - ' 7,506 7,507 6,760.2 6,761.0 A3, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet PACKER, 7, 365 1 1 7,506 7,536 6,760.2 6,784.8 A -2, 3K -12 8/27/1992 4.0 RPERF 2 1/8 "Silver let, 0 deg. ph 7,512 7,513 6,765.1 6,765.9 A -2, 3K -12 1/14/1987 1.0 IPERF 2 1B" EnerJet 7,520 7,521 6,771.7 6,772.5 A -2, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,528 7,529 6,778.2 6,779.0 A -2, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,535 7,536 6,784.0 6,784.8 A -2, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet NIPPLE, 7.383 - 7,542 7,543 6,789.7 6,790.5 A -2, 3K -12 1/14/1987 1.0 IPERF 2 1/8" EnerJet 7,549 7,550 6,795.5 f 0,796.31A-2,3K-12 1/14/1987 1 1.0 IPERF 12 1/8' EnerJet 7,556 7,561 6,801.21 6,805.31A-2, 3K -12 linvigui I 1.0 IPERF 12 1/8" EnerJet sos, 7,417 TTIE 7,417 IPERF, 7,4767,490 RPERF, 7,472 -7,409 IPERF, 7,482 -7,483 IPERF, 7,484-7,405 IPERF, 7,486 -7,487 - IPERF, 7,508 -7,507 IPERF, 7,512 -7,513 IPERF. 7,520 -7,521 RPERF, 7,505- 7,536 IPERF, - 7,529 -7,529 IPERF, 7,5357,536 -_ IPERF, 7,542 -7,543 - -- IPERF, 7,5467,550 PERF, 7,5667,597 PRODUCTION, 7,754 To. 7,775 MEMORANDUM TO: Jim Regg y~ P.I. Supervisor ( ~~~ ~~1 ~" ~ FROM: Chuck Scheve Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-12 KUPARUK RIV UNIT 3K-12 Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv ` Comm Well Name: KUPARUK RN UNIT 3K-12 Insp Num: mitCS09051s161606 Rel Insp Num: API Well Number: 50-029-216ss-00-00 Permit Number: 186-165-0 Inspector Name: Chuck Scheve Inspection Date: 5/ls/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Ka2 ' Type Inj. N Z'~7p 6643 '~ IA 720 2360 2300 2300 P.T.D 18616s° ' TypeTest i sPT Test psi 1660.75 OA aao soo soo soo Interval aYRTST p~F P ~ Tubing z7so z7so 27so z7so NOtes• Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. ~ ;~ ~, ,. ~l ~~ n^~ -~ Wednesday, May 20, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska JUL 0 3 2007 8l Cons;> P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 \ \oS \~ lo/ Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 sCANNED JUL 05 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ITom entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. ~~ M.J. Loveland ConocoPhillips Well Integrity Supervisor e-----/~ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 1C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 1 C-190 2_ 27" none 27" na 10 6~ ";;,, -B 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 ) ') Tom Maunder, P .E. Senior Petroleum Engineer State of Alaska 33 W. 7th Ave. Ste. 100 Anchorage,AJ< 99501 January 19, 2006 Robert W. Buchholz / Robert Christensen Greater Kuparuk Unit Production Engineering Technician (907) 659-7535 RECEIVED JJj N 2 0 7006 Alaska Oil & Gas Cons Cnnvni . . VIIHIQss,on Anchorage \ ~~- (Cr1Ç ~C!-\NNE¡r) ~Jt~,N 2 0 2005 Tom: Enclosed is a correction of a 10-404 for 3K-12. On 5/23/2003, this well returned to water injection service. The original10-404 checked the well status as WAG. There are no plans to make any injectors on the 3K drill site WAG wells. Therefore, the correct well status for 3K-12 is WINJ (water injection). Robert W. Buchholz RECEIVED ') ) JAN 2 0 2006 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commissio REPORT OF SUNDRY WELL OPERATIONS Anchorage o Oil to WINJ Time Extension 0 o Repair Well D Pull Tubing D Operat. ShutdownD Abandon D Alter Casing D Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 69' 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING PROD. CASING PROD. CASING Perforation depth: Stimulate D Waiver 0 Plug Perforations D Perforate New Pool 0 Perforate D 4. Current Well Status: Development D StratigraPhiC' 0 Service Other Re-enter Suspended Well 5. Permit to Drill Number: 186-165 6" API Number: 50-029-21655-00 Exploratory D o 9. Well Name and Number: 3K-12 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 7775' feet true vertical 6982' feet measured 7667 feet true vertical 6893 feet Length Size MD 110' 16" 110' 3909' 9-518" 3978' 7685' 7" 7754' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3887' 6965' Measured depth: 7472-7561' true vertical depth: 6732-6805' Tubing (size, grade, and measured depth) 2-7/8", J-55, 7417' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7365' SSSV= SSSV SSSV= 1766' 12. Stimulation or cement squeeze summary: Intervals treated (measured) none RBDMS 8Ft. .IAN 2 0 2006 13. Treatment descriptions including volumes used and final pressure: Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl TUbinQ Pressure 965 965 Casinq Pressure 10 585 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run_ 1736 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAGD 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 if C.O. Exempt: Daily Report of Well Operations _X Contact Printed Name Signature WDSPL D Title Phone Production Engineering Technician 907-659-7535 Date 1/19/2006 Form 10-404 Revised 04/2004 Submit Original Only ·' Date Event Summary ) 3K-12 DESCRIPTION OF WORK COMPLETED SUMMARY 5/23/03 I Returned well to Water Injection service III . ; ) lVIE1VlUKANlJUM ) State of Alaska ) Alaska Oil and Gas Conservation Commission TO: Jim Regg \~ P.I. Supervisor I \,'1e¿" -bl (4 f ü5" DATE: Wednesday, May 25, 2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-12 KUPARUK RIV UNIT 3K-12 \ó \IeG \~ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: -\Po P.I. Suprv ~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3K-12 Insp Num: mitCS050521l53625 Rei Insp Num: API Well Number: 50-029-21655-00-00 Permit Number: 186-165-0 Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3K-12 Type Inj. w ITVD 6644 IA I 400 2040 2000 1990 P.T. 1861650 TypeTest SPT I Test psi 1661 OA 200 480 480 480 Interval 4YRTST P/F p Tubing 2850 2850 2850 2850 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCl~NNED JUt () 'l2DDS Wednesday, May 25, 2005 Page 1 of 1 ) ') STATE OF ALASKA ..¡0Ç ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test {tP"" ;?'j;~~,OO~r' ~'t, 0 ~ {JJQ r Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.a. ; a 'i _ 'tfg i.tsta ~. .. ,) OPERATOR: ConocoPhillips Alaska Inc. FIELD 1 UNIT 1 PAD: Kuparuk 1 KRU/3K DATE: 05/21/05 OPERATOR REP: Arend 1 Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. well3K-02 I Type Inj I S I Tv.D·1 6421 I Tub~ng I 27501 27501 27501 2750 I Interval I 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 1 550 1 550 1 550 we"3K-04 I Type Inj I S I T.V.D. 6431 I Tubing I 30001 30001 30001 3000 Interval 4 P.T.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 1 350 1 350 1 350 well3K-05 I Type Inj I S I T.V.D. 6341 I Tubing I 27501 27501 27501 275OI'nterval 4 P.T.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 1 940 1 940 1 940 well3K-07 1 Type Inj I S I T.V.D. 6565 I Tubing I 29501 29501 29501 2950 Interval I 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 1 340 1 340 1 340 we"3K-12 I Type Inj I S I T.V.D. 6644 I Tubing I 28501 28501 28501 2850 \ Interval I 0 . P.T.D. 1861650 Type Test P T est psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 1 480 1 480 1 480 we"3K-13 I Type Inj I S I T.V.D. 6376 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 1 600 1 600 1 600 Well\3K-15 I Type Inj I S I T.V.D. 6448 Tubing I 28501 28501 28501 2850 Interval I 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 1 450 1 450 1 450 well3K-18 I Type Inj I S I T.V.D. 6605 Tubing I 22001 22001 22001 2200 I Interval I 4 P.T.D. 1861510 Type Test P T est psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 1 560 1 560 1 560 well3K-19 I Type Inj I S I T.V.D. 6331 Tubing I 27501 27501 27501 2750 \ Interval I 4 P.T.D. 2011080 Type T~st P T est psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 1 620 1 620 1 620 well3K-25 I Type Inj I N I T.V.D. 6552 I Tubing I 27~1 275\ 275\ 275\lnterval 4 P.T.D. 1980810 Type Test P Test psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 1 600 1 600 1 600 Well 3K-26 I Type Inj I S I T.V.D. 6656 I Tub~ng I 27501 27501 27501 2750 I Interval I 4 P.T.D. 1970770 Type Test P T est psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 7201 780 1 780 1 780 we1l13K-3O I Type Inj I S I T.V.D. 6580 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1971130 Type Test P Test psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 1 460 1 450 1 450 Well 13K-31 I Type Inj I S I T.V.D. 6117 I Tubing I 285~1 28501 28501 285Ollnterval 4 P.T.D. 1980820 Type Test P T est psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 1 600 I 600 1 600 we1l13K-34 I Type Inj I S I T.V.D. 6285 I Tub~ng I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1980770 Type Test P Test psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400/650 I 650 1650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water In] M = Annulus Monitoring I = Initial Test G = Gas Inj P = standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during Workover D = Differential Temperature Test o = Other (describe In notes) MIT Report Form 5/24/2005 Revised: 05/19/02 MIT KRU 3K 05-21-05.xls ... ~ ConocoPh illi pS Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 2, 2004 Mr. Tom Maunder )x aD rrJ Alaska Oil & Gas Commission ~ r 5:/ 0 ~ 333 West ih Avenue, Suite 10 ('-\~ Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top ofthe circulation ports in the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. The top-fill operation was completed on April 29, 2004. Dowell-Schlumberger batch-mixed Arctic Set II cement to 15.7 ppg in a blender tub. The cement was placed in the conductor from the bottom-up via a hose ran to the bottom of the void. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volume used on each conductor. Please call Marie McConnell or me at 907-659-7224, if you have any questions. Sincerely, b%,* \~<L~"-\-\ ",- ~~\ ~'~ ~~ k~« ( ~ \~ ~ '\\ \ "':> ""ù \- ~ ~ ~ç;>~ \ ~ \"' \- \"",-c CE <J'-'\.v V",,- T '-16 \( ¥U 'l ~ \ \ \JQ,~ \..\(.. {~ \ \ ~(n\'--^,{¿ ",,- \- \a \?'" (, \-., +- \'-G:~ ~ \ \. ~ ~Cc W "-i~\.\l.,,\ v"- '~\'-<é c..ú~ ~ c~:::- . kífíf\( S- (~- G t;j fZ-tc~ Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment RECEIVED MAY 042004 Alaska Oil & Gas Cons. Commission Anchorage . WEll NAME 2C-09 2M-33 3H-21 3H-24 3H-28 3H-32 3K-12 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-off Kuparuk Field April 29, 2004 PTD# SERVICE CEMENT TOP TYPE It 1842210 Producer 54.0 1960720 Producer 40.0 1880080 Producer 34.0 1960150 Injector 25.0 1960370 Producer 20.0 2000010 Producer 10.0 1861650 Injector 48.0 Arctic Set 1115.7 PPG Cement II --(I .~ ,c~/" - \ b --'('~ L'> \ \/ -t. -\ - t;: u ,^,- "'\ VOLUME BBlS 9 5 5 3 4 2 10 c. . \ ' ~ \¿ \ ~'D I+t- '--.,(¡.'-J, t: '....; .:; ,,~\~~,,-<ë ~ \:è\ .;, ~ .' L-\ ,L\ I ~:? ( ,;) , <.c \ l, ":) \ i (...J. ~ MEMORANDUM State of Alaska TO: Randy R nch Com' sioner .\ \ Oþ¡' Jim Regg /)/7:0 ¿ \l6, P.I. Supervisor ~1: l Alaska Oil and Gas Conservation Commission FROM: Chuck Scheve Petroleum Inspector DATE: Wednesday, Februmy 18, 2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-12 KUPARUK RIV UNIT 3K-12 THRU: Src: Inspector NON-CONFIDENTIAL API Well Numbe 50-029-21655-00-00 InspN mitCS040217184907 Inspection Date: 2/17/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: 3K-12 Type Inj. P TVD 6644 IA 1320 2100 2070 2070 P.T. 1861650 TypeTest SPT Test psi 1661 OA 920 980 980 980 . -----'---.-"- Interval Initial Test P/F Tubing 2500 2500 2500 2500 Notes: Well recently converted from producer to injector. Pretest pressures observed and found stable. Type INJ. Fluid Codes F =FRESH WATER INJ. G=GAS INJ. S=SALT WATER IN.!. N=NOT INJECTING Type Test M=Annulus Monitoring P=Standard Pressure Test R=lntemal Radioactive Tracer Survey A=Temprature Anomaly Surve D=Differential Temprature Test Interval 1=lnitial Test 4=Four Year Cycle. V=Required by Variance W=Test during Work over O=Other (describe in notes) Wednesday, February 18,2004 \:})(ÇA~íNJE,D M¡4~~ 1 2 2004 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AltetCasing ['-'] . Repair Well [] .... Plug Perforations 'E~ Stimulate ~ Time Extension ~ ' Other r'~ . . .. · :. · . Chef'ge ApProved Program E~ Pull Tubing .r'-~ . P~rf°rate New P0ol r-"] .. .Re~enter susPended.Well ' 2. Operator Name: 4. cufi;~nt'wel!:statu{;':' .. · ' · · . · · · · 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. .Development__;~] ' Exploratory [~] 186-165 / - 3. Address: Stratigraphic r'"] Service [ ' 6. APl Number: P. O. Box 100360 ..... 50-029-21655-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-12 8. Property Designation: 10. Field/Pool(s): Kuparuk Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7775' feet true vertical 6982' feet Plugs (measured) Effective Depth measured 7667 feet Junk (measured) true vertical 6893 feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 16" 110' 110' SUR. CASING 3909' 9-5/8" 3978' 3887' PROD. CASING 7685' 7" 7754' 6965' Perforation depth: Measured depth: 7472-7561 true vertical depth: 6732-6805 RECEIVED Tubing (size, grade, and measured depth) 2-7/8", J-55, 7417' MD. JUN 2 0 2003 Alasl<a Oil & G,as Cor~s. Co~i,ssion Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7365' SSSV= SSSV SSSV= 1766' Anchorage i2. S(imulation'or cement.squeeZe summary: · " .. Intervals treated (measured)= N/A : . Treatment des'qdptions incl.uding volumes used and final pressure: . ... .. .. . 1'3. · · '" .Representative'Dai!y Average .Production 0r:ln]egtion .Data '.' "OiI-Bbl ; ." .. Gas;Mcf .. · · Wate~l~bl ...Casin',q Pressure T~bin~'P~essum Prior to well operation 1 . ' "' :~''" '477'" 1 ;100' ' ' ' '.70~)" S.ubsequf~nt.t0 operation .'. ' ' ' . 988 .' ' 1100' .... 1'610 14. Attach'mehts' "· 15. Well 'Class after p[bpo~ed Work: ' ' Copies of Logs and surveys run _ ... 'Expl0rat6~ '[~] · Development [--] Service r~ Daily Report Of Well Operations ~X 16. Well Status after'proposed. Work:- ." : · Oi'[--~ Gas[]'-]' .WAG r'~ GIN J?-] WINJ r--] WDSPL[~] . 17. I hereby Certify that ihe foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: I Contact Jeff Spencer @ 659-7226 . Pr. inte. d~an3~"~/P~~~stensen/ Title Production Engineering Technician Signature i~/,/~~/_.///~_~ ~ Phone 659-7535 Date 6/18/2003 Form 10-404 Revised 2/2003 · ;CA NE.' JUL, 0 : 003 SUBMIT IN DUPLICATE 3K-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/231031RetU med'well 'to wa~ter .Inje(~tion service I 1 ..... i.' TYpe. 0f ReqUest: Abandon Alter casing Change approved program APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 (~::::)%,,~¢~ ~'b~',br,,,(,~, '~q:b' \~-,,~¢,.:_~C:~ ~-' ~ SuSPend ~ ' ~emfionShutdo~ ~. Pedomte ~ ~ Va~ance ~ ' Annula;~isp,'~ ~' .. Repair well ~ Plug Pe~o~ti~s ~ ' ' Stimulate ~ · :. ~me E~ension ~ .~her ~ ~ .. Pull~ubing.. ~ Ped0ate. N~=~:p~l ' ~ R~nterSus~nd~Well'~ 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 :4,..CuiYent' Well ClasS: · .' " DeveloPment ~ ~]' '. Expl0rato~j D · . strat!graphi(~ E] sewice r-~" 5. Permit to Ddll Number: 186-165 6. APl Number: 50-029-21655-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 69' 3K-12 8. Property Designation: 10. Field/Pool(s): '.'. Kbparuk .unit Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total ~epth MD (ft): 7775' TotalDepthTVD(ff): 6982' Casing Length CONDUCTOR 110' SUR, CASING PROD. CASING Perforation Depth MD (ft): ~. :4-~Z,~'i ..::'. i"i:.';:'. ::. ;: ...:~ 3909' 7685' Effective Depth MD !ft): Effective Depth'l'VD (ft): [Plugs (measured): ]Junk (measured): i.!=.i'".'~ i'i:.:7~71 ':" ;'i.: "' ····:::6893.. '=i.i:.i ':,:.':' i"i ::. '..'=:'.i~.::'.':.:."....:" :: :..;:.".:'.:": '.i.'.: '.' :.'.'=.;... ......... :.i...'...: 'i.'ii'":'i' Size MD . _ 16" 110' 9-5/8" 3978' 7" 7754' Perforation Depth TVD (ft): . ..ITubing Size: ITubing ~ ITubing MD(ft): 6'~;~18~'.:".'.:;;"'::".:.'.:'i"' ::, '. '.:': .',: ':.'..::'..;'..:,...: ..:'i." '.] 2-7/8" [ J-55 ! 7417' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= CAMCO 'HRP-1-SP' pkr= 7365' SSSV= SSSV SSSV= 1766' i2:: Atta~ht$~ ;i ?i;D~c'~i@tiOh' Sbmm;acj ~.'prop0sal .: .'.:[~] · · ~' .i'.. !13:'i...Well Ci~iSS :~fter pi;0'~i~ed. W0~k:. '. :: ...'. ' .' · .;" · ... ' :,."[~t~Ji!~~1 ~pe[a~i;~'.l~[~r:;m:' '..'E~].'...::. "...Bo~ sket~H"';.E] ..: ::'::'":. '; ..:'.: :".EX~lQ.'rai~ty. E]'. 1':';: ':'":' :'. 'D~vel~.ment': ~E] · · '.~14. E~timalted Dat~.foi~..' .: ' .'" ." "";'..' .:. · · ..:.:".'.'. ". ,:' .' ' '1.5: ..Well Status after propqs~l wdrk! '. ';.' ' '..'. · .'" '. · :Com~'~n~{n~:~¢e;,ations:.'. :. ' ..... .'.',~7~,;3!d;3..:"" · '". '.. Oil.. E~. '.':'" .' ..' ':;.:'..Gas'."E] .' "'". ·. pl,gged El' : 16.: v;erb_,.al Appr0v,all : ·, .' · · .'..Da :i~"",~, : ' ..'" .. .. . . ' :17. I he¢~by certifyitba~t the fo(egoing is true and correct to the best Of my knowledge. '. 'Contact: · printe~l N'~tm¢ ~ .iBob~rt'D. c~ri&tens~n ..' . " . 'Title: ' ' Signature Commission Use Only Conditions of approval: Notify Commission so that a representative may witness · W!Nj ..'BI' . . W~SPL"i~ :. · . . .. . .. · .. . ,..-.... . . .. ~l~ff spencer @.659-722'6 " Production Engineerin~ lechdician :'.'Abandoned' :E~ .. Plug Integrity E~ BOP Test E] Mechanical Integrity Test Location Clearance E] Other: RECEIVED Subsequent Form Required: /O-"Z~(;2~/ ,~,/~,,/ ,~1¢¢~ ~ ~--~~ MAY ~ 9 2003 ¢/~/~ Alaska Oil & Gas Cons. Commission - BY ORDER OF Anch0~ge ¢ Approved by: ~~ ~~~'~ COMMISSIONER THE COMMISSION Date: ~~~ Form 10-403 Revised 2/2003 · JUN ORfGfNAL SUBMIT IN DUPLICATE 3K-12 i' DESCRIPTION SUMMARY PROPOSAL ConocoPhillip's Alaska Inc.' is requesting approval to return well 3K-12 to WAG injection service. Well 3K-12 was a Sidetrack candidate for 2003. The well was put on Production on 1/28/03 for . reservoir pressure reduction. The sidetrack has .been postponed until late 2004. Due to produced Water handling requirements at CPF-3, this well needs to put the well back to injection as soonas possible. ., Re: KRU Well 3K-12 (PTD#1861650) Subject: Re: KRU Well 3K-12 (PTD#1861650) Date: Tue, 27 May 2003 13:59:57 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> 3K-12 was returned to injection and BOL 5/23 due to produced water injection hole capacity shortage at CPF3. I will schedule a State witnessed MITIA for the upcoming week. Thanks Nina Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom_maunder@admin.state.ak.us> 05/27/2003 01:26 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: KRU Well 3K-12 (PTD#1861650) Thanks Nina. One other question, when was the well returned to injection?? Tom NSK Problem Well Supv wrote: > Tom- > The paperwork was generated by Bob Christenson and I sent it from the slope > this morning. Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom_maunder@admin.state. ak. us> 05/27/2003 12:56 PM To: NSK Problem Well Supv/PPCO@Phillips CC: Subject: Re: KRU Well 3K-12 (PTD#1861650) Jerry, > A quick question. Where is the paperwork originating?? Is it coming from > you > guys on the slope or from someone here in town?? > Tom > NSK Problem Well Supv wrote: 1 of 2 5~30~2003 10:58 AM Re: KRU Well 3K-12 (PTD#1861650) >> Tom- > > Just wanted to give you heads up on a situation with KRU Well 3K-12 (PTD# > > 1861650). This was an injection well that was approved for temporary > > production via Sundry #303-017. The well has been on production since > > January 2003. Just recently it was converted back to injection and > > operations inadvertently put on line prior to conversion sundry papers > > being approved. The paperwork is in the mail > > Will you please respond to this email as a "verbal approval" for the > > conversion to injection. We would like to leave the well on injection > and > > not shut it in pending paperwork approval Sorry for the confusion. Let > me > > know if you have any questions. > > Thanks, > > Nina Woods > > Problem Well Supervisor > > ConocoPhillips Alaska Inc. > > (907) 659-7224, 659-7043 > (See attached file: tom_maunder, vcf) (See attached file: tom_maunder.vcf) Tom Maunder <tom maunder~admin.state.ak.us> · ii Sr. Petroleum Engineer ~: Alaska Oil and Gas Conservation Commission 2 of 2 5/30/2003 10:58 AM Re: 3K- 12 [~roducer to Injector ,, Subject: Re: 3K-12 Producer to Injector Date: Mon, 02 Jun 2003 13:21:06 -0800 From: Tom Maunder <tom maunder~admin.state.ak.us> To: NSK Problem Well Supv <N1617@conocophillips.com>, Jerry Dethlefs <Jerry. C.Dethlefs~conocophillips.com>, Bob Fleckenstein <bob__fleckenstein~admin.state.ak.us> Sorry about that, the correct well is 3K-12. Tom Maunder wrote: Jerry, Nina or MJ, On the approved sundry to convert 2K-12 back to an injector, I forgot to include that a 404 was required. Would you please send in one to document the switch. Thanks. Tom Maunder, PE AOGCC ~_~ tom_maunder, vcf Name: tom_maunder.vcf Type: VCard (text/x-vcard) Encoding: 7bit Description: Card for Tom Maunder [ of 1 6/3/2003 1:33 AM Re: KRU Well 3K-12 (PTD#1861650) Subject: Re: KRU Well 3K-12 (PTD#1861650) Date: Tue, 27 May 2003 08:09:45 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: NSK Problem Well Supv <n1617@conocophillips.com> CC: bob_fleckenstein@admin.state.ak.us, AOGCC North Slope Office <aogcc_prudhoe_bay@admin.state.ak.us> Hi Jerry, With the few wells that are changed back and forth, this shouldn't be a problem. The important item is that the well previously "qualified" by MIT and cement quality analysis to be a service well. The short production period should not have altered the "qualifications". All that said, when a well is converted to service the normal practice of performing an MIT should be done. If that has not been performed, arrangements should be made with the Inspector to witness a MIT on the well. You have approval to keep the well in operation pending the arrival of the paperwork. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Just wanted to give you heads up on a situation with KRU Well 3K-12 (PTD# 1861650). This was an injection well that was approved for temporary production via Sundry #303-017. The well has been on production since January 2003. Just recently it was converted back to injection and operations inadvertently put on line prior to conversion sundry papers being approved. The paperwork is in the mail Will you please respond to this email as a "verbal approval" for the conversion to injection. We would like to leave the well on injection and not shut it in pending paperwork approval. Sorry for the confusion. Let me know if you have any questions. Thanks, Nina Woods Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 Tom Maunder <tom maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I of 1 5/27/2003 8:09 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION t. Type of request! A~hd~n_ Alter casing_ .. -.' 'R~pair:W~ll 2 ' ~ Plugging~ 2. Name of Operator I 5. Type of WeE """ Phillips Alaska, Inc. I Development__ 3. Address Explorato~_ P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service_X APPLICATION FOR SUNDRY APPROVALS 'S~d2 ' '~ '. 01~'~ai ~'_ Re.eht~r su~d~ v~ll _ Time extension _ stimulate_ -' 6. Datum elevation (DF or KB feet) 4. Location of well at surface 4167' FNL, 4962' FEL, Sec. 35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL,;$ec, ~, Ti:2N4B~,~U~' At effective depth (asp's 529306, 6008103) At total depth 1400' FNL, 4892' FEL, Sec. 1, T12N, R9E, UM (asp's 529911, 6005596) RKB 69 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-12 9. Permit number / approval number 186-165 10. APl number 50-029-21655 12. Present well condition summary Total depth: measured 7775 feet true vertical 6982 feet depth: measured :.~i~:,.,., ~ ;~ '~ ~: feet Effec~ve true vertical../' : Casing Length Size CONDUCTOR 110' 16" SUR. CASING 3909' 9-5/8" PROD. CASING 7685' 7" 11. Field / Pool Kuparuk Oil Pool Plugs (measured) ~" ' · Junk (measured) Cemented Measured Depth 110' 3978' ·Oth, er_X True vertical Depth 110' 7754' Perforation depth: measured !7,-4-7~2;~4~i-7506~75 ~3~.; ~!'~549;'7556~61 true vertical ~ ;(~1~;;67,~5~.;6789; 67~5; ~0~ Tubing (size, grade, and measured depth 2-7/8",6.5¢, J-55 ~ ~ 7417' MD. Packers & SSSV (type & measured depth) CAMCO 'HRP-I-SP' @ 7365' MD. CAMCO "I'RDP-1A-SSA' @ 1766' MD. 'RECEIVED 6as tons. toBfCss~o, Anchorage 14. Estimated date for commencing operation I 15. Status of well classification as: :t . 01/20/03 ;:16; ~f~tdp~sa! was verbally eJ[Sj3¥.oV~~ ' 1/i'6~0~3 ' ' I Oil _ Gas __ I 'Name of,approye;[ TdmMaUnder, ' ,Date apPrp~ed,, IService_X WINO 17. I hereby certify that the. forego~est of my knowledge. _ Signed J~~ - Title' Production Engineering Technician Robert D. Christensen FOR COMMISSION USE ONLY Suspended _ Questions? Call Jeff Spencer 659-7226 Date /~-~/~ ~ Prepared b~/ Robert CAristensen 659-7535 Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Location clearance _ L~ Mechanical Integrity Te~t__ Subse. quent forrn required lo- ORIGINAL SIGNED BY Approved by order of the Commission M L- Bill Commissioner Date SCANNED FEB RBDHS BFL , _ ,JAN 2_7 2003 Form 10-403 Rev 06/15/88 · ~ ' ' ; '~ . i SUBMIT IN TRIPLICATE 3K-12 DESCRIPTION SUMMARY PROPOSAL Phillipas ?l~ska Inq.i'~iSi':regu~fing apprOval for,a tempora~ conversion ofwell 3K- produced water:injectiOn ~to productiofi for C'FD drilling operat{ons. Due to high re§erv0i~r!iPte~sure (5294Psi), wel~ 3K-12 Will to check.iher~ae~oir(~m~u~r~lflhe pr~sure~isstill~high, the :well will continue ~o be ~n~ ' ....... STATE OF ALASKA ~:~- ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl. OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 41109' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL, Sec. 1, T12N, R9E, UM At effective depth At total depth 1399' FNL, 388' FWL, Sec. 1, T12N, R9E, UM 5. Type of Well: Development __ Exploratory_ Stratigraphic__ Service__X (asp's 529304, 6008103) (asp's 529813, 6005863) (asp's 529912, 6005597) 6. Datum elevation (DF or KB feet) RKB 69 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3K-12i 9. Permit number / approval number 186-165 10. APl number 50-029-21655 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 1 10' SURF CASING 3909' PROD CASING 7685' 7775 feet Plugs (measured) 6982 feet 7601 feet Junk (measured) 6838 feet Size Cemented 16" 1540# Poleset 9-5/8" 980 Sx AS IV & 320 Sx Class G 7" 300 Sx G & 175 Sx AS I Tagged Fill (1/27/00) @ 7601' MD. Measured Depth 110' 3978' 7754' True verticalDepth 110' 3887' 6965' Perforation depth: measured 7472 - 7489'; 7506 - 7536'; 7542'; 7549'; 7556 - 7561' true vertical 6732 - 6746'; 6760 - 6785'; 6790'; 6795'; 6801 - 6805' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55, Tbg @ 7417' MD. Packers & SSSV (type & measured depth) Camco 'HRP-1-SP' Packer @ 7365' MD. Camco 'TRDP-1A-SSA' @ 1766' MD. RECEIVED MAR 2 7 2001 Alaska 0il & Gas Cons. Comrnissior~ Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl - Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 600 650 Casing Pressure Tubing Pressure - 2900 29OO 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil ~ Gas __ Suspended Service __.(Water Inj)__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Form 10-404 Rev 06/15/88 · Title: Datt repare'~y~h n :eirce~265_ 6471 SUBMIT IN DUPLICATE 3K-12i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 1/27/00: RIH & tagged fill at 7601' MD. 1129100: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 7472 - 7489' MD 7506 - 7536' MD 7542' MD 7549' MD 7556 - 7561' MD Pumped 653 bbls in Stage #1: a) Slick Seawater @ 26 bpm & 8263 psi, followed by b) Gelled Scour w/2440 lbs of 20/40 mesh proppant, followed by c) Shutdown. ISIP @ 3470. Pumped 880 bbls in Stage #2: d) Gelled Diesel w/2000 lbs Rock Salt Diverter, followed by e) Gelled Scour w/4000 lbs of 20/40 mesh proppant @ 23 bpm & 8300 psi, followed by f) Shutdown. ISIP @ 3290. Pumped 907 bbls in Stage #3: g) Gelled Diesel w/2000 lbs Rock Salt Diverter @ 18 bpm & 6500 psi, followed by h) Gelled Scour w/4176 lbs of 20/40 mesh proppant @ 23 bpm & 7440 psi, followed by i) Shutdown. Returned the well to water injection & obtained a valid injection rate. STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMI~ REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Sewice 1109' FSL, 316' FWL, $EC.35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL, SEC.1, T12N, R9E, UM At effective depth 1344' FNL, 368' FWL, SEC.1, T12N, R9E, UM At total depth 1399' FNL~ 388' FWL~ SEC.I~ T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7 7 7 0' true vertical 6 9 7 7' feet Plugs (measured) feet m Other 6. Datum elevation (DF or KB) RKB 69' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3K-12 9. Permit number/approval number 86-165 ! 9-006 10. APl number 50-029-2165500 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7667' feet Junk (measured) 6892' feet 13. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 1 6" 3941 ' 9-5/8" 7720' 7" Cemented Measured depth True vertical depth 1540# POLESET 110' 110' 980 SX AS IV & 3 9 7 8' 3 8 8 7' 320 SX CLASS G 300 SX CLASS G & 7 7 5 4' 6 9 6 4' 175 SX AS I measured 7479', 7482', 7484', 7486', 7506', 7512', 7528', 7535', 7542', 7549', 7556'-7561' true vertical 6737', 6740', 6742', 6744', 6760', 6765', 6778', 6783', 6789', 6795', 6801'-6805' Tubing (size, grade, and measured depth) 2-7/8 J-55 TBG w/TAIL @ 7407' Packers and SSSV (type and measured depth) HRP PKR @ 7380'/CAMCO TRDP-1A-SSA SSSV ~ 1796' Stimulation or cement squeeze summary 7520, 6771 ', ntervals treated (measured) SEE A'I-rACI-IED PRESSURE COMMUNICATION HISTORY LOG. A WORKOVER WAS PERFORMED ON 3K-12 IN 10/91 - APPROVAL NO. 261 Treatment description including volumes used and final pressurel 14. Reoresentative Daily Avera0e Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 653 820 1488 Subsequent to operation 0 0 1150 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector _X Daily Report of Well Operations m Oil Gas Suspended ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 900 Service 2762 Si~ned ~'~, ~ '' ~ Form 10-404 Rev 09/12/90 Title Petroleum Encjineer SUBMIT IN DUPLICATE 4/88 5/88 5/20/88 5/24/88 Tbg. Pressure Csg. Pressure Start 3025 620 1.5 Hours 3025 620 Test results confirm leak in packer assembly. Start injecting at 2650 psi (header max.) again. Communication appears to have stopped. Injection rate increased from 800 to 2000 BWPD. Communication becomes apparent again. Reduce injection pressure. Eventually decided on a limit of 1650 psi. RIH set SV in D Nipple and pressure test: Tbg. Pressure Start 3500 10 min. 3350 Csg. Pressure 2640 2675 Start 4100 2 min. 4025 27O0 2725 Start 2875 15 min. 2850 1600 1650 Overall tests results imply no communication exists above the D Nipple. (Note the short test duration.) tubing Integrity, Lost in hole one Otis 'G' type packoff element. RIH set BP in collar above bottom GLM, pressure test: Tbg. Pressure Csg. Pressure Start 3530 2070 40 min. 3250 2070 Test results appear suspicious. Reset BP, pressure test: Tbg. Pressure Csg. Pressure Start 3250 1 500 20 min. 3240 1530 30 min. 3230 1540 45 min. 3230 1545 No obvious pressure communication seen. Bled 7" annulus, pressure test: Tbg. Pressure Csg. Pressure Start 31 70 1000 25 min. 31 50 1040 40 min. 3145 1040 Results and conclusions same as above. JOG 1/22/91 Tbg. Pressure Csg. Pressure Start 3025 620 1.5 Hours 3025 620 4/88 Test results confirm leak in packer assembly. Start injecting at 2650 psi (header max.) again. Communication appears to have stopped. Injection rate increased from 800 to 2000 BWPD. 5/88 Communication becomes apparent again. Reduce injection pressure. Eventually decided on a limit of 1650 psi. 5/2 0/8 8 RIH set SV in D Nipple and pressure test: Tbg. Pressure Csg. Pressure Start 3500 2640 10 min. 3350 2675 Start 4100 2700 2 min. 4025 2725 Start 2875 1600 15 min. 2850 1650 Overall tests results imply no communication exists above the D Nipple. (Note the short test duration.) Lost in hole one Otis 'G' type packoff element. tubing integrity, 5/24/88 RIH set BP in collar above bottom GLM, pressure test: Tbg. Pressure Csg. Pressure Start 3530 2070 40 min. 3250 '. 2070 Test results appear suspicious. Reset BP, pressure test: Tbg. Pressure Csg. Pressure Start 3250 1500 20 min. 3240 1530 30 min. 3230 1540 45 min. 3230 1545 No obvious pressure communication seen. Bled 7" annulus, pressure test: Tbg. Pressure Csg. Pressure Start 31 70 1 000 25 min. 31 50 1040 40 min. 31 45 1040 Results and conclusions same as above. JO3 1/22/91 12/26/88 1/89 1/89 2/5/89 2/1 1/89 4/89 6/20/89 Pull up hole and set BP in collar above next GLM, pressure test: Tbg. Pressure Csg. Pressure Start 2970 1075 25 min. 2890 1075 BP probably not set good since 7" annulus pressure did not change. Pulled DV #3 - looked OK - redressed and reran. Pulled bottom DV- looked OK - redressed and reran (second redressing of bottom DV.) RIH set BP in D Nipple. Pressure tested: Increased tubing pressure to 2600 psi, decreased pressure in the 7" annulus to 650 psi. Let sit overnight. Pressures did not change. Test results imply tubing integrity, communication must be a packer leak. Leave 7" annulus pressure at 650 psi, bleed tubing pressure to 200 psi. Let sit overnight. Pressures equalized at 620 psi. Test results imply one way leak from 7" annulus to tubing. Leave tubing pressure at 620 psi, pressure 7" annulus to 2600 psi. Let sit overnight. Pressures equalized at 2250 psi. Test results confirm one way leak from 7" annulus to tubing. Leave tubing pressure at 2250 psi, bleed off 7" annulus. Could only bleed to 400 psi. Test results imply tubing to 7" communication. Received permission from the state to continue operating performing additional diagnostic work. RIH pull~ BP. Ran Amerada bombs - BHP=3700 psi ~ 7740 Pressure tested tree. kl~s~ Gradually increase injection pressure to 2100 psi. Rate increases from 600 to 800 BWPD, 7" pressure increases to 2600 psi. Well failed an internal MIT. Increased tubing pressure to 2400 psi. Observed a 40 psi drop in tubing pressure after 30 min. Decreased pressure in 7" annulus to 1400 psi JCG 1/22/91 12/13/90 1/21/91 and increased tubing pressure to 2500 psi. Observed 240 psi increase in 7" annulus pressure after 30 min. Pressure tested tubing hanger to 5000 psi. Problem must be downhole. RIH set SV in SBR and pressure tested: Tbg. Pressure Csg. Pressure Start 31 70 1 300 5 min. 3080 1 300 10 min. 3020 1310 15 min. 2970 1320 20 min. 2920 1330 Teat reaulta Imply no tubing Integrity, communication exiats above the SBR. 1/22/91 STATE Of ALASKA ALA~, ~A OIL AND GAS CONSERVATION COMMlu..,iON · REPORT OF SUNDRY WELL OPERATIONS i'i 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate ~ Plugging Perforate X Repair well 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 4. Location of well at surface 1109' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL, Sec. 1, T12N, R9E, UM At effective depth 1344' FNL, 368' FWL, Sec. 1, T12N, R9E, UM At total depth 1399' FNL, 388' FWL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7 7 7 0' true vertical 6977' 6. Datum elevation (DF or KB) 69' RKB, PAD 35' 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-12 .,.-- ..... 9. Permit number/approval number 86-1 65/#261 10. APl number ~;0-0:89-21655 11. Field/Pool Kuparuk River Oil Pool feet feet Plugs (measured) None feet Effective depth: measured 7667' feet true vertical 6892' feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 8 0' 1 6" 1540# POLESET 1 1 0' 1 1 0' 3941' 9-5/8" 980sxASIV& 3978' 3887' 320 sx Class G 801 3' 7" 300SxClassG& 7754' 6964' 175 Sx AS I measured 7479', 7482', 7484', 7486', 7506', 7512', 7520', 7528', 7535', 7542', 7549, 7556'- 7561' true vertical 6737', 6740', 6742', 6744', 6760', 6765', 6771', 6778', 6783', 6789', 6795', 6801'- 6805' Tubing (size, grade, and measured depth) 2 7/8" J-55, tbg w/tail @ 7407' Packers and SSSV (type and measured depth) HRP pkr @ 7380' & TRDP-1A-SSA SSSV @ 1796' 13. Stimulation or cement squeeze summary Re-perforation of A2 & A3 Sands @ 4 SPF Intervals treated (measured) 7472' - 7489', 7506' 7536' (md) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Oomm[ssio~ Anch0ra.q~ 14. Prior to well operation Subse~iuent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure - 0- -0- 850 1300 -0 -0- 1050 1300 TubingPressure 2800 2800 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Water Injector X~ Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C,~' ~(~ ~~i~/ Title EJ/13 ,~ ¢~ f~ Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE I SCA# t FIELD COST E.g..ST. T~ I LOG ~Y .///o AR..O Alaska. Inc. ~ KUPARUK RIVER UNIT Subsidiary of Atlantic Richfield Com0any WELL SERVICE REPORT WELL IPBDT j , COI~TRA~CTOR/KEY PERSON ,DAYS I D~_ T~..~. /~:Q-/,~P i ~IL~,~ , [ DESk. ION OF WORK .~/CC~ ACCUM ULAT~ COST PAGE 1 OF Alaska 0il & [.~ao I;ons, Co,,,::: ....... , ( r'-I CHECK THIS BLOCK [lr SUMMARY CONTINUED ON BACK } [~ COMPI~TE [~] INCOMPLETE STATE OF ALASKA CONSERVATION COMMISSION 0 R I G I N ~~_.. ALASKA OIL AND REPORT OF SUNDRY WELL OPERATIONS _ 1. Operations performed: Operation Shutdown Stimulate __ Pull tubing X Alter casing Repair well 2. Name of Operator 5. Type of Well: Development "X' ARCO Alaska. Inc. Exploratory _ 3. Address Stratigraphic _ Plugging Perforate Other 6. Datum elevation (DF or KB) 69' RKB. PAD 35' 7. Unit or Property name feet P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 1109' FSL, 316' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL, Sec. 1, T12N, R9E, UM At effective depth 1344' FNL, 368' FWL, Sec. 1, T12N, R9E, UM At total depth 1399' FNL, 388' FWL, Sec. 1, T12N, R9E, UM 12. Present well condition summary Total Depth' measured 7770' feet true vertical 6977' feet Plugs (measured) Kuparuk River Unit 8. Well number 3K-12 9. Permit number/approval number 86-1 65/#261 10. APl number 50-029-21655 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7667' feet true vertical 6892' feet Junk (measured) Casing Length Size Structural 8 0' 1 6" Conductor Surface 3941 ' 9-5/8" Intermediate Production 801 3' 7" Liner Perforation depth: measured 7479'-7561' true vertical Cemented 1540# POLESET 980sxAS IV & 320 sx Class G 300 sx Class G & 175 sx AS I Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55 tbg W/ tail @ 7406' Packers and SSSV (type and measured depth) Camco "HR-1-SP" Pkr @ 7380', Camco "TRDP-1A" SSSV @ 1796' 13. Stimulation or cement squeeze summary Measured depth True vertical depth 11 0'md 11 0'tvd 3978'md 3887'tvd 7754'md 6964'tvd RECEIVED OCT 2 5 ,991' A~aska 0ii & 6as Cons. Anchora[~e Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drilling Engineer Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIONS PAGE: 1 WELL: 3K-12 BOROUGH: NORTH SLOPE UNIT: KUPARUK RIVER UNIT FIELD: KUPARUK RIVER FIELD LEASE: ADL 25649 ALK 2562 API: 50-029-21655 PERMIT 86-165 APPROVAL: Conservation Order #261 ACCEPT: 08/20/91 08:00 RELEASE: 08/24/91 06:00 OPERATION: WORKOVER RIG: NORDIC 1 AFE: AK5857 WI: 55.347699 08/21/91 (1) TD: 0 PB: 7667 SUPV:DB/DS 08/22/91 (2) TD: 0 PB: 7667 SUPV:GB/CD 08/23/91 (3) TD: 0 PB: 7667 SUPV:GB/CD KILL WELL MW:ll.3 THXL CONT MOVE RIG FROM 3A PAD TO 3K-12,ACCEPT RIG AT 0800 HRS,MU CHOKE/KILL LINES, PULL BPV, RU OTIS SLICKLINE, PRESS TEST LUB TO 2000 PSI,RIH PULL PRONG F/BLNKING PLUG, POH, RIH PULL BLANKING PLUG FROM D NIPPLE @ 7396' WLM, RIH W/OM-1 KICKOVER TOOL, LATCH 1 1/2" CV R/GLM @ 7316' WLM, POH, RD OTIS SLICKLINE RU CIRC HEAD, SITP =1320 PSI,SICP=1250 PSI,CIRC 50 BBLS FRESH H20 DN TBG UP ANN.,SHUT IN CHOKE & BULLHEAD 12 BBLS H20 INTO PERFS, SHUT IN AND MONITOR PRESS, SITP=930 PSI,SICP= 930 PSI DISPLACE ANN W/240 BBLS FRESH H20 AT 3 BPM/1200 PSI,SHUT IN AND WATCH PRESS,SITP=900 PSI,SICP=850 PSI,CONDITION THIXSAL IN PITS,ADD THIXSAL AND XCD POLYMER TO BRINE, DECREASE WEIGHT TO 11.3+ PPG F/12.3 PPG, KILL WELL BY PUMPING DN TBG THRU OPEN GLM UP ANN, SHUT IN WELL, SITP=0,SICP=0,NO FLOW DAILY:S97,069 CUM:$97,069 ETD:S97,069 EFC:$364,000 PU/TIH WITH 3 1/2" DP MW:ll.3 THXL SET BPV,ND TREE,NU BOPE, TEST TO 3000 PSI,WITNESSED BY H. HAWKINS AOGCC, PULL TBG HGR TO RIG FLOOR, LD SAME,MONITOR WELL OK, POH W/2 7/8" COMPLETION, CHANGE SEAL RINGS,DRIFT, STRAP SAME,RECOVERED 30 SS C-LINE BANDS,BREAK DN CAMCO OEJ, REMOVE SEAL, CHANGE PIPE RAMS TO 3 1/2",PU CAMCO PACKER PLUCKER AND 3 1/2" DP, SET WEAR RING, RIH W/BHA WHILE PICKING UP DP DAILY:S28,147 CUM:$125,216 ETD:S125,216 EFC:$364,000 POH/LD 3 1/2" DP MW:ll.3 THXL SERVICE RIG, BREAK CIRC, TAG PACKER @ 7365' DPM, LATCH PACKER PU SHEAR PACKER FREE @ 60K# PULL, CBU, POH W/PACKER, LD PACKER AND TAILPIPE,MU 6 1/8" BIT ON DP, TIH, PU KELLY @ 7400',WASH DN, TAG FILL @ 7497',REAM F/7497'-7664',REV CIRC HOLE CLEAN FORMATION SAND IN RETURNS,BLOW DN KELLY, POH, LD DP,PREP. TO RUN COMP. DAILY:S35,839 CUM:$161,055 ETD:S161,055 EFC:$364,000 08/24/91 ( 4) RIG RELEASED @ 0600 HRS MW:ll.3 THXL TD: 0 CONT POH LD 3 1/2" DP,PULL WEAR RING, CHANGE RAMS TO 2 7/8" PB: 7667 PU TAIL PIPE AND MU CAMCO 7 X 2 7/8" HRP PACKER & OEJ, RUN IN SUPV:GB/CD HOLE W/2 7/8" COMPLETION, MU CAMCO 2 7/8" SSSV, TEST C LINE TO 5000 PSI F/15 MIN, CONT RIH W/COMPLETION, MU CIW 3 1/2" TBG HGR, MU C LINE TO HGR AND TEST TO 5000 PSI,LAND TBG, PRESS TBG TO 3000 PSI TO SET PACKER, TEST TBG TO 3000 PSI F/30 MIN, PU SHEAR OEJ @ 37K OVER STRING WT.,RELAND TBG, TEST ANNULUS TO RECE~V 2500 PSI F/30 MIN, CLOSE SSSV, BLEED TBG TO 1000 PSI,TEST SSSV F/15 MIN, OPEN SSSV, BLEED OFF TBG AND ANNULUS PRESS,SET BPV ND BOPE,NU CIW 3 1/8" 5K TREE, SET TEST PLUG, TEST TREE TO 007 § 5000 PSI,TEST TBS HGR/PACKOFF TO 5000 PSI,PRESS UP TO 4500 PSI ON TBG TO SHEAR OUT BALL, BALL DID NOT SHEAR, DISPLACE Alaska Oil .& Gas Gons. Comm%s~N ANNULUS W/70 BSA SEAWATER FOLLOWED BY 270 BBLS DIESEL, THRU 3/4" CV AT 7294',CV PLUGGED OFF W/THIXSAL, SURGE AND ~Ch0~ CONT TO CIRC AT 5-60 SPM/2700 PSI,SHUT IN WELL, SITP=1000 PSI TEST CV, CV WOULD NOT HOLD, RD LINES, SECURE WELL,CLEAN PITS MOVE RIG, RIG RELEASED AT 0600 HRS. DAILY:S68,210 CUM:$229,265 ETD:S229,265 EFC:$364,000 DR CLLING a. MEMORANDUM St , e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Sm~_~ DATE:October 1, 1991 Commis s ione~"-'"' i~> FILE NO: HH101 - 3. DOC THRU: TELEPHONE NO: SUBJECT:BOP Test AAI KRU DS 3K-12 Permit 86-165 Kuparuk Rv Field FROM: Harold R Hawkins Petr Inspector ~ednesdav, Auaust 21., 1991 I witnessed a BOP test for AAI KRU 3K-12. There were no failures. I filled out an AOGCC field report which is attached. In summary, the BOP test for AAI KRU DS 3K-12 on Nordic Rig 1 was satisfactorily performed. Attachment 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 OPERATION: Drlg Operator /Z~//~/ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOP Test Report Wkvr/ Location: Sec 3~- T/~/' Drlg contrctr Location (general) Housekeeping (general) Reserve pit R.,.? ~ UM Rig#, Well sign Rig ! MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Audio BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve DATE TEST: Initial J Weekly.~ Other Representative //~ Z~/b/_ Permit # ~/ Casing set @ ,~y ft ACCUMULATOR SYSTEM: Full charge pressure Press after closure psig psig sec sec Pump incr clos press 200 psig Full charge press attained Controls: Master Remote KELLY AND FLOOR SAFETY VALVES: Upper Kelly Test pressure ~F~//~/~ Test pressure Test pressure Test pressure Test pressure Test Pressure Lower Kelly ~~ Ball type .... ~ ~::~ Inside BOP ~~ Choke manifold ,~ ~:~ Number valves ~~ Number flanges ~~ Adjustable chokes .~, ~ ~ Hydraulically operated choke / TEST RESULTS: Failures ~-_~-~' Test time ~ '*~J~- hfs Repair or replacement of failed equipment to be made within ------days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 07/08/91) Ab' ,A OILAND GAS CONSERVATION COMMI.. ,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing _ Change approved program_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Suspend _ Operation Shutdown _ Re-enter suspended well_ Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance ~ Perforate _ Other 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 1109' FSL, 316' FWL, SEC. 35, T13N, R9E, UM At top of productive interval 1133' FNL, 291' FWL, SEC. 1, T12N, R9E, UM At effective depth 1344' FNL, 368' FWL, SEC. 1, T12N, R9E, UM At total depth 1399' FNL, 388' FWL, SEC. 1, T12N, R9E, UM 7770" feet Plugs (measured) 6977" feet None 7667' feet Junk (measured) 6892' feet None 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 6. Datum elevation (DF or KB) RKB 7. Unit or Property name Kuparuk River Unit 8. Well number :~K-12 feet , Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 9. Permit number 86-165 10. APl number 50-029-21 655 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Length Size Cemented Measured depth 80' 16" 1540 #Poleset 110'MD 3941' 9 5/8" 980SXASIV& 3978'MD 320 SX CLASS G 7 7 2 0' 7" 300 SX Class G & 7 7 5 4' 175 Sx AS I True vertical depth 110°TVD 3887'TVD' 6964'TVD Alaska 0il & Gas Cons, C0m! '' ~ch0rage":" measured 7479', 7482', 7484', 7486', 7506', 7512', 7520' MD 7528', 7535', 7542', 7549', 7556' - 7561' MD true vertical 6737', 6740', 6742', 6744', 6760', 6765', 6771' TVD 6778', 6783', 6789', 6795', 6801 -6805' TVD Tubing (size, grade, and measured depth 2 7/8" J-55, tbg w/tail @ 7407' Packers and SSSV (type and measured depth) HRP pkr @ 7380' & TRDP-1A-SSA SSSV @ 1796' Description summary of proposal X Detailed operation program BOP sketch -- 13. Attachments 14. Estimated date for commencing operation ASAP 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil Gas Suspended Service Water Injector Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ,,~_.,~.2 jl~ /~.,~e- ~~ Title FOR COMMISSION USE ONLY ~" Conditions of approval' Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 0R!G!NAL SIGNED BY LONNIE C, SMITH Commissioner JApproval Nc~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 APproved Copy Returned SUBMIT IN TRIPLICATE Kuparuk River Unit Well 3K-12 Well 3K-12 is a water injection well. It has a single completion (see attached diagram) and is injecting into the A Sand. Recently, high pressures (2000 psi) have been seen in the 7 inch casing, indicating pressure communication between it and the tubing. ARCO Alaska, Inc. requests permission to continue injection at a reduced injection pressure while diagnostic work is underway to locate and fix the leak. Gas Cons. Comrnis~.;~. [t~.nchora§e WELL: 3K-12 API #: 500292165500 ADL LEASE: 25629 PERMIT #: 86-165 SPUD DATE: 11/05/86 COMPLETION DATE: 02/21/87 SURFACE LOCATION: 1109'FSL,316'FWL,SEC35,T13N,R9E TOP OF KUPARUK: 1133'FNL,291'FWL,SEC1,T12N,R9E TD LOCATION: 1399'FNL,388'FWL,SEC1,T12N,R9E ORIGINAL RIG RKB: 69 MSL PAD: 35 MSL REVISION DATE:01/07/87 TUBING SPOOL: 35 MSL 16" 62.5# H-40 Ca 110 SSSV' CAMCO TRDP-1A-SSA 2.312" ID Ca 1796 9.625" 36# J-55 Ca 3978 SBR. CAMCO OEJ ID Ca 7363 PKR: CAMCO HRP-1-SP NOGO: CAMCO 'D' NIPPLE 2.25" ID Ca 7396 SHEAR OUT: CAMCO 7" 26# J-55 Ca 7754 Ca 7380 Ca 7406 / XXXl xxxl I I I- IIIIIIIII I!1111111 I I_ GLM1 Ca 2581 / 1.0" GLM2 ca 4371 / 1.0" GLM3 ca 5413 / 1.0" GLM4 Ca 6095 / 1.0" GLM5 Ca 6492 / 1.0" GLM6 Ca 6920 / 1.0" GLM7 ca 7316 / 1.5" 2.875 6.5# J-55 ABMOD TUBING TAIL ca 7407 Al 7479 Al 7482 Al 7484 · 7486 il 7506 Al 7512 Al 7520 Al 7528 A I 7535 Al 7542 Al 7549 zJ 7556 - 7561 1 SPF I SPF 1 SPF i SPF I SPF I SPF i SPF 1 SPF 1 SPF i SPF I SPF 1 SPF PBTD 7667 , PBTDSS 6823 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN,,dSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing Alter Casing [] Other ~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc RKB 69' Feet 3. Address PO Box 100360, Anchorage. AK 99510 4. Location of well at surface 1109' FSL, 316' FNL, Sec.35, T13N, RgE, UM At top of productive interval 1133' FNL, 291' FWL, Sec. 1, T12N, RgE, UN At effective depth 1344' FNL, 368' FWL, Sec. 1, T12N, RgE, UM ~ , 388' FWL, Sec. 1, T12N, R9E, UM 6. Unit or Property name Kuparuk River Unit 7. Well number 3K-12 /Al ~ c ~' 8. Approval number #7-613 9. APl number 50-- 029-21655 10. Pool Kuparuk River 0il Pool 11. Present well condition summary.,_ Total depth: measured //70' MD feet - ..... true vertical 6977' TVD feet Plugs (measured~lOne -. measured 7667' MD feet true vertical6892' TVD feet Effective depth: Junk (measured) None Cemented Measured depth True Vertical depth 1540# Poleset 110' MD 980 SX ASIV 3978' MD & 320 SX Class G 300 SX Class G 7754' MD & 175 SX ASI 110' TVD 3887' TVD 6964' TVD measured 7479' 7482' 7484' 7486' 7506' 7512' 7520' MD 7528' 7535' 7542' 7549' 7556'-7561' MB true vertical6737, 6740' 6742' 6744' 6760' 6765' 6771' 6778' 6783' 6789' 6795' 6801'-6805' IYD Casing Length Size Structural Conductor 80' 16" Surface 3941' 9-5/8" Production 7720 ' 7" xxxxbkrX~xxxx Perforation depth: Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/Tail @ 7407' Packers and_S_S_SY.(bzpe and measured depth) HRP pkr ~ 7380' ~ TRDP-1A-SSA SSSV (a 1796' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) 13. JUN 2 2 I988 Alaska 0il & Gas Cons. Commission Anchorage Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 602 BOPD 915 MCFPD 0 BWPD 0 BOPD 0 MCFPD 2276 BWPD Prior to well operation Subsequent to operation Casing Pressure 1050 ps i g 1400 psig Tubing Pressure 110 psig 1900 psig Copies of Logs and Surveys Run ~ 14. Attachments Daily Report of Well Operations 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Sr. Operations Engineer Form 10-404 Rev. 12_/1-85 Date~ Submit in Duplicate~ .rICO Alaska, Inc. Subsidiary of Atlantic Richfield Company CC ~,CTOR REMARKS WELL SERVICE REPORT IFIELD- DISTRICT- STATE OPERATION AT REPORT TIME CO M F_~ Cc~r' 3~Z.Ct ~ c:>~_~O -- PC,O, bO(oN. ~OV~ TO 5~-~ JUN 2 2 1988' Alaska, Oil & Gas Cons. Commission Anchorage {'-') CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company IFIELD - DISTRICT- STATE .... OPERATION AT REPORT TIME WELL SERVICE REPORT WELL l PB DT NTRACTOR REMARKS JUr~ ...... WIIIIIII~NI I Nasd 0ti & Gas Cor~s." ' '.~_n. charage r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Report Tamp. aF Chill Factor 1 Visibility milesI Wind Vel. knota t Signed STATE OF ALASKA ALA~,,A OIL AND GAS CONSERVATION CON .... fSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage? AK 4. Location of well at surface 99510-036O 109 ' FSL,. 3.16' FWL. Sec 35 T13N R9E UM t top oTproaucuve interval ' ' ' ' 1133' FNL, 291' FWL, Sec. 1, T12N, RgE, UM At effective depth 1344' FNL, 368' FWL, Sec. 1, T12N, RgE, UM At total depth 1399' FNL, 388' FWL, Sec, 1, T12N: R9E: UM 11. Present well condition summary Total depth: measured 7770' MD feet true vertical6977, MD feet Effective depth: measured 7667' MD feet true vertica%~c~_, feet Casing Length Size Structural 80 ' 16" Conductor Surface 3941' 9-5/8" xxx~x0o~li~te Production xxx~t~xxxx Perforation depth: 5. Datum elevation (DF or KB) RKB 69 feet 6. Unit or Property name Kunaruk River Unit 7. Well number 3K-12 8. Permit number Permit #86-165 9. APl number 50-- 029-21655 10. Pool Plugs (measured) None KuDaruk Rivmr Oil Pnnl Junk (measured) None Cemented Measured depthjk~B$~8' 0~ 1540# Poleset 110' MD 980 SX ASIV & 3978' MD 320 SX Class G 7720' 7" 300 SX Class G & 7754' MD & 175 SX ASI measured 7479', 7482', 7484', 7486', 7506', 7512', 7520' MD 7528', 7535', 7542', 7549', 7556'-7561' MD truevertica16737,' 6740', 6742', 6744', 6760', 6765', 6771' TVD 6778', 6783', 6789', 6795', 6801-6805' TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7407' Packers and SSSV (type and measured depth) HRP pkr fa 73~f)' ~ TRflP-]A-SSA SSSV @ !796' 12.Attachments Description summary of proposal Convert well from oil producer to water injector 13. Estimated date for commencing operation October 1, 1987 ~__~ 14. If proposal was verbally approved Form No. Dated Name of approver depth 110' 3887' 6964' TVD TVD TVD Detailed operations program L-] BOP sketch [] Date approved 15. I hereby certify that the ~oregoing is true an~ correct to the best of my knowledge Signed./~] ~,;.,.,~ /~ ~/~'/,t~"l~.~.~.c/u'T'g'/ Title Sr. 0p er at ions Engineer ~' Commission Use Only Dat¢/16/87 Conditions of approval Approved by Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I Form 10-403 Rev 12-1-85 by order of the commission Date Submit in triplicate STATE OF ALASKA ; ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~j~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-165 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21655 4. Location of well at surface 9. Unit or Lease Name 1109' FSL, 316' FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1133' FNL, 291' FWL, Sec. 1, T12N, RgE, UM 3K-12 At Total Depth 11. Field and Pool 1399' FNL, 388' FWL, Sec. 1, T12N, R9E, UN Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk Ri vet 0i 1 Pool RKB 69' ADL 25629 ALK 2562 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 11/05/86 11/10/86 02/21/87'I N/A feetMSLI 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7770'MD 6977'TVD 7667'MD 6892'TVD YES ~1 NO [] 1796 feet MDI 1700' (Approx) 22. Tvpe Electric or Other Logs Run DIL/SP/SFL/GR, FDC/CNL, Cal, CBL/GR/CCL, Gyro, CCL/Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 110' 20" 1540# Pol eset 9-5/8" 36,0# J-55 Surf 3978' 12-1/4" 980 sx AS IV & 320 sx ~la~ G 7" 26.0# J-55 Surf 7754' 8-1/2" 300 sx Class G & 175 $ AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7479'MD 6738'TVD 7528 'MD 6778'TVD 2-7/8" 7407' 7380' 7482'MD 6740'TVD 7535'MD 6784'TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7484 'MD 6742'TVD 7542 'MD 6789'TVD DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7486 'MD 6743'TVD 7549'MD 6795'TVD See attached AddenJum, dated 03/24/87. for 7506'MD 6760'TVD 7556'-7561 'MD 6801 '-6805 'TVD 751 2'MD 6765 'TVD 7520'MD,. 6771'TVD Perforated w/1 spf ,. 27. N/A PRODUCTION TEST Date F. irst Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAs-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATEDi~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ '28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None *NOTE: Drilled RR 11/12/86. Tubing run 12/05/86. Perforated well 01/14/87. Form 10-407 WC2:34:DANI Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7270' 6565' N/A Base Kupaurk C 7334' 6618' Top Kuparuk A 7447' 6711' Base Kuparuk A 7601' 6838' 31. LIST OF ATTACHMENTS ........ Addendum, (dated 03/24/87). 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .. , ~)~U~(~./ '~ Title Associate Engineer- Date ... z~-~-C'/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement. lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 11/21/86 2/21/87 2/21/87 3K-12 Arctic Pak w/29 bbls AS I, followed by 54 bbls Arctic Pak; tst OK. Data frac well. Displ tbg w/45 bbls diesel. RU WL & HP pressure monitor. RIH, set pressure recorder @ 7450'. RU Dowell, tst lns to 8000 psi. Pmp 44 bbls diesel w/l% Musol @ 2.6 BPM, 3130 psi 45 bbls gelled diesel w/no FLA @ 5.1BPM, 3550 psi. Shut dn & allow Musol to soak across perfs. Pmp 100 bbls gelled diesel (no FLA) @ 20 BPM, 4850 psi. Shut dn. ISIP = 2495 psi. Press stabilized @ 2025 psi. Step rate tst w/gel diesel (no FLA). Pmp 1-1/4 bbls @ .25 BPM, 2435 psi. Pmp 2.5 bbls gel diesel @ .5 BPM, 2680 psi. Pmp 3.75 bbls gel diesel @ .75 BPM, 2890 psi. Pmp 5 bbls gel diesel @ 1BPM, 3014 psi. Pmp 7.5 bbls gel diesel @ 1.5 BPM, 3185 psi. Pmp 10 bbls gel diesel @ 2 BPM, 3170 psi. Pmp 20 bbls gel diesel @ 4 BPM, 3300 psi. Pmp 18 bbls gel diesel @ 6 BPM, 3520 psi. Shut dn. ISIP = 2477 psi. Press stabilized @ 1842 psi. Pmp 50 bbls gel diesel @ 20 BPM, 4780 psi. Shut dn, flow back f/5 min @ 1BPM. Press stabilized @ i866 psi. Pmp 50 bbls gel diesel w/FLA 20#/1000 gal silica flour @ 20 BPM, 4800 psi. Shut dn. ISIP = 2587 psi. Flow back @ 1BPM f/5 min. Press stabilized @ 2050 psi. Pmp 400 bbls gel diesel w/FLA (20#/1000 gal silica flour) @ 20 BPM, 4800 psi. Shut dn. ISIP = 2489 psi. SIP = 2312 psi - 10 min = 2208 psi - 15 min = 2166 psi - 30 min = 2031 psi. POOH w/WL. Gel up f/sand frac. Total load to recover = 758 bbls gel diesel & diesel. Frac Kuparuk "A" sand perfs 7479', 7482', 7484', 7486', 7506', 7512', 7520', 7528', 7535', 7542', 7549' & 7556' thru 7561' per procedure dated 1/19/87 as follows: Stage 1: 50 bbls gel diesel @ 20 BPM, 4656-4670 psi Stage 2: 47 bbls gel diesel w/1 ppg 100 mesh @ 20 BPM, 4670-4595 psi Stage 3: 360 bbls gel diesel @ 20 BPM, 4595-4650 psi Stage 4: 33 bbls gel diesel w/2 ppg 20/40 mesh @ 20 BPM, 4650-4550 psi Stage 5: 34 bbls gel diesel w/3 ppg 20/40 mesh @ 20 BPM, 4550-4620 psi Stage 6: 35 bbls gel diesel w/4 ppg 20/40 mesh @ 20 BPM, 4620-4644 psi ADDENDUM WELL: 3K-12 (cont'd) 2/22/87 Stage 7: 37 bbls gel diesel w/5 ppg 20/40 mesh @ 20 BPM, 4644-4650 psi Stage 8: 38 bbls gel diesel w/6 ppg 20/40 mesh @ 15-20 BPM, 4650-3936 psi (started losing primer during Stage 8, dropped rate to 15 BPM) Stage 9: 20 bbls gel diesel w/7 ppg 20/40 mesh @ 15 BPM, 3936-3954 psi Stage 10:20 bbls gel diesel w/8 ppg 20/40 mesh @ 15 BPM, 3954-3900 psi Stage 11:44 bbls gel diesel flush @ 12-15 BPM, 3900-4200 psi (Note: Unable to maintain 20 BPM rate after Stage 7 & unable to maintain 15 BPM on flush) Fluid to Recover: Sand in Casing: Sand in Zone: Average Press: 686 gel diesel 1116 lbs 1900 lbs 100 mesh & 31,184 lbs 20/40 mesh 4650 psi RU WL, tst lubr to 1500 psi. GIH w/CCL/Temp tl, tag SSSV @ 1796'; vlv closed. Pmp dn tbg, SSSV opened. RIH, tag fill @ 7528' (btm perf @ 7561'). Rn CCL/Temp log f/7528'-7000'. POOH, RD Otis. Turn well over to Production. Bate ' CHRI!! T N KUPARUK OPerATIONS ENG~t'JEER~NG REPORT of SUB-SURFACE DIRECTIONAL SURVEY ARCO ALASKA, Inc. Pad 3K, Well Number: 9/9A Kuparuk' Field, North Slope, Alaska JOB NUHBER 450-190 Survey By R BARNARD TYPE OF SURVEY GO Mwd R~C~I¥~D JUN 2 2 1994 A,i~ska u~t & Gas Cons. Commission Anchorage DATE 01-OCT-86 Office Anchorage, Alaska fJ lERSTMRN CHRISTENSEN P. O. Box 91970, Anchorage, Alaska 99509-1970, Phone: (907) 563-3650 Date: December 3, 1986 ARCO ALASKA, INC. P.O. BOX 1479 Anchorage, Alaska 99510 Well Number: Pad 3K, Well No: 9/9A Location: Kuparuk Field, North Slope, Alaska Type of S%~rvey: GO Mwd Date: 01-0CT-86 Method of Computation: Radius of Curvature Surveyor/Driller: R BARNARD Job Number: 450-190 Attn: Mr. R. A. Ruedrich Dear Mr. Ruedrich: We are enclosing the original and one (1) copy of the sur- vey run on the above mentioned well. To date, the following distributions have been accom- plished: A. 1 Copy delivered to drilling in-house distribution. B. 6 Copies noted for oil company representatives. C. 3 Copies for E/C permanent well files. We wish to take this opportunity to thank you for using Eastman Christensen and look forward to being of service in the furture. S~~ely, ?OM J Drilling/Planning Engineer TJ:rh cc/file P.A. Dimmock - BP Alaska Exploration Karen Mestas - Standard Alaska Production Co. Dick Stewart - Union Oil Co. T.A. Edmondson - Chevron U.S.A. N.H. Smith, Jr. - Mobil Oil Corp. J.C. Willner - Phillips Petroleum Co. EASTMAN CHRISTENSEN RECORO OF SURVEY F::'OR · ii- ]")F" E R iq T 0 F,: · '.:.'; T F;: Lif":-I' U R EF. · WEL. L_ ~i- L O C: A T I I":lN · ,JOB NIJMBER : q/~p _/~,~ · RIG : FfOYOI',I * · ]]ECL!NAT!ON : · RKB "f'O SEA : 69.0 : ARE:O AL A::";I< A-, I NC. .~. : P ;z d :'-':K .~. : 9A (O~t~,~,~ ,~l~/~, ~) '.:";LO'I" : 9 : I< ~J P ;& r. u I:: F i e 1 d, N,:, r- t h 'S '1 ,:, P e, A 1 ~ s k ~ .~ :3 0. ~._'::' 5 E * F'LgNE OF VERTIC:gL SECT ION -~ .~. DIREC:TION : N 87 35 E . . .> . . . . . . . . . . . . . . . ..¢*~....e,.* . . . . . . ~ ~ ~ .~..~..~. 7-7 Eastman ARCf] ALASKA~ INC. Pa d :2:K KuPar. uk Fie'ld~ Nc, r. th SloPe., A'lask~ SLriT : NELL. : 9A F'BHL ' N 87 "-"~ E DATE F'RIN'rED : 07-Nr-iV..--.86 Fll IR REP NKI. : ::;q)/-.:'::A!=: ''", '"" ................ -At.~ JOB NUMBER : MEA:;URED DR IF'T DRIFT E:OURF'-;E TRUE: VERTIF':AL SUBSEA R E C T A N G I_1 L A R ' C L 0 :-S U R t2: !::,OL,I.', ~, DEPTH ANGLE I"~IRECTION LENGTH VERTICAL SECTICiN TVD C: 0 0 R D I N A T E 'S DI'.:i;TANCE DIF;~ECTi[Cq'4 :!!i&-~i'..:"I'-:' [) M D M D E F' T H D M ..... · ' oO.) o o_ '.~P]Pi 00 0:2:6 N 7~ 4:3 W 4.8~';:~0 9ffl4.98 14°':',_,._,. 00 ('). 24 S 27 ::6_ W 528. O0 1482.96 1992 00 0:36 N / = . .. . .... :,._, 12 E 509 O0 1991 94 24'.-}3.00 2 30 N 10 36 E 501.00 2492.73 2807.00 2 24 N 2 12 W 314.00 2806.44 '2'.-}5'F.~.0~'~ :3 4-2 N 50 :}.':6 E 152.00 2'P58..2:3 :31' :30.00 :3 24 N '7:3:30 E 171.00 :2:128.2:3 :::.:86:3.00 1.'2:24 N 71:34 E 7:--::3.00 :.:.:847.77 7.21 242:2:. 7:3 :-'::. 76 2737.44 12.26 28::ii:9. ]ii: :2: 28.41 :3()59.2:3 16,2. :2:2 :3'7'78.77 10.78 N 6.76 E 24. 1:3 N '7.75 E :'::1.25 N 10.'P4 E :::_:9, 64 N 26. '15 Ii:-' F-:O. 84 N 15'.:.). (}5 E 0. ("x') S 1.65 N 45 1:!!': Iii:: 4.5:"_-': N 4 14 4.6:3 N 5("~ 4-() W 1.:2',4 N 6:3 4. 4.022.011) 1'7 36 N '74 1:3 E,' 159.00 400().'P6 4.1:ii:1.01]~ 2:':: 12 N 87 30 E 159.00 414.9.'F.~2 4.:2::'::':) 0 0 2:9:2:~') '.E; :::9 .=;8 ......... 54 E 1 .00 4291.44 m-~ ."'i ,"l.. -- . 4,_ ~,-., {'){'} :::7 18 S :--:::: :36 E 1K:'-}. 0(~ 4-44'.-}· 1{'~ 5062.00:34 4:3 '.S ::::3 42 E 5:2:4. or) 4:3:3o. :::: 1 20 3.4...5 :39:31.96 ~: .... :.. :::6 4 ('}::::('~. '.:.~ 2 :37'::3.4:3 4222.44 4:32. z.._',"" '-' 4 :'::_ r-'-:_ ¢~.. 10 745. :Z:2 4:311 · ::: 1 ?:3. I'P N l'.:.)'i;). 69 IS 101.93 N 254.27 E 103.40 N :324.:34 E 102.04 N ,-128.2'.:> E 94.62 N 742.4:_:: E '""=""F _ _ 997 95 5201 10 · _,._, ~ :,. 00:31 6 N :3 :':: :'::(") E 464.00 .52. 7 ~"~. 1 i') . . 5715.00 28:3() N :32 6 E 1:39.(')0 54:34. 10 1("}91.54 5:365. 10 587::-]:. 00 25 24 N 80 42 E 158.00 5574.92 1162.72 5505.'F.~2 60:32.00 22 6 N :'::1 42 E 1.57.0('~ 5'72~:). 44 122/:,. :35 5651.44 6212.00 18:30 N 77 24 E 180.00 58::::'.:).2:3 128:_--:.17 5820.23 6401.00 15 30 N :34 24 E 18'.:.'~.C)0 6069.95 1:34:3.01 6000.95 6588.00 14 54 N 87 0 E 187.00 6250.41 1:3:-}2.01 6181.41 6772.00 1:3 18 K-; 88 0 E 1:34.00 6428· 86 1436.79 6359.86 6'.::~:35.00 12:30 S 82 42 E 16:3.00 6587.74 1472.89 6518.74 744:3.00 11 0 S :'::1 45 E 508.00 7085.08 1574.70 7016.08 158.39 N 1337.51 E 1:346.::35 Iq ;:.::: [!5 I':' 162.06 N 1386.2:9 E 1375.:!i!::3 N ::::3 ::,:.) t 162.46 N 14:31.20 E 1440. :}';' I'.1 159.51 N 1467.46 E 1476.10 Iq ::',::: "i;:.:: !" 14.5 51 N 1~/_.,:~ ,-'= ~:"~' z.,::, :..~.,'1 ....... ;K_, E ~ FJ i -' · ..~/~,. :.: ,.., ,._, . CLOSURE - DISTANCE : 1576· 68 DIRECTION : N :34 42 E REPORT UNIT~Feet '.:;I IRVEy.~, i]:ALP. ULAT I K~N ME 'FHCmD : I'?a d i u s ,", .F ,'-u ,-.; .~..i. -- -- ,~,r,,~,-~.~,,~.----,q . ,. ........ Eastn n '.~;I...IRVEY Rt..IN I NFF:~RPIA'I":[ ON - ( F:ONT ]: NLIED ) '.F.;IJIRVE Y T,:",OL: J30 M~,:I :E:F'LID DATE 01 -UtZ. T-,=, z, E/E: MAONETIC: '.:i;INGLE '.E:HI"iT '.E:L.IRVEY Eastman EASTMAN CHRISTENSEN RECORD OF SURVEY OI::'E"RAT OR * '..::; T R U c-r u F,: E: WEL. L .~. -~- L 0 C AT I O N -~- * ,_lOB NUMBER : ~'~ -- /~t9 ~ RIG : DC~YON '.-} ~ DECLINATION : * RKB TO SEA : 6?.0 EC DISTR.[CT : Anch,:,r-ase, Alask~ 7-7 East manL ARC:O ALA'.'-':I<A, I NC:. Pa d :3K Kurar. uk Field, N,':,r'-th c-.~,l,:,pe, Alaska 'SLOT : WELL : 9A F'BHL : N :-::7 [mATE PR I NTED : 07-NOV-::2:/_-, OIJR REF. NA. : S0/_-.44':?. 2AR ,_lOB NUMBER : MEASURED DRIFT DRIFT COURSE TRIJE VERTICAL SUBSEA R E C: T A N G IJ L A R m:: L '1- '""' I' ' -' '" '"' !-' ......... .. [EFfH ANIZ'iLE [IREL. TION LENGTH VERfI_.AL ~:;EI-:TION TVD C: 0 f"l R D I N A T E S DI'.::;-f'ANIZ:E DIRE:C'I'[f"It'-.t ""'..'1..:1"-, D M D M DEF'TH D t'1 472.00 ," 24 N 4.'i'_' 18 ~~ 472.00 ':.'~'=".00.': ._._, () :36 N 72 4.9~~ '..'75'1-.'P8 148:3. O0 0 24 S 27 :-::6 W ~28.00 1482. ':?/_'. t992. O0 0 36 N 65 1:2 E .509.00 1'.~91.94 0.00 -6':::'.00 0.00 N 0.00 E 1 '":' '':" C '-' · · · .~= 4Jo, O0 I 1/_-, N i 17 E O. 5:.'3 885.98 4.57 N O. :_::4 E -:2:45 141 ."::. ':76 ~..'-' '-?s: N .:~. =i¢' W i .... -- I~l -~.2:3 i922·94 0.48 N !,25 W 4. 5:i~:: N 4 1Li. !:::: ,:.,.. il L|.6:-:; N 50 /I-()(.,.J (). I :1.. :34 N 68 4:!3 W ,:.,.. I' 249:3.00 2 30 N 10:36 E 501.00 24'F.¢2.73 2807.00 2 24 N 2 12 W 314.00 2806.44 2'F~5'.-?.00 .'2'. 4::" N 50 :_::6 E 152.00 3'1:3~"~,.00 8 24 N '7:2::30 E 1'71·('~0 3128.23 3863.00 13 24. 1'4 71 54 E 7:3:3.00 :'::L:47.77 7 · "21 2:42.:: :2:. 7:3 8. '76 27:37.44 12 · '?/- .':,,-', c. c~ .-'. o 62. :32 3778.77 10.7:__:.: N /_-..76 E 24. 1:3 N 7. '75 E :31 · 25 N 10, '.'):'4 E :3'F.'. 64 N 26.75 E-" 80.84 N 159.05 E 4022.00 1'7 :Z.:6 N '74 1:3 E 15'F,'.00 4000.96 41:::1.00 2:3 12 N :37 :'::0 E: 159.C) 0 4147).'.:.~2 4:3:3'F~. O0 29:30 S 8'F~ 54 E 157:.00 4':.:."~;~1.44 4528.00 37 1 ::_': .'E; 88:2:6 E 18'~.?. O0 4. 44'.::;. 10 5062.00:34 4:;; '.:3 8::_'-: 42 E 5:34. O0 48::'!:0. :-]:1 20::3.45 :39:31. ':76 '::"~':' :--: 6 4 ¢')::2: 6) 9 2 .~...- ~-' i _ . . · . .. :2:2::::. 4:3 42:22.44 4:32.23 4:380. 10 745.82 4:2:11.81 5220.00:35 6 S 88 42 E 158.00 5010.:31 8:36.14 '1.94.1.31 5377.00:34 4-:3 ::; :32 0 E 157.00 51:3'.;~.00 925.34 5070.00 ?:":"::' ()0:2:4 :'::() :-::; ¢2:7 18 E =("'"' O0 ='.~'- .... ~4'::'.~ ............... , .,._, .... ,~.. 4:2: 1 ':)(')':~ 7:3 43 · .... · ..... ~.. · ..._'t..~... · 644'.-? O0 :':::3 6 S ::::'T¢ 24 E 5/_'.70A /-,A?M. 5':? 1.....-.4:3:3 5'.:)56 59 700'.:.~. O0:31 24 N 88 0 E 560. O0 /:,47'F.¢. 18 1922.9:3 64:30. 1S ':72.57 N 832.97 E: :::: :':: :::: . ()';' Iq ::::.7:zl<:, j:: ,.~.. I :5:5.2:3 N 922.56 E ':;~2,./:,. Zl-'::~ 1',1 :ii-',.,-'t 4:7:-: 1::' '., .i 58.52 N 1208. :3::: E 12()'.:). 7.5 I",t :3 / '! .4 t: :.~..- 49 44 N 1 ~' ''~'''' 6(') E 1 fi24 4 C) I",1 : '.:.: :: t:: · ....I ~ ..:j · · 53. O'.T¢ N 1 :-::22. :2:/.'-, E 1 :!:::'::2:::. 14 lq ;i:i::ii: ::i:'~, I' - . ........... - ':' · '::.'O'.T,'4 / ' ' 7527.00 :...41 42 N :.37 3,r} E .~1:3 O0 /-,';'4('). &l ':,¢:,'::~4.,rr"., 6871,61 ~ ..... 73 N 20'.-73 20 E. . t I',.I :::::::':: 'i. :: ,, , CLOSURE - D I STANCE : 2094.17 DIREC:TION : N :3:3 15 E REPORT ~ I TSFee t SURVEY CALCULATI ON ME'FftOD : Rad i u,-: ()-P ,'::,J r'.,..,...,, i.,] :.:., SURVEY RUN INF:ORMATION D I RECT I ONAL DRILLER: R BARNARD ,'.,..,:'~;~.. '.:;URVE]Y TCI()L: GCi Mu~d :::;F'l...l[) KfA-FE:: ('-) ] -- I'_] C: -I" - ~ :::: /_-, .... lOB NI'-~: 450-..l '.:.)() Easttr n [ · ::, JRVEY RUN I NFORMAT I ON ( CANT I NUElh ) ::_: I DETRACK C:ALC:LILAT I ON: T I ED I N AT' 5A/:.,~.:.' MD '.-];IEDTRACK KOP 5275 +/-' MD ~...;~ .... ,,, ~ ~~ ~-~~~~~~- --f ............... ~ ~ : . , . . . . ~. ....... :_;::' ~.~ .... i_'.;.'.~.. . ~ ~.. ~.[ ~ .... ~ - , . ....... ~~~ ..... ~ .... r..~~~~~ , i - ~ - ' ' i -~ ' ' i ...... ~ '~-- .... --=- . . l~l i : .... I I l~~ December 8, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60090 Well: 3K-12 Field: Kuparuk North Slope, Alaska Survey Date: November 17, 1986 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-Sun/NL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 r:'~RC:O "'~ ...... " .. ~'~L~,.-~.::,l--.~.-~.: lng Df4TE OF .C;LtF.'VEY :BI< .... 12 C:OMPUTP~TION DATE BU.:,.:, L~YRU:,L. UF IL. ::;t IP~d:::'Y [-'::iL! P F~ RILl Ii:: ........................................................... T~...iVT.:.".~':[~E'F~~T:~,T-, ,.~--F,i~~';F-"i:]T-:.'5:-: B 0- .- 60'/.':;".::' 0 AL~4.::,I--,~-~ I-i::EI._L.Y BUSH I .·. M .. .................. :-. .::'... ,,. :.. T I:;: 1..I [i:: S U ~* S E ~ (':: (] lJ R :~; E C: 0 t.j R S E 000 - L [ I~i T 0 T vA L. ME~SURE.T.~ V::F..RT.T. CAI... VER-'FiiZ.:(~L"- .I'NCL;-TN¢..qT TON 'D .T. R'ECT.]:.'ON ..... :E:E~Z~'TTW .......... R~:T~'~[IKFr~iR ...... C'OOR.TJ :i: N (.] 'T ['-.'. :~; OF.'_'P TH DI~!:t:::' TH DEPTH DEG h:l I. N DEGREES DEG/ .. 1 00 1 ()0. C)O :B 1 ,, O0 0 7 N 2'F'. 80 E (). 12 (), 0'? N 0 ,, (':,~:5 t:~: 20C~ 200,00 131.00 0 7 N :B0.:39 E 0.00 0.2'7 N 0. i~: ~00 5:0C) ,. O0 ~3'1'. 00 ................. 0 ........ I-O ..... N' 2'4,30 'E ...... O'TD';~ ....................... Q ~"5'~ ..... N ,:]~ ,, 27 i .... /I. 00 400 r~ r~ :':~"::: 1 (":~ o o 18 N "":' . . .,~ ............. ................... /.:_,. I() E o '-'= ~") 70 N ,'3 /.,,", ~ C) 0 45'?, 99' 430. '?'F' 0 :B 4 N :5:6. 10 E o, 28 0.7'F, h.I :I ,, 5:7 600 ...~':~'~. . . ':~':~.... ...~'0,..,., ,~c~.... n ....... ~7 S 74 ,' ~'~-~E 0':' 3 ~ ......... 0;6'q N ":',..., f~4.. '700 6'? 9.78 6:30.98 () :B4 S d,O. 6'~ E 0.27 0.22 N :3 ,, 6-4. t:::; ',:a'~c~ '7'::~'::~ '"""" 7:::6), q):::: 0 22 S 4:B 50 E 0:24 '-' .......... :,,: ........ 0.26 .::, 4. :BO ,;:,~)~ ,::.,,-.,,~,-,::, :. ,, ,~..., .- ,.., ...., ....° ':' r~ ,~:, / 0.. ......... .,~'~ ............ ....... ~:"' 31 ;' I'0"-~ .......... 0'~'~ .................... i%f'TF;'"' ~; -4 ,:'::, '5; i:" 1000 9'?'?. 97 930. '? 7 0 24- S 16, ,, d, 9 E 0. 10 i. :3'7 'S 4. '~::' -":~ I I 00 i 09'? ,, ? 7 I O:BO. 97 0 2 d, S 2. 10 E 0.' 12 ' 2.0~5: S ~3. (;:,,6 ........... ~, /~'-S 5.0:2 i:B00 1299.9'7 12:B0.?'7 0 10 S 12. 10 E O. 17 :B. 16 S ~;,(;)1 1 z~OC~_ 1 ._"::'~,9. . . q~v. . 1 :B:::O .... ,9'7 0 7 S 6,4: . i 0 E 0. 1 ~ 3, .a'-':._, '-'.:, 5 , i 4. i:5 1500 'J. 4, 9'?. 97 14 :~0. ? 7 0 ]; 8' ~ '-" .... '-' "' ' ..... · :::, ~:,4~ ,::,~_~ 'E ........ ~:-~"7 .................. 3~5I .... !~; ~f:;..'! :;:: 1600 1 '5'79, 9,6 15:B0, '?,6 0 24 S 69.80 E 0. 1:2 :B. 75 S 6. C:,::::; ]. 7o('). . _ :1. ~-'v':?,_, .... , '?A, ......... 1A:::c) . '~F,.. .... 0 1'/-, '.5;[~:4 , F',':~_ .. E .... 0:-'1 z_ ,_, :B. ':':',.., ... '.~; :~., ,, ,(:,:3 '1800 179'?,96 I'7J:'c) 9'5 .......... -0 ...... [":6: N .:,~Y E ~" ~-"'S- /-, ',::'::~ 19()0 1899, 96 18:30, 96 0 27 N 19,69 N 0,22 3.01 S 6,.'77 2000 1'P99.95 19:30.95 0 :39 N 1:3.50 W 0.21 2.08 S 6,. ~;~;;~ '2I'00 207~ '?~ ....... ~ ...................... . ...... "- ,.-..:,?, :,_ ~ ~1 ~ ~ 'N I~,. (~ N (') t:,'? () ~'6,-'-'.~: ,:':.,~,',: ~:"' · 2_ 2 (-)_ ('~_ .... 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('J ' 04 (') . ,:)C) '6'00'i '00 ............. ._,°-°~--'~. ,_,,_. ;:, .................... ._.~r°~. -. ~, ~_ O' 04 0 . C)C,,. .... 700. O0 :d. ,_:-~1 S 6.88 E O. 04 O. 0(').. ARCO ALASKA, 3K .... 12 KUPARUK A L A S K A M E A S U R E :0 I)EF'T'H 1865;' 1969 2069 226S.' 2:369 256',:.:' 2'6/:,5? 2770 2971 .'2:073 :>,': 176 · .D ..'L ,2, :B 500 ?.612' B724 I N C: ,, :.S F:' Fi:R R ~ ..... S I_IN b..I El... L. 't~; I...1t:;~ V [5 Y .'[ N G C 0 M PA N Y !:'..,- DATE OF: ::;LIRVEY NOVEMB[ii:R C:OMPLITAI'ION DATE .............................. NO %,'tS.-: ~'-I'?:.,--~ .... ~R-'PiK ::: B 0 --,.'.'-., 0 0 '7,' KELL. Y lr:]US;HINtB ISI..._EV. OPERATOR-.MC:GL ~:1: INTERPOLATED VAL. LtES F'OR EVEN 100 FEEl" OF SLtB-SE~ DEPTH 't"F:t. IE V E F;: "1" I C A 1 .... Ii I: F:' T I--I 2 ::..!: 69 ,, C:, ~.'-~ 2 3,5, ::;', 0 () :;2: 4-69.00 2569.00 26,'.':, 9, 00 :276 9. () () ',::' f-::,'!-, 5? ,. C) .... ,o/. ,? 00 ,,:L :: 2, F ,, , :::.: 069.00 :2:169, ..::,.,:.,::, ::,. (.h. ::!!', :B,:':, 9 ,, 0 () 346'!::'. 00 -',=:z c,, O0 :36,"-, 9.00 ..... ~-~'A ....................................... TOTi~[: ....................................................................................................................... VEF, T I C:A[.. REI]:TAN(:!iI.I.IL Al::;,'C:OOFR[:I I N~.~I E.::, MKI-- TVD VERT IL.i..~l..-'" "I ' f"l '""" t ........ I:. EF TH hl _. F,, I' r.t., !SOUTH EAS..:T/WES]' 24()0 O0 lV .-,:,Z .... N 2500.0(b 24. 10 iq 260(). O0 .......... ~0'; .1.2 N ':.:: '..:' (::~ ,':) ,, 00 2':::', ':?,:':, N 2::::C) O. 0 () :'22. ::.':':5 FI ]::900.00 8" ..~2 N F:O00. O0 8.60 · 3100. O0 G::3. O0 S · '"~ ""r "" '" .",,.':.'::,, ©0 64 ~.,::. .::, ::.:.': 300.00 102.8,:':, ...... ~, - .. i .- .,.- :36C)0.00 242.2:3 S 109. 15 E ARE:O ALASKA,. INF:. 3K- 12 L. uMF U FA ! I L. N DATE t...~ L. A.:,K (..~ ......................... ~ ..:: ::c¥. :::.::: :w .,, Z NT'ER?8:~;~TED VAL. UES FOR EVEN DATE OF SLIRVEY NOVEMBER KELLY BI_I!.-7:;H I NG F.!:t_EV. ::.-: 0 F'F: R A T I.-. F.'.-.--I'1C :.":~ I_ i :[ F;t IF; lO() FEET OF SLIB-SEA DEPTH "I'RUE M E A SURE_F.) V EI'-?'T ! rs: A L D E F:' T H !'] E F:' T H ..;) 7/ ._~ 4077 -.1. :32 2 444,5, 45 '70 4696 4820 45:,.q 3 5066 · _ I ..'PC) 55:1 :':: 5 ,.'-I-:2: · _, .d ,".:':, 0 56 8 :;:.': ._1 ~"~ t.,~ ._=;9'.29 ~,-~- (.)..' i ~ ..................... TOTAL VERTICAL RECTANLSUL. AR C:001:;:D I NATES ME.I-.TVD VI;!:'.R'I" T C:AI .... /EFTH NORTH/SOUTH EAS-;T/WE;ST D I FFEREI',!C:E 40 ,'.!:, ?. 00 4.16? ,, O0 .-,, ,- '~ .,::, 0 ;7. . 4369.00 44/:b9.00 4 569,0 0 46,'.'.:.,'P. 00 47/.':, 9.00 4869. O0 4'3769. O0 506'.:.~. 00 .:51 ,'_'.:,9. O0 ' 52 <':, 5.'. C.) 0 5:369.00 4,:")0('). ('),'"'~.... 4:'?/0, ¢)2 ....... !B 1 ,"-,7 .47. ET ]..-,,z.,/..... 'P:.7.: ;7:' ]. , 7:'::: 4 .t ¢.') c) c) c) P;/:,O '=';,-1. S 181 '2 % E-' 1 '='-' 0'-.-./ 2:3 i ~'-'-, .... . ...... ~ .... ,~ ...... ._1 ..Zi ,, . . ... 4200, O0 633, I0' F:: 192:, 23 E I77', 2I ....... ;:-.-:4, 13 4:30 (") ...... ...., z: .... ,. 4 o E 2 ti ~ , 9.....":: 24 .7 ...."::' 44()o, 00 78(), 95 S :;i:17, 7/_-. E 227, 14 :25,, 2() 4'.."5.-, 00 00 .......... ""='-'" "'" '='' · ..... ..............· -.,. ,..-,. ,-,., .'T:; 224' 7q:2" E ....................... 25 I'7-I-~ ":',:......,":', '-'... ,"'".., 4600 oc~ ':,'--',: o,:.) :.:.';; 22/:, ~':~ E 274 ~':';t'~ 23 "::":::' ~, .... -' ,~.t_, ~ ... . -..... . -_ .- ,, ....,,..., 4700 '4800 .......... .,...:,~. 49(")("). C) O ~ 142.6 ~ S 2:7.: 8 "~1 . . ..... 7._ E :_::4 4 '7 4 :2:2: 14 .500C~ ...., 0() 1:21:3, :--:4 S ,... 51'00' O0 fq'2C) o, r) c) ]. '-' ='. -~- 7 y:l S'; ....... . .... ...",..I... ... 5 30 0 00 1 426 4..:,-'= "-'.:. 4 60, 482.60 2 71 5-;:..--.' E 414 '-"-' '::'3. 13 .... , .... . ar:. a;7. .,... 2'84"5 5'? E 4, 3'7, .'_--:7 23. :[ .'.5:. .... 22. :_-':7 2::.:.'. :3 6 ARCO AL. ASKA ~ :3 K- 1 2 KUPARUK ALASKA t:.!;F:'EF:~:F~:"~ ...... fi:L.ilq WEI....I .... SLtRVEY I NG C:OMF'ANY ......................................................................... RNCFIORAGE- I tq C:. COMPUTATION DATE I NFERRULATE£ VALUES FOR EVEN DATE OF' SURVEY I',IOVEMBEf~,' I<EI_I_Y BLISH I NG [:.:.~,_ E':::. v' .. nPERATF~R-MC :31...I .f R:F: " TRt..IB MI-'::. A SL.IRFZ. [:l V F:i; F:;,' T :i; C:AI .... I.]E F' ]"1-'1 I:) [".: F:'T H FEET OF SUB-SEA DEl=TH 62 ':7/5 .576 '.:;'. 00 6, 4.1. :5: 5 :::,'_':, '? ,, 00 /:., 54.1. 5 '.:.:',:'--,'!9, 0 () ,:'.-:, 66 4 ,'.'.-:, ,:} ,:':, 9 ,, 0 0 -"-" .... ,{-, 1 6/,:, 7 /::,'P, ()() 6 '? 0';> ,'::, :2:69, 0 C) '70:31 ,<:, :36'.:.>. 00 '7.1. 5:;:'.-: 6469, 00 72 ':? -..'.1. ,,:, .':::i ,'::, ':;, ,, 00 '7:3'!-.-,' 6 6, &, 6 'i;;', () 0 '751 7 676::;'. O0 76:2:::: 686, 9.0 7 '770 6'F.> 77. 17 VERT I _.Al_ RE'r":T'AN[~LII._AF-i' C(]ORD I NATEs--; MD--TVD VI::-_RT I CAI .... DEPTH NOF;Tf'H /::-::0t.. ITFI EA ::-.-;T / WE"'.F::T D I I.'-- FERENC:E L-.:ORR ECT I ON 504.67 526.75 54 ?,-F.~:,q. 572.72 595.94 618.63 " 64 (). 'i? 0 6.6,2.8 i 705.7I '72'7.06 7zlE:.;-53 ...... 769..9:';..' 22.07 22, · -,.-, r.':, .,:2 .,::. ,, '2) :. 23, 0 '":,' ':" '") ~-'::i,":. :.::: / "::' 1 c, I .~.., ~ ... .- . ~,. .~... ,, 2 .1 ,, ::-'~:~: 21 "' 2.1....-1.7 21. :2:'i;:.' 56. C) O.. (3. c). 16 ::-: :3 . :.3.' :2 S ..:: ....... z.'""c,. 1:3 5'7 () O. 00 1701.90 S :344.47 5800, O0 ~ ' 4 ,, I / 71 I S 360 87 59C)C). ()C) 1841. 11 S :2:7'7.9/., &, () () 0 ,, 0 () 1910, '79' E: :3'P 6,, (] 6 6100,00 1~7~,"3I E; 415.00 6,200.00 2046.90 S 4:34.50 6 ...... :3 (") o . () .... c) .:..'":' 11:3. ?; 1 ....,':' 4...., =..,., =' . 12 ................... :. /::,,, !...:, % 476 54 6~=;C)(') ¢"~("~ 22zt. 4 :t.~- E; .q.':?¢) ...... ~, ....... ,; *..., ...... - /-, ......../-, (') (") . (') ............ (') '2' ::: (") ::::t .9. (")_ E: ~:;. 22. 1 .., '= 700 C)O 23?:3 F~ c, ~;45.87 ., ~ .... i._ ...t ,- 6 E: C)(). 00 24:38. 19 S 569.7.5 /-,9(-)8. 1 7 9 Ffi(-) 7 c,R E; ......... THE: CALCUf_.A"I" '[ ON PF:;,'CH::::I.'.-'.':!:)L.IF;..'f.-.::!!.~; L.I'.::'::E A I._. :[ NEAR I N"r'I.'.<RPCU....AT'I. ON BETWEEN 'I-HE I",tE:AF:;,'EL::T' :7-:0 F'C. IL':.IT MIl (FROM RADIL.I'.E; OF CL.IRVATL.IRE) F'OINTS ARC:O ALASKA :'::K- 12 KUPARUK ALASKA M E A ~i,:.; U R E D DEF'TH 72'70 73:34 7447 7/:.., C~ 1 '765 C:, 76,S7 7 7 '70 I NC:. S;F'E:F;:F..'Y .... .::;t. IN WEL. L SLIF;:VIF".YI NG F.:OMF'ANY DATE OF' .:,_RVEt NOVE'MBEF~ TRUE V t::':: R T I i.-.: A I .... DEPTH 6565. 11 6617. :3':..> 6710, 74 6',:.i;3 7 ~ '74 ,"::, 8 78. l d. ,/:, 8 ':2 2 . 17 6'77¥. 17 · :, JI:':-.::,E H ......................................... TCJTF.~[... VERT Z _.~-~1 .... IREC:TANGLILAR COORD [ N A ]"E'S ....... DEPTH NORTH/S'OL1TFI EAST/WEST MARKER 4S)8. 14 E TOP KLIF'ALIRK C: 510.23 E BASE KUPARUK C ~'I%"??-E ...................... TOF~I:.::]]F'~'RL~F:.'T '-"A .......... · 567,, :'3Zl. E!: BASE KI..IF'ARI...IK A 571.87 I.:i: '..SLIRVEY DEPTH 575. i'2 E PLUG BACK TD 5?4.8:3 E ]"OT'AL DEPTH DRIL. L..EF:~: STRATIGRAPHI C SUMMARY ............... MARKER ................ '"'-~,fRED'"DEPTH BKB ...... ~:'= = =' '= -:" TV D- ' ................................ TRIC~."F~S BKB SLIB-SEA VERTI CAL. TEd::' KI...IF'AFi:LII-::; C: 7270 BASE TOP KLtF'ARUK A 7'447 ....................................... BASE KI..IF:'ARt...IK A 7/:..01 PLI...IG BACt< TD 7667 'T'¢FI'(.1L. I]E:F"I-H DR]7I....LER '-~'7"~rh. ...... ,':: ..... (:,._ :t :L ;-/- 17 ,, ':' ' 6710 .":.'P~' 6C4:::7.74 68':.)2.1'7 ...................... 67~?' '1'7' .. (.'.': Ct Iii R D :i] hi A ]"} . WITH REF. ( 0 R I (~; ]i N .... ]. ]. ()';;'F' :iii;i ..... -; :i ,:.,. ?' i,,ii, SEC :35 T FROM I....INEAR EXTRAPOLA'TION"BEL, ON 'DEBP~-' ._-STAT ION, .................................................................... COMPUTEI-7 PR(]GRAM - ::;PERRY SUN THREE 1]IMENSIONAL RADIUS OF CURVATURE. I'JATA F:ALF:ULATION AND INTERPOLATION BY RRI]ILIS OF L-:URV~TLIRE ........................................................ --.._~-..L. L ................ ~ ;--g .~ :.:Z :,_T_%: ::.~]".~:.-.LL .................................................................................... :.2-.Z ............................. I]ATE." OF SURVEY NOVEMBE.".R 17., COMPUT'AT~ON'--DATB NOVEMBER 19, l'.-.-,':F.:6 ,JOB NUMBER AK-BO-6OO'F/O .-' · : ~ :: i,'-~ I--..ELLY,:BtJ~H~Nb EL. EV /-,':) (-)(-~ F'"t'. F -5GG. CG I 77'70 5Cq '5CC. C qBCC qtqSKq. :.NC. S:C ~. 7770 1 ARCO Alaska Inc Post O 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 22, 1987 Transmittal #5893 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (.1 blueline unless otherwise specified) 3K-12 2" & 5" FDC Raw 11-11-86 7100-7741 2" & 5" FDC Porosity 11-11-86 7100-7741 2" & 5" DIL 11-11-86 3980-7767 Cyberlook 11-11-86 7150-7720 3K-11 2" & 5" FDC Porosity 11-4-86 7000-7782 2" & 5" FDC Raw 11-4-86 7000-7782 2" & 5" DIL 11-4-86 1000-7808 Cyberlook 11-4-86 7000-7750 ' 3Q-16 2" & 5" FDC Raw 11-18-86 5900-?226 2" & 5" FDC Porosity 11-18-86 5900-7226 2" & 5" DIL 11-18-86 3931-7252 Cyberlook 11-18-86 6030-7100 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Rathmell D & M L. Johnston (~endor Pkg) Vault Cfilm) ARCO Alaska, Inc. is a Subsidiary o! AtlanticRichfieldCompany ARCO Alaska. Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DAT~ January 2, 1987 TRANSMITTAL # 5869 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3K-11 ~ 3K-12 ~ 3K-8 '""~ 3K-10 CBL 11-16-86 5547-7730 CBL 11-17-86 5115-7674 Pulse Echo Log 11-16-86 CBL 11-16-86 5502-7173 7002-8381 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Chevron (+ sep) Mobil (+ sep) Vault (film) L. Johnston SAPC (+ sep) Unocal (+ sep) ARCO Alalkl. Inc. is · SuD$~clilry of AtlanticRichfieldCom~eny .... STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION COMMI'.. .,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Fi Stimulate ~ Plugging ~- Perforate - Pull tubing Alter Casing [] Other IX C~PLETE 2. Name of Operator ~ARCO Alaska~ Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1109' FSL, 316' FWL, Sec.35, T13N, RgE, LlVi At top of productive interval 1133' FNL, 291' 'FWL, Sec. 1, T12N, RgE, At effective depth 1344' FNL, 368' FWL, Sec. 1, T12N, R9E, UM At total depth 1399' FNL, 388, FWL, Sec. 1, T12N, R9E, LH 5. Datum elevation (DF or KB) RKB 69' 6. Unit or Property name Kuparuk River Unit 7. Well number ~-17 8. Approval number 0. APl number 50-- 029-21655 10. Pool Kuparuk River 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor Surface Length 80' 3941' 7720' Production 7770'MD 6977'TVD 7667'MD 6892 'TVD feet feet feet feet Plugs (measured) None Junk (measured) Nol3e Size Cemented Measured depth 16" 1540~ Pol eset 1lO'MD 9-5/8" 980 sx AS IV & 3978'MD 320 sx Class G 7" 300 sx Class G & 7754'MD 175 sx AS I True Vertical depth 110'TVD 3887 'TVD 6964'TVD Perforation depth: measured true vertical None Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7407' Packers and SSSV/type and measured depth) HRP pkr @ 7380 & TRDP-1A-SSA SSSV @ 1796' 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final press[Jre 13. N/A Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14. Attachments (C0npletion Well History w/Addendum, dated 11/19/86) Daily Report of Well Operations X Copies of Logs and Surveys Run ~X 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ Form 10-404 Rev. 12-1-85 Title Associate Enqineer Date (DAM) SW0/146 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided, The "Final Report" form may be used for reporting the entire operation if space is available, Accounting cost center code District I County or Parish State Alaska iLease North Slope Borough Field or Unit Kuparuk River ADL 25629 Auth. or W.O. no. ~ T t e AFE AK1444 I Completion Nordic 1 API 50-029-21655 A.R.Co. W.I. 56.24% Alaska IWell no. 3K-12 Operator ARCO Alaska, Inc. Spudded or W.O, begun Date Complete 12/4/86 Date and depth Comp_lete record for each day reported as of 8:00 a.m. 12/o5/86 12/06/86 I otal number of wells (active or inactive) on this est center prior to plugging and ~ bandonment of this well I our I Prior status if a W.O. 1630 hrs. 7" @ 7754' 7667' PBTD, Tst SSSV 10.1 ppg NaCl/NaBr Accept rSg @ 1630 hfs, 12/4/86. ND BOPE, NU & tst tree. Rn 224 its, 2-7/8", 6.5#, J-55 EUE 8RD AB-Mod tbg w/SSSV @ 1796', HRP Pkr @ 7380', TT @ 7407'. Tst pkr to 2500 psi. Tst ann to 2500 psi. Tst SSSV. 7" @ 7754' 7667' PBTD, RR 6.8 diesel ND BOPE, NU & tst tree to 250/5000 psi. RR @ 1100 hfs, 12/5/86 Old TD I New TD I PB Depth I Released rig Date I Kind of rig ll00 hrs. 12/5/86 I Classifications (oil, gas, etc,) I Type completion (single, dual, etc.) Oil J Single Producing method I Official reservoir name(s) Flowing I Kuparuk Sands Potential test data Displ well to diesel. 7667' PBTD Rotary , , Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day P-~ml~ size, S'PM X length Choke size T.P. C.P. Water % GOR GraVity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 11/17/86 3K-12 Rn CBL/GR/CCL f/7674'-5115'. Rn gyro f/surf to 7650'. Make GR/JB rn to 7679' WLM. ' ~rilling Supervisor , ~ h ~/~ STATE OF ALASKA ALASKA -,IL AND GAS CONSERVATION COMMI,. ,~ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown - Re-enter suspended well - Alter casing '- Time extension-_ Change approved program ___ Plugging ~- Stimulate- Pull tubing- Amend order--' Perforate-' Other - 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box I FIll3F~ Anrhnrar~. Al< qq§l_O 4. Location of well at surface 1109' FSL, 316' F-~I_, Sec 35, T13N, RgE, LlVi At top of productive interval 1137' FNL, 215' I~L, Sec.1, T12N, R9E,~ (Approx) At effective depth 1380' FNL, 270' FWL, Sec.1, T12N, RgE,~ (Approx) At total deoth ].437' ~NL, 286' FWL, ~:::. 1, T12N, RgE, WIN(Approx) 5. Datum elevation (DF or KB) 69' RKB 6. Unit or Property name F,_,~.~_!k Riv6r ~Jn!t 7. Well number 3K-12 8. Permit number 86-165 9. APl number 50-- 029-21655 10. Pool Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: meas u red true vertical Casing Conductor Surface Length 80' 3941' 7720' Production 7770'1VD feet 6975 'TVD feet 7667'~ feet 6891 'I'VD feet Plugs (measured) Nolle Junk (measured) None Size Cemented Measured depth 16" 154~ Poleset 110'~ 9-5/8" 980 sx AS IV & 320 sx Class G 3978'~ 7" 300 sx Class G & 7754'~ 175 sx AS I True Vertical depth 110"I'VD 6962'TVD Perforation depth: measured true vertical Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12,Attachments Description summary of proposal Well History 13. Estimated date for commencing operation Decer~r, 1986 Detailed operations program I~OP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer (Dm) (// - Commission Use Only SA/184 Date Conditions of approval Approved by Notify commission so representative may witness -' Plug integrity - BOP Test - Location clearance IApprOval NO' ,,,,-: ....................../.¢-~-~, by order of ,., --/ Commissioner the commission Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company {~, Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial RePort" on ihe hr$t Wednesday after a weu '$ spudded or worKover 3perat!on$ are started. Daily worx prior to SDuddmg srlouid be summarized on ~he form g:ving intrusive dates only District Alaska Field Kuparuk River A'th. or W.O. no. AFg AK1444 Doyon 9 Operator ARCO Alaska, Inc. JCounty parish or bOrOugh North Slope Borough Lease or Unit ADL 25629 Titl* Drill API 50-029-21655 11/6/86 ]Hour 0515 hrs. State ARCO W.I. Prior ,tatu· Alaska Well no 3K-12 56.24% if · W.O. S~udd. d or WoO. begae Spudded' 1LIO8186 "ti/to;se t]JtW-86 The alcove lo corr~t Ofltlh~, P~ 8e md 87. ComplMe-m~ord for eieh day reported ';.1%" @ 110' 2~4', (144'), Drl$ Wt. 8.9· PV 16, YP 18, PH 9.0, WI. 12.6, Sol 0 ~cepc ri& @ 0001 hr,, 11/6/86. Nil diverCe~. ,hz, e~ 11/6/86. Dr1 Co 254'. 16" @ 110' 3.~1'6", (3262'), DD Wt, 9.1, PV 18, YP 16, PM 9.0, WL 13.2, Sol 6 D~I, DD & surv to 3516'. §0~', 1.0~, N64.7E, 503.98 TVD, -1.10 VS, 1515', .3°, ST.IE, 1514.90 TI;D, 5.30 2919', 8.1°, Sl8.5E, 2917.53 TVD, -3.40 VS, 3237' 2.785, 7.69~, 22.21E , 18.7~, S14.0~, 3227.03 TVD, 67.91 rS, 61.295, 9-5/8" @ 3978' 6987', (3471'), Drlg Wt. 9.4, PV --, YP 5, PH 10, WL 5.6, Sol 8 Drl & surv 12k" hole Co 3993', C&C, POOH. RU & rn 91 ~Cs, 9-5/8", 36#, J-55 gTC cs$ w/FC @ 3887', FS @ 3978'. Cmt w/980 sx lead cmo & 320 sx tail. Displ using rig pmps, bump plug. ND diverter. for~mtion C8C 3394', 3706', 26"9°, 4813', 5212', 35.6~, 5905', 35.7~, 6375', 35.9°, ~ & Cst BOPE. RIH, DO cmo & fit equip. Conduct to 12.5 PP8 l!25/. Drl & surv 8½" hole co 6987'. ~16.4~, 3373.80 TVD, 123.49 rS, 115.098, 55.76~ 811.8g, 3654.88 TVD, 258.27 rS, 254.328, 92.37g S 6.1[, 4157.30 TVD, 586.87 VS, 570.18S, 142.99E $ 0.6g, 4566.14 TVD, 882.50 VS, 867.80S, 160.41~ S 6.7E, 4971.37 TVD, 1171.44 VS, 1158.40S, 178.95~ Sll. IE, 5453.24 TVD, 1516.88 VS, 1499.86S, 232.42g S12.1E, 5834.44 TVD, 1791.78 rS, 1769.17S, 287.70g 7" @ 7754' 7770' TD, 7667' PBTD, Freeze protect Wt. 10, PV 20, YP 9, PE 9.5, WL 4.6, Sol 10 Drl to 7770', short trip, C&C, spot diesel pill, POOM. RU & rn ORL. RU & rn 187 jts, 7", 26~, J-55 BTC csg w/FC @ 7667', FS @ 7754'. Cmt w/lO0 sx 50/50 Pozz & 200 sx C1 "G". Displ w/lO.1 ppg brine, bump plug. Did not recip pipe. ND BOPE, NU & tst BOPE. Prep to freeze protect well. 6880', 35.1°, S13.3E, 6245.52 TVD, 2084.87 VS, 2055.255, 352.17E 7384', 34.8°, S18.8E, 6658.67 TVD, 2372.37 VS, 2332.72S, 431.99~ Date / / Title ARCO Oil and Gas Compa,~y '~' Daily Well history-Final Report Instructions: Prepare and submit the "Final Report" gn the 'irst Wecr-es3ay ~fter ~!!o¢,,ab!e nas been assigned 3r well !s Plugged. Abandoned. 3, Sold "Final Report" should be subm*tted also when operauons are susDen2ed ~or an ~ndef~P~e 3r appreciable length of ~ime On wor~overS ~hen an o~claJ ~est ~s not re0uired uoon completion, rePod como!etlon and ,epresentatlve test ;a:a m ~OCKS prowCed The "Final Report" form may be used for ,eportmg the enhre o¢eration ,~ soace ~s avadaeie. District Alaska Field Kuparuk River Auth, or W.O. no. AFE 504998 Nordic #1 ICounty or Parish Lease or Unit Title Operator I A.R.Co. ARCO Alaska, Inc. Spudded or W.O. begun I Date Spudded Date and depth Complete record for each day reported aa of 8:00 a.m. Old TD 0800 hrs. 11/13/86 Released rig Classifications (o11, gas, etc.) Oil Producing method Flowing Potential test data North Slope Borough ADL 25629 Drill Accounting cost center code State Alaska JWell no. 3K-12 API 50-029-21655 W.I. ~otal number of wells (active or inactive) on thisI Icost center prior to plugging and I 56.24% labandonment of this well iHour i Prlor status If a W.O. 11/6/86 j 0515 hrs. I 7" @ 7754' 7770' TD, 7667' PBTD, RR lO.1 ppg NaCl/NaBr RR @ 0800 hfs, 11/12/86. INew TD l pm Depth 7770' TD 7667' PBTD JOate Kind of rig 11/12/86 Rotary Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, 8PM X length Choke size T.P. C.P. Water % GOR :Gravity Allowable Effective date corrected The above la correct _ _/ For form preparation and distribution, see Procedures Manuel, Section 10, Drilling, Pages 86 and 87. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 De~ember 2, 1986 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk AT0-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #5838 Transmitted herewith are the following 'items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-16 OH LIS Tape + Listing 11-18-86 #72087 3895.5-7157 3K-12 OH LIS Tape + Listing 11-11-86 #72055 996.5-7793 Recei pt Acknowl edged' Distribution: ~state~ of' Al as ka' ?~:~:~.~ TKKW' pg: 0040 (MF) -C ED lao,<a 0il & Gas Cons. CommissJo~ Anchorage Date: D. We the rell ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfleldCompany September 24, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Telecopy: (907) 276-7542 Kuparuk River Unit 3K-12 ARCO Alaska, Inc. Permit No. 86-165 Sur. Loc. tl0.9'FSL, 316'FWL, Sec.35, T13N, R9E, UM. Btmhole Loc. 1478'FNL, 280'FWL, Sec. 1, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COMMISSION dlf Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA _,IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 I la. Type of work Drill J~, Redrill F-II lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone ~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 69' , PAD 35' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Pool P.O. Box 100360 Anchorage, AK 99510 ADL 25629 ALK 2562 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2o AAC 2s.025) 1109'FSL, 316'FWL, Sec.35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .mber Number l137'FNL, 215'FWL, Sec.1, T12N, R9E, UM 3K-12 #8088-26-27 At total depth 9. Approximate spud date Amount 1478'FNL, 280'FWL, Sec.l, T12N, PgE, UN 10/17/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 7739 'MD 1109' ~ surface feet 3K-11 25'~ surfacefeet 2560 (6931 'TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2650 feet Maximum hole angle 36 0 Maximum surface 2290 psig At totaldepth (TVD) 3460 psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 2b," !6" 62.5# H-~.O Weld 80' 35' 35' !!5' !!5' ±200 cf !2-!/4 9-5/8" 36.0# I_r-,~ BTC ~'q'~' 25' 25' ~a~, ~:' !080 ~x AS / 8-1/2" 7" 26.0# J-55i BTC 7705' 34' )4' 7739' 6931' 200 sx Class G (minimu HF-E W TOC 500' above Top of 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 ~ '. ~ Intermediate Production '."'i2' ~ 7 Liner Perforation depth: measured ~1-,-~Lm 0il & Gas C0.qs. r.,...,~ ~-~ true vertical 20. Attachments Filing fee J~ Property plat [] BOP Sketch ~ Diverter Sketch ~' Drilling program Drilling fluid program ~ Time vs depth plot [] Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements 21.1 hereby certify,,~at the foregoi~g,j~,,,true and correct to the best of my knowledge Signed Title Regional Drilling Engineer Date (/ ~, c/ // -- Commission Use Only (LWK) PD/O04 "/' / I APInumber IApprovaldate I See cover letter Permit Numbe~ ~6--/¢~¢ 50--'big, .%~- 09/24/86 for other requirements Conditions of approval Samples required [] Yes I~ No Mud Icg required [] Yes [] No Hydrogen sulfide measures [] Yes [] No Directional survey required ~Yes [] No Other:Required wor~~. ~' · · [] 5M; [] 10M; [] 15M by order of ~~.~ Approved by Commissioner the commission Date ~) Form 10-401 Rev.'"T2'~-1-85 Sub triplicate PAD 3K; WELL NO, 12 REVISED PROPOSAL KUPARUK..FIELD, .NORTH SLOPE., ALASKA EASTMAN WHIPSTOCK, [NC. 0 .......... SURFACE_ BASE PERPIAFROST TVD=I?21 3000 5000. 6000 7OO0 KOP TVD-2650 THD-2650 DEP-O TOP UGNU SNDS TVD-2694 THD-2694 DEP=! .... BUILD 3 OEO .... PE-Rr' 1'00- -ir? 15 TOP 14 SAK SND.~ TVD-~5334 TPID-3350 DEP-12? 21 K-12 TVD=3664 TPID-:~719 DEP-291 EOC TVD=3764 TPID-3839 DEP-;~59 9 5/8' CSG PT T'V D = 386~4'-'-T~lD= 3963DEP'430 AVERAGE ANGLE 35 DEl3 41 MIN K-5 TVD=S739 THD=6271 DEP=1777 1 000 2000 T/ ZONE D TVD=6354 TMD-7028 DEP-2218 T/ ZONE C TVD-6449 TMD-7145 DEP-2287 T~ ZONE A TVD-6647 TMD-7~89 DEP-2429 TARGET CNTR TVD-6708 TMD-Z464 DEP-2473 B/ KUP SNDS TVD-6769 T~D-7539 DEP-2516 , TD (LOG PT) TVD-6931THD-?739 DEP'2633 I 3000 VERTICAL SECT[ON SURFACE LOCAT ! ON ~ 1109' FSL. 3'16' FWL SEC. 35, T I3N. R9E TD LOCATION' t478' FILL. 280' FWI. SEC. !, TI2#, ReE z HOR I ZONTA,L PBOJECT ! ON SCALE 1 IN. = l OOO FEET ^RCO x PAD!.3K~ WELL N~?'12 REV[SED PROPOSAL KUPARgK_F!E.¢D, NO. TH $[O.p~/~ ALASKA .! EASTHAN WHIPSTOCK. INC. 1000 m 1 000 _ 2000 _ .3,000 _ WEST"EAST 1 000 0 1 000 2000 .3000 TARGET CENTER S 1 0 'DEC' 46 MIN--E 2473' (TO TARGET) ~OUI'N 2429 TARGET LOCATION ~ 1320' FNL. 250' FWL 6EC. I, TI2~I.-ReE- 300 .... 400 500 ' 600. KUPARUK R I VER UN I T 20" D I VERTER SCHEMAT I C DE SC R I PT I ON ~m~ 1. 1~" CONDUCTOR. 2. TANKO STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LONER QUICK-CONNECT ASSY. S. TANKO UPPER QUICK-CONNECT ASSY. 6. 20" 2000 PSI DRILLING SPOOL N/lO" OUTLETS. 7. 10" HCR BALL VALVES N/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 8. 20" 2000 PSI ANNLLAR PREVENTER. 6 ARCO ALASKA, I NC . , REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20 AAC2S. 03S (b) HR I NTENRNCE & OPERAT I ON 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW A I R THROUGH O I VERTER L I NES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF NELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DO~'~NINO DIVERSION. DO NOT SHUT IN NELL UNOER ANY C I RCUMSTRNCES,., RIO 6 DIAGRAM #1 5000 PSI RSRRA BOP STACK I. 16" - 2000 PSI TAhI<CO STARTING HEAD 2. II" - 3000 PSI CASING HEAD 3. I1" - 3000 PSI X 13--5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRILLING SPOOL W/CHOKE ~ KILL LINES 6. 13-5/8' - 5000 PSI ~E RAM W/PIPE RAMS ON TOP, BLIhD RAMS ON BOTTCM. 7. 13-5/8" - 5000 PSI ~ ACCUMULATOR CAPACITY TEST i. CHECK At~) FILL A(~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCL~TOR PRESSURE IS 3000 PSI WITH 1500 PSI D(~TREAM OF THE REGULATOR. 3. CELSERVE TIt~, THEN CLOSE ALL UNITS SINIJLTAI~OUSLY AhD RECORD THE TIt~ AI~D PRESSURE RE]V~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING PL~ OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LC~ LIMIT IS 45 SE(I~ CLOSING TI~ AhO 1200 PSI RE)vtAINING PRESSURE. 5 L 2 13-5/8" BOP STACK TEST I. FILL BOO STACK ~ CH(3~ MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL LOCK DOV~ SCREWS IN WELI_i~ ARE FULLY RETRACTED. SEAT TEST PLUG IN WELLFF_AD WITH RUNNING ,JT AhD RUN IN L~ SCREWS. 3. CLOSE ANqULAR PREVENTER ~ MANUAL KILL A~ CHOKE LINE VALVES ADJACENT TO BOO STACK, ALL OTHER VALVES AhD CHOKES SHOULD BE OPEN. 4. PRESSURE UP TO 250 PSI AhD HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI ~ HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OPEN ~ PREVENTER ~ MANUAL KILL At~D CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AhD HCR VALVES ON KILL AhD CHOKE LINES. 6. TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. '7. CONTINUE TESTING ALL VALVES, LINES, AhD CHOKES WITH A 250 PSI LOW AhD 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRF.e~SUEE TEST ANY CHOKE THAT IS NQT ~ FULL CLOSING POSITIVE SEAL CHOKE. FUNCTION TEST CHOKES THAT DO NOT FULLY CLOSE. 8. OPEN TOP PIPE RAMS ~ CLOSE BOTTCM PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI ~ 3000 PSI. 9. OPEN BOTTCM PIPE RAMS, BACK OUT RUhlqING JT AhD PULL OUT OF HOLE. I0. CLOSE BLINO RAMS AhD TEST TO 250 PSI AND 3000 PSI. I!. OOEN BLIND RAMS AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAt~DPIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOP TO 250 PSI AhD 3000 PSI. 13. RECORD TEST IN=DRMATION ON BLOWOUT PREVENTER TEST FORM, SIGN, AND SF_hD TO DRILLING SUPERVISOR. 14. PERFORM COV~LETE BOPE TEST AFTER NIPPLING UP AND WEEKLY THEREAFTER FUNCTIONALLY OOERATE BOPE DAILY. Oil & G~s Cons. ~'~ '~' -~:.;¢. 510084001 REV. 2 MAY 15, 1985 DRILLING FLUID PROGRAM Density PV YP Viscosity Initial Gel i0 Minute Gel Filtrate API pH % Solids Spud to 9-5/8" Surface Casing 9.6-9.8 15-30 20-40 50-100 5-15 15-30 20 9-10 10_+ Drillout to Weight~ 8.7-9.2 5-15 8-12 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Weight Up to TD 10.3 9-13 8-12 35-45 3-5 5-12 6 9.5-10.5 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. L~5 / in GENERAL DRILLING PROCEDu~ KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. i0. Run and cement 7" casing. Pressure test to 3500 psig. 11. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13, Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. [ PIUD ~ i ,CLEANER STIR STIR CLEANER ~STIRt TYPICAL HUD SYSTEt'I SCHEHATIC LWK4 / ih ,% ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 7, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3K Pad (Wells I - 18) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU1/12 Enclosure If ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany __ ,mi IIII IIII IlL I .... ~, ,,,a,~ , , J .I , II Ill ti Ill : ,r 27, 2~ S.,EGTtO# :~5, T.I$1kL,R. gE.~U ~: A.S.P. No~i'k . ~ ~ ,~ Zone 4 LOCATED IN PROTRAGTED LOCATED IN PROTRACTED SECTION. 35~ T.I~N.~ R. gE.~U.M. SECTION ~5~ T.I~N.~ R. gE.~U.M. ,,.,,o,.,,.. ,,.,.,.o,,, X · 5~,~.14 L~G. 149'45'~.9~" X · 5~,~.7~ L~G. ~49'45'~.~5" 1~' ~, 318' ~ ~" ~.S P~- ~.S ]1~' ~, 316' 4 - Y - 6,~,3S3.~ ~T. 70'~'02.~14" 13 - Y - 6,~,078.~ ~T. X - 5~,~.11 L~G. 149'4S'~.~3' X - 5~,~S.7~ L~G. 149'45'~.~3S" 1359' F~, 3~' ~ ~" ~.7 P~' ~.S 1~' ~, 31&' ~ ~- ~.0 P~" S - T - 6,~,~.~ ~T. 70'~'01.79S~ 14 - Y - i,~,OS3.Ti ~T. 70'2S'S~.0923' 13~' ~, 317' ~ ~- ~.8 P~ ~.S 1~' ~, 31S' ~ ~- ~.0 P~' ~.S 6 - V - 6,~,~3.~ ~T. ~'~'01.S~I' 15 - Y · 6,~,0~.S3 ~T. 70'~'~.~S1' X - S~,~.OS L~G. 149'4S'~.~78" X - 5~,~S.7S ~. 149'45'~.~" 1~' ~, 317' ~ ~- ~.9 P~" ~.S 10~' ~L, 31S' ~ ~- ~.0 P~' ~.S 7 - Y - 6,~,~8.~ ~T. 7~'01.~" 16 - Y ' 6,~,~3.~ ~T. 70'~'~.S~' X ~ S~,~S.~ L~G. 149'45'~.~ X - 5~,~S.78 ~G. ~4~4S'~.9~5' 1~' ~L, 317' ~ ~- ~.0 P~" ~.S 1~9' FSL, 31S' ~ ~- ~.0 P~ - 34.S 8 - Y - 6,~,253.70 ~T. 70'26'01.~' 17 - Y - 6,~7,978.81 ~T. X - S~,~S.~ L~G. 149'45'~.~" X - ~,~S.77 L~G. 1259' ~L, 317' ~- ~.0 P~" ~.S ~5' FSL, 31S' ~ ~- ~.0 P~- ~.S ~ - Y" 6,~,2~.6S ~T. 70'~'~.8124' 18 - V - 6,~7,953.69 ~T. X - 5~,~S.9~ L~G. 149'4S'~.~" X - 5~,~5.73 ~G. 149'45'~.~77" 12~' FSL, 317' ~ ~ - ~.1 P~" ~.S 959' KL, 31S' ~ NOTES I. ALL COORDINATES ARE A.S.R~ZONE4. . ~ALL DISTANCES SHOWN ARE TRUE. ~.HORIZONTAL POSITIONS BASED ON 3K CONTROL MONUMENTS PER bHD & ASSOC. 4. VERTICAL POSITIONS BASED ON 3K TBM No. 4 ~ TBM No. 5 PER LHD E ~SS~. 5.0. G. ELEVATIONS INTE~POLATED FROM S/C DRAWING CED-RIXX-3070 rev.~ B I II M I I II , , ,, , , CER~FICA~ OF SURVEYOR: I HEREBY C~Tl~ THAT I AM PROPERLY REGISTERED AND LICENSED ~ PRACTICE LAND ~RVEYINO IN ~E STATE OF ALASKA ~D THAT ~ TH~S PLAT REPRESENTS A LOCATION SURVEY ~.-'* · MA~ BY ME OR UN~R MY SUPERVISION ~ AND THAT ALL DIMENSIONS AND OTHER DETAILS . r DATE 2 MAY 1986 ~ KUPARUK PROJECT ~-*~-~ DRILL SITE 3K CONDUCTOR " ~lOWO. NO. NSK 86-31 ~ Arcr~ ~uteva~, Suite 20~, AnCho~¢e, Alaska 99503"llsuL~ .OT TO SCALE II I I I k.,,LL.L..,k.,L~.I ,, I. ,..,, .L .L %..;L'~ L.,L.~vi vvl ,I ~1 ) .L L.~.'d.I..L.J.,~ (1) Fee ~}~, ~?'~o 1. Is (2 thru 8) (3) AdnRn (4) Casg (10 and 12. 13. (14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. (5) BOPE (23 .thru 28) (.6) OTI-I~ /~..~,,~. ~- 1~- ?~ (29' thru 31) (6) Add: the permit fee attached .......................................... ~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. ~ 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool ............ ~ 6. Is well to be deviated and is wellbore plat includ<ed ................ 7. Is operator the only affected party ................................. ~ 8. Can permit be approved before fifteen-day wait ...................... j~ Does operator have a bond in force .................................. ~ .. Is a conservation order needed ................ ' ..................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~x~ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is conductor string provided ........................................ ~ Will surface casing protect fresh water zones ....................... ~ Is enough cement used to circulate on conductor and surface ......... ~ " Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. ,~ Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~,~ Is a diverter system required ....................................... Is the drilling fluid program' schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ..~OOo psig .. Does the choke manifold comply w/AP1 RP-53 (May 84) .................. the presence of H2S gas probable exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. Geo log~: Engineering: %qt_LCS .BEW rev: 07/18/86 6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Additional Remarks ~L¢~ - moo" 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. LIS TAPE VERIFICATION LISTING LVP 010.H02 VERIFICATION LISTING PAGE ~ REEL HEADER ~"~ SERVICE NAME :EDIT DATE :86111113 ORIGIN : REEL NAME :149471 CONTINUATION # :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE ~ TAPE HEADER SERVICE NAME :EDIT DATE :86/11/13 ORIGIN :FSIA TAPE NAME CONTINUATION ~ :01 PREVIOUS TAPE : COMMENTS :LIBRARY 'TAPE ~ FILE HEADER FILE NAME :EDIT .OO1 SERVICE NAME : VERSION ~ : DATE : MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE : INFORMATION RECOROS ~ MNEM CONTENTS UNIT TYPE CATE SI ZE CODE CN : ARCO ALASKA, INC. 000 000 018 065 WN : 3K-12 000 000 006 065 FN : KUPARUK 000 000 008 065 RANG: gE 000 000 002 065 TOWN: 13N 000 000 004 065 SECT: IT 000 000 002 065 COUN: NORTH SLOPE 000 000 012 065, STAT: ALASKA 000 000 006 065 MNEM CONTENTS UNiT TYPE CATE SIZE CODE PRES: E 000 000 001 065 -,..,. COMMENTS '"'" ....... ,. ...... ., ....... .,.,. . o .~. .......... , .-. , ........ ,..,... ,. .. .. ~,..~....,.~,...~:.-.:..~: .:.~.-,L-~k-'--'-u-.,~--'~ ' ~ ;.,: ...... ~`~;~`~`~``~`~`~*`:~.`:~*`~`~`~.`~*`~`~`~`~~``4~*`~`~;~`~``~`;~`~k~~ , ,,.~.,. . ,., ~, ~ ~ ~ .,..,..~.,.... ~ .,. ~:;~,~., 'LVP OlO.H02 VERIFICATION LISTING PAGE Z -,-"' S C Hi L U M B E R G E R '~-.- -,- A:LASKA COMPUTING CENTER '~ COMPANY = ARCO ~LASK~ INC WELL : 3K-12 FIELD : KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER AT AC~C: 72055 RUN #ONE~ DATE LOGGED: I1 NOV 86 LOP: T HALSTEAD CASING : 9.625" @ 3OTB~'' - BIT' SIZE : TYPE FLUID = LSND POLYMER 'DENSITY : 10.0 LB/G RM = 2,,700 @ 74 DF VISCOSITY : 38.0 S RMF = 3.170 @ 74 DF P H : 9°5 RMC : 2.280 @ 74 DF ~LUID LOSS = 4.8 C~ RM AT 'BHT : I.~68 ~ 142 DF M~TRIX S~NDS'TONE ~:~ THIS DA'T~ HAS NOT BEEN DEPTH SHIFTED OVERLAYS FIELD PRINT.S~'""~'~x~.,-~,-,- LVP O1D.HO2 VERIFI.CATION LISTING PAGE 3 SCHLUMBERGER L'OGS INCLUDED WITH THIS MAGNETIC TAPE: DU~AL INDUCTION SPHERIC/~LLY FOCUSED LOG (OIL) DATA AVAILABLE: 7767' TD 3~80' FORMATION DENSITY COMPENSATED LOG (FDN) COMPENSATED NEU~TRON ~OG (FDN) D~TA AVAILABLE: TT4~' TO TIO'O ~ GAMMA R~Y IN .C~SING (GR.CNL) DATA AVAILABLE: 3980' TO 1000~ .,.~. DATA FORMAT RECORD X:~ ENTRY BLOCKS' TYPE SIZE REPR CODE ENTRY 2 1 66 0 ~+ 1 66 1 ~ 4 73 60 9 4 65 .liN 16 1 66 1 0 1 66 0 D&TUM SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT AP1 AP1 AP1 4PI FILE SIZE SPL REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. CODE (OCTAL) DEPT FT O0 000 DO 0 0 4 1 68 O000000OO00000 SFLU OIL OHMM O0 220 O! 0 0 4 i 68 00000000000000 ILO OIL DHMM O0 120 46 0 0 4 1 68 00000000000000 ILM OIL OHMM O0 120 44 0 0 4 ! 68 00000000000000 SP OIL MV O0 010 O! 0 0 4 1 68 00000000000000 GR OIL GAPI O0 310 O~ 0 0 4 1 68 00000000000000 LVP OlO.H02 VERIFICATION LISTING PAGE 4 GR FDN GAPI O0 CALI FON IN O0 RH05 FON G/C3 O0 ORHO FDN G/C3 O0 NRAT FON O0 RNRA FDN O0 NPHI FDN PU O0 DPHI FON PU O0 NCNL FDN CPS O0 FCNL FDN CPS O0 GR CNL GAPI O0 310 280 35O 356 420 O00 890 890 330 330 3 ! 0 0I 01 02 O1 O1 O0 O0 00 31 30 O1 DATA DEPT 7793.0~000 SFLU' SP -97.4375 GR RHOB 2.4512 DRHO NPHI 32.7637 DPHI GR -999.2500 DEPT 7700.0000 SFLU SP -48.6250 GR RHOB 2.5430 DRHO NPHI 35.1552 DPH[ GR -999.2500 DEPT 7600.0000 SFLU SP -59.7813 GR RHOB 2.4766 DRHD NPH[ 36.7188 DPH[ GR -999.2500 DEPT 7500.0000 SFLU SP -77.2500 GR RHOB 2.4297 DRHO NPHI 30.8105 DPHI GR -999.2500 DEPT 7400.0000 SFLU SP -79.3125 GR RHOB 2.4746 DRHO NPHI 33.8379 DPHI GR -999.2500 DEPT 7300.0000 SFLU SP -80.6875 GR RHOB 2.5039 DRHO NPHI 32.0313 DPHI GR -999.2500 DEPT 7200.0000 SFLU SP -80.3125 GR RHOB 2.5391 DRHO 3.4528 85.7500 0 · 1108 12.0590 3.3687 95.5625 0.1177 6.4961 3.9560 87.0000 0.1274 10. 5203 6.6152 67.2500 0.0313 13. 3609 5.6366 82.3125 0.0654 10.5387 2.7576 86.5000 0.0938 8.8633 6.9967 102.8125 0.1655 0 0 0 0 0 0 0 0 0 0 0 !LD GR NRAT NCNL tLD GR NRAT NCNL ILD GR NRAT NCNL ILD GR NRAT NCNL ILO GR NRAT NCNL ILD GR NRAT NCNL ILD GR NRAT 4 4 4 4 4 4 4 4 4 4 4 2.6453 85.7500 2.8548 2226.0000 2.5542 95.5625 3.0547 2042.0000 3.2309 87.OO00 3.1230 1761.0000 5.045! 67.2500 2.8085 2162.0000 4.6761 82.3125 3.0234 2238.0000 2.6445 86.5000 2.9238 2264.0000 3.0744 102.8125 2.8125 68 00000000 ,68 00000000 68 00000000 68 00000000 68 000'00000 68 00'000000 68 00000000 68 00000000 68 00000000 68 00000000 68 00000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ILM CALl RNRA FCNL 2.9277 8.0156 3.1230 712.5000 ILM CALI RNRA FCNL 2.7494 8.4297 3.3906 602.0000 ILM C ALI RNR A FCNL 3.2358 8.2109 3.4414 511.5000 iLM CALI RNRA FCNL 5.4358 8.6797 2.9551 731.5000 ILM CALI RNRA FCNL 4.7101 8.9062 3.1992 699.5000 ILM CALI RNRA FCNL 2.7557 9.0938 3.1387 721.0000 ILM CALI RNRA 3.2204 9.0000 3.1602 ~VP OlO.H02 VERIFICATION LISTING PAGE 4PHI 3R DEPT SP RHOB 4PHI DEPT SP RHOB NPHI GR DEPT SP RHDB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR OEPT SP RHOB NPHI GR DEPT SP NPHI GR DEPT SP RH05 30.4688 DPHI .-999.2500 7100.0000 SFLU -80.1250 GR 2.4277 DRHO 47.607~ DPHI -999.2500 7000.0000 SFLU -76.7500 GR -999.2500 DRHO -999.2500 DPHI -999.2500 6900,0000 SFLU -82,0625 GR -999,2500 DRHO -999,2500 DPHI -999,2500 6800.0000 SFLU -79,6250 GR -999,2:500 DRHO -999,2500 DPHI -999,2500 6?00,0000 SFLU -66.1250 GR -999,2500 DRHO -999.2500 DPHI -999.2500 6600.0000 SFLU -69.t250 GR -999.2500 DRHD -999.2500 DPHI -999.2500 6500.0000 SFLU -67.1250 GR -999.2500 DRHO -999.2500 DPHI -'999.2500 6400.0000 SFLU -72.3750 GR -999.2500 DRHD -999.2500 DPHI -999.2500 6300.0000 SFLU -73.5625 GR -999.2500 DRH~ 6.7328 NCN'L 2,1440 ILO 117.0625 GR 0,0908 NRAT 13.4793 NCNL 3,1408 ILO 104,8125 GR -999,2500 NRAT -999, 2500 NCNL 2.1777 ILD 112. 8750 GR -999. 2500 NRAT ,-999.2500 NCNL 2. 9983 ILD 1 $ 5 · 7500 G R -999.2500 NR'AT -9'99. 250'0 NCNL 1,8169 ILD 10Z, 3750 GR -999,2500 NRAT -999,2500 NCNL 3.1710 ILD 123.7500 GR -999.2500 NRAT -999.2500 NCNL 1.9234 ILD 119.8125 GR -999,2500 NRAT -99'9,2500 NCNL 2.2875 ILD 98.7500 GR -999.2500 NRAT -999.2500 NCNL 2.2910 ILD 72.7500 GR -999.2500 NR4T 2023.0000 1.5378 117.0625 3.7559 1803.0000 1.7849 -999.2500 -999.2500 -999.2500 1.8160 -999.2500 -999.2500 -999.2500 2.4093 -999.2500 -999.2500 -999.2500 1.9846 -999.25~00 -999.2500 -999.2500 2.7290 -999.2500 -999.2500 -999.2500 2.7582 -999.2500 -999.2500 -999.2500 2.1961 -999.2500 -999.2500 -999.2500 2.0271 -999.2500 -999..2500 FCNL ILM C~LI RNR~ FCNL ILM CALl RNRA FCNL ILM CALI RNRA F CNL ILM CALI R:NR~. FCNL ILM C-&LI RNRA FCNL I LM CALI RNRA FCNL ILM C~LI RNRA FCNL ILM CALl RNR~ FCNL ILM C~LI RNRA 640.0000 1,5989 8.6875 4.0547 444.2.500 1.8380~ -999.,2500 -999,2500 -999,2500 1.B823 -999.2500 -999.2500 -999.2500 2.4688 -999,2500 -9'99. 2500 -999.2500 1.9044 -999.2500 -999.2500 -999.2500 2.8162 -999.250.0 -999.2500 -999.2500 2.4490 -999.2500 -999.2500 -999.2500 2.2400 -999.250~ 999.250 -ggg.2500 2.0163 -999.2500 -999.2500 LVP OIO.H02 VERIFiCATiON LISTING PAGE 6 NPHI GR DEPT SP RHOB NPHi GR OEPT SP R HOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR OEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP -999.2500 DPHI -999,2500 6200,0000 SFLU -76.5625 GR -999,2500 DRHO -999.2500 DPHI -999.2500 6100,0000 SFLU -76,1875 GR -999,2500 DRHO -999,2500 DPHI -999.2500 6000,0000 SFLU -77.8750 GR -999,2500 ORHO -999,2500 DPHI -999,2500 5900,0000 SFLU -81,0625 GR -999,2500 DRHO -999,2500 DPHI -999.2500 5800,0000 SFLU -74,9375 GR -999,2500 DRHO -999,2500 DPHI -999,2500 5700,0000 SFLU -72,5000 GR -999,2500 DRHO -999.2500 DPHI -999.2500 5600,0000 SFLU -72.6875 GR -999,2500 DRHO -999.2500 DPHI -999.2500 5500.0000 SFLU -71.3125 GR -999.2500 DRHO -999.2500 DPHI -999.2500 5400.0000 SFLU -66.9375 GR -999.2500 DRHO -9'99.2500 NCNL 1,9'963 ILO 81.4375 GR -999.2500 NRAT .-999.2500 NCNL 3, 1096 ILD 105.t875 GR -999 .. 2500 N R A T -999. 2500 NCNL 3.3031 ILO 108,0625 GR -999,2500 NRAT -999.2500 NCNL 2,9045 ILO 93,2500 GR -9'99,2500 NRAT -999,2500 NCNL 2.3564 ILO 97.6875 GR -999.2500 NRAT -999.2500 NCNL 3,2597 ILD 107,6875 GR -999,2500 NRAT -999,2500 NCNL 3.4730 ILD 96,0000 GR -999,2500 NRAT -999.2500 NCNL 3.1145 ILO 96.2500 GR -999.2500 NRAT -999,2500 NCNL 2.7939 ILD 97.5625 GR -999.2500 NRAT -999.2500 1.9113 -999.2500 -999,2500 -999,2500 2.9697 -999.2500 -999.2500 -999.2500 2,8696 -999.2500 -999,2500 -999,2500 2.7460 -999.2500 -999.2500 -999.2500 2,2142 -999.2500 -999.2500 -999.2500 3.0901 -999,2500 -999,2500 -999,2500 3.1428 -999.2500 -999.2500 -999.2500 2,9862 -999,2500 -999,2500 -999,2500 2.5762 -999.2500 -999,2500 FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL 'ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALi RNRA -999.2500 1.9567 -999.2500 -999.2500 -999.2500 2.9893 -999.2500 -999.2500 -999.2500 2,9119 -999.2500 -999.2500 -999.2500 2.8587 -999.2500 -999.2500 -999'2500 2.2414 -999.2500 -999.2500 -999.2500 3.1140 -999.2500 -999.2500 -999.2500 3.1948 -999.2500 -999.2500 -999.2500 2.9984 -999.2500 -999.2500 -999.2500 2.6297 -999.2500 -999.2500 L'VP OlO.H02 VERIFICATION LISTING PAGE ? NPHI DEPT SP RHOB NPHI DEPT SP RHOB NPHI GR DEPT SP RHOB NPHI GR DEPT SP RHDB NPHI GR DEPT SP RHO8 NPHI GR DEPT SP RHOB NPHI GR OEPT SP RHDB NPHI GR DEPT SP RHOB NPHI GR DEPT SP -999.2500 DPHI -999,2500 5300.0000 SFLU -66.3125 GR -999.2500 ORHO -999.2500 DPHI -999.2500 5200.0000 SFLU -67.6250 GR -999.2500 DRHO -999.2500 DPHI -999.2.500 5100.000'0 SFLU -66.2500 GR ,-999.2500 DRHO -999.2500 DPHI -999.2500 5000.0000 SFLU -70.4375 GR -999.2500 DRHO -999.2500 DPHI -999.2500 4900-0000 SFLU -70,3750 GR -999,2500 ORHO -999,2500 DPHI -999.2500 4800.01000 SFLU -71.7500 GR -999.2500 DRHO -999.2500 DPHI -999.2500 4700.0000 SFLU -71.5000 GR -999.2500 DRHO -999.2500 DPHI -9'99.2500 4600.0000 SFLU -71.6875 GR -999.2500 DRHO -999.2500 DPHI -999,2500 4500.0000 SFLU -71.6250 GR -999.2500 DRHO -999.2500 NCNL 2.7099 ILD 101.8125 GR -999.2500 NRfiT -999.2500 NCNL 3,3478 ILO 93.6875 GR -999.2500 NRAT -999,2500 NC'NL 3.6101 ILD 89.1250 GR -999.2500 NRAT ,-999.2500 NCNL 3.5413 ILO 87.1250 GR -999.2500 NRAT -999.2500 NCNL 3,28.49 ILD 94.:9375 GR -999.2500 NRAT -999,2500 NCNL 2.8708 ILD 83.1250 GR -999,2500 NRAT -999.250.0 NCNL 3.1795 ILO 94.5000 GR -999.2500 NR~T -999.2500 NCNL 3.0647 ILO 94.9375 GR -999.2500 NR~T -999.2500 NCNL 2.6412 ILD 83.3125 GR -999.2500 NRAT -999.2500 2.5425 -999.2500 -999.2500 -999.2500 3.3725 -999.2500 -999.2500 -999.2500 3.7105 -999.2500 -999.2500 -999.2500 3,3204 -999.2500 -~99.2500 -999.2500 3.2376 -999.2500 -999.2500 -999.2500 2.8300 -999.2500 -999.2500 -999,2500 3.1308 -999.2500 -999.2500 -999.2500 2.5798 -999.2500 -999.2500 -999.2500 0.9666 -999.2500 -999.2500 FCNL ILM CALI RNRA FCNL ILM CALI R NRA FCNL I LM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM RNRA FCNL ILM CALI RNRA FCNL ILM C,6LI RNRA -999.2500 2.5589 -999.2500 -999.2500 '-999.2500 3,3527 -999.2500 -999.2500 '-999.2500 3.5765 -999.2500 -999.2500 -999.2500 3.3704 -999.2500 -999.2500 -999.2500 3.2416 -999.2500 -999.2500 -999.2500 2.7943 -999.2500 -999.2500 -999.2500 3.0830 -999.2500 -999.2500 -999.2500 2.5300 -999.2500 -999.2500 -999.2500 1.0612 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE NPHI -999.2500 DPHi GR -999.2500 DEPT 4400.0000 SFLU SP -'72.5625 GR RHOB -999.2500 DRHO NPHI -999..2500 DPHI GR -999.2500 DEPT 4300.00'00 SFLU' SP -75.0000 GR RHOB -999.2500 DRHO NPHI -999.2500 OPNI GR -999.2500 OEPT 4200.0000 SFLU SP -73.1250 GR RHOB -999.2500 DRHO NPHI -999.2500 DPHI GR -999.2500 DEPT 4100.0000 SFLU SP -77.8125 GR RHOB -999.2500 ORHD NPHI -999.2500 DPHI GR -999.2500 DEPT 4000.0000 sFLu SP -78.4375 GR RHOB -999.2500 DRHO NPHI -999.2500 DPHI GR 68.6875 DEPT 3900.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO NPHi -999.2500 DPMI GR 49.5938 gEPT 3800.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHD NPHI -999.2500 DPHI GR 55.2813 DEPT 3700.0000 SFLU SP -999.2500 GR RHDB -999.2500 DRHD NPHI -999.2500 DPHI GR 46.2500 OEPT 3600.0000 SFLU SP -999.2500 GR RHOB -999.2500 DRHO -999.2500 NCNL 3.t897 ILD 76.8750 GR -999.2500 NRAT -999.2500 NCNL 3.3591 ILD 75.8750 GR -999.2500 NRAT -999.2500 NCNL 3.3516 ILD 73.4375 GR -999.2500 NRAT -999.2500 NCNL 3.2849 ILD 89.6250 GR -999.2500 NRAT .-99'9.2500 N.CNL 3.4689 ILO 82.0000 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 iLD -999.2500 GR -999.2500 NR4T -999.2500 2.8273 -999.2500 -999.2500 -999.2500 3.8811 -999.2500 -999.2500 -999.2500 3.4104 -999.2500 -999.2500 -999.2500 3.2782 -999.2500 -999.2500 -999.2500 3.5739 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL I~LM CALI' RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNR& FCNL ILM C4LI RNRA FCNL ILM CALI RNRA -999.2500 2.9119 -999.2500 -999.2500 -999'2500 3.9338 -999.2500 -999.2500 -999.2500 3.2828 -999.2500 -999.2500 -999.2500 3. 3128 -999.2500 -999. 2500 -999.2500 3.3662 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.H02 VERIFICATION LISTING PAGE 9 NPHI GR DEPT SP RHO8 NPMI GR DEPT SP RHOB NPHI GR OEPT SP RHOB NPHI GR DEPT SP NPHI GR DEPT SP RHOB NPHI GR DEPT SP RH06 NPHI GR OEPT SP RHOB NPHI GR DEPT SP RHOB NPHI uR DEPT SP RHOB -999.2500 DPHI 47. 61875 3500:.0000 SFLU -999.2500 GR · -999.2500 DRHO -999.2500 DPHI 40.3438 3400-0000 SF'LU -999.2:500 GR -999.2500 DR~O -999.2500 DPHi 42.0938 3300.:0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 35.8125 3200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 OPHI 38.6875 3100.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 41.5000 3000.0000 SFLU -999.2500 GR -999.2500 DRHD -999.2500 OPHI 29.g844 2900.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 33.3438 2800.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 24.6875 2700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 :NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO · -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 -999.2500 -999.2500 -999.2500 -9'99.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -ggg.2500 -999.2500 -999.2500 FCNL' ILM CALI RNRA FCNL ILM CALl RNRA FCNL I LM CALI R NRA FCNL ILM CALl RNRA FCNL ILM C.ALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 - 999.25 0 0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -ggg.2500 -999.2500 -999.2500 -999.2500 -999.2500 LVP OlO.HO2 VERIFICATION LISTING PAGE 10 NPHI -999, 2500 DPHZ ER 35-5625 DEPT 2600,00:00 .SFLU SP -999,2500 GR RHOB -999.2500 DRHO NPHi --999,2500 DPHI GR 42.18T5 DEPT 2500,0000 SFLU SP -999.2500 GR RHOB -999,2500 DRHD NPHI -999.2500 DPHI GR 31,8281 DEPT 2400,0000 SFLU SP -999,2500 GR RHO8 -999.2500 ORHO NPHI -999.2500 DiPHI GR 31,9219 DEPT 2300,0000 SFL~U SP -999,2500 GR RHOB -999,2500 DRHO ~PHI -999.2500 DPHI GR ~1.593B DEPT 2200,0000 SFLU SP -999,2500 GR RHOB -999,2500 DRHD NPHI -999. 2500 DPHI GR DEPT 2100,0000 SFLU SP -999,2500 GR RHOB -999,2500 DRHD NPHI '-999.2500 DPHI DEPT 2000,0000 SFLU SP -999.2500 GR RHOB -999,2500 DRHO NPHI -999.2500 DPHI GR 31.375.0 DEPT lgO0.O000 SFLU SP -999.2500 GR RHDB -999.2500 DRHD NPHI -999.2500 DPHI GR 43.8125 DEPT 1800.0000 SFLU SP -999.2500 GR RHOB -999,2500 DRHO -ggg. 2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO ,-999.2500 GR -999.2500 NRAT -999.250i0 NCNL -999.2500 ILO -999.2500 .GR -999.2500 NRAT -999.2500 NCNL -999,2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999,2500 ILD -999.2500 GR -999.2500 NRAT -999,2500 NCNL -999,2500 ILD -999,2500 GR -999,2500 NRAT -999,2500 -999.2500 -999.2500 -999.25,00 -999.2500 -999.2500 -999.2500 -999.2500 -999.250!0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -9~9.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999,25O0 FCNL ILM CALI RNRA FCNL ILM CALI. RNRA FCNL ILM CALI RNRA FCN[. ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNR~ -999,2500 -999,2500 -999,.2500-999.2500 ,-999.2500 -999.2500 -999.2500 -999.2500 -999-25100 -999.2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 .VP OIO-HOZ VERIFICATION LISTING PAGE QPHI ~R )EPT ~P 4P HI ~R ]EPT SP RHOB qPHI DEPT SP RHOB qPHI ~R DEPT SP RHOB NPHI SR DEPT SP RHOB NPHI DE .PT SP RHOB NPHI GR OEPT SP RHOS NPHI GR DEPT SP RHOB NPHI GR DEPT SP -999,2500 OPHI 30'2500 1700.0000 SFLU -999.2500 GR · -999.2500 DRHO. -999.2500 DPHI 48.8750 1600.0000 SFLU -999.2500 GR -999.2500 DRHO -999'2500 OPHI 24.968? 1500.0000 SFLU -999.2500 GR -999.2500 DRHO -999,2500 OPHI 38.3125 1400,0000 SFLU -999,2500 GR -999,2500 DRHO .-999,2500 DPHI 26.7188 1300,0000 SFLU -999,2500 GR -999,2500 DRHD -999.2500 DPHI 43.3438 1ZO0.O000 SFLU -999.2500 .GR -999.2500 DRHD -999.2500 DPHi 26.9375 1100.0000 SFLU -999,2500 GR -999.2500 DRHO -999,2500 DPHI 38.6875 1000.0000 SFLU -999.2500 GR -999,2500 DRHO -999,2500 DPHI 53,8750 996.5000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 NCNL -999,2500 ILO -999,2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999,250!0 GR -999,2500 NRAT -999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999,2500 NRAT -999.2500 NCNL -999.2500 ILO -999-2500 GR -999,2500 NRAT -999,2500 NCNL -999,2500 ILD -999,2500 GR -'999,2500 NRAT -999,25010 NCNL -999.2500 ILD -999.2500 GR -999,2500 NRAT -999.2500 NCNL -999.2500 -999,2500 GR -999.2500 NR~T -999,2500 NCNL -999.2500 ILO -999.2500 GR -999..2500 NRAT -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,250.0 -999.2500 -999-2500 -999.2500 -999.2500 -999,2500 -999,2500 -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 FCNL ILM CALI RNRA FCNL ILM CALI RNRA F CNL ILM C A L I RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNR~ FCNL ILM CALl RNR4 FCNL ILM C~LI RNRA -999.2500 -999,2500 -999,2500 -999,25:00 -999,25'00 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 VP 010.HOZ VERIFI~%~IDN LISTING PAGE 12 PHI -599o2500 DPHI R 49.4375 -999.2500 N:CNL .~;~ FILE TRAILER ~ :ILE NAME :EDIT .001 ;ERVICE NAME : FERSION ~ : )ATE : ~AXIMUM LENGTH : 1D24 :ILE TYPE : 4EXT FILE NAME : ~ TAPE TRAILER ~ ~ERVICE NAME :EDIT )ATE :86/11/13 )RtGIN :FS1A FAPE NAME : ~ONTINUATIDN ~ :O1 ~EXT TAPE NAME : :OMMENTS :LIBRARY TAPE ~ REEL TRAILER ~'~' SERVICE NAME :EOIT ]ATE :86/~1/13 ]RIG[N : ~EEL'NAME :149471 :ONTINUATION # :01 4EXT REEL NAME : 'OMMENTS :LIBRARY TAPE -999.2500 FCNL -999.2500