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189-035
RECEIVED. • vtok,-05 OCT 192017 WELL LOG TRANSMITTAL# AG 7-riNe To: Alaska Oil and Gas Conservation Comm. September 29, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 i..0:GSD Anchorage, Alaska 99501 0,21,�;;1-� RE: Multi Finger Caliper : 3I-11 Run Date: 8/31/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3I-11 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21932-01 Multi Finger Caliper (Field Log) 1 color log, ea. 50-029-21932-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED Office: 907-273-3527 FRS_ANC@halliburton.com Date: Signed: , A.4 22-ucs-iok, Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN ^ Color items -Pages: ^ Grayscale, halftones, pictures, graphs, charts - Pages: ^ Poor Quality Original -Pages: ^ Other -Pages: DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type OVERSIZED ^ Logs of various kinds ^ Other COMMENTS: ~~ ~~; ch `~ Scanned by: Beverly Bre in Nathan Lowell ^ TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: /s/ !s/ NOTScanned.wpd WELL HISTORY FILE COVER PAGE XHVZS This page identifies oversize material and digital information available for this individual Well History file and weather or not it is available in the LaserFiche file. Please insure that it remains as the first page in this file. / /i"I' ~ ~.çell History File # Digital Data Added to LaserFiche File 0 CD's - # - 0 DVD's - # - 0 Diskettes - # - 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No Oversized Material Added to LaserFiche File 0 Maps # 0 Mud Logs # - 0 Other # 0 Yes 0 No 0 Yes 0 No 0 Yes 0 No General Notes or Comments about this file. If any of the information listed above is not available in the LaserFiche file you may contact the Alaska Oil & Gas Conservation Commission to request copies. Please call Robin Deason at (907) 793-1225 if you have any questions or information requests regarding this file. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 25, 2010 RE: Plug Setting Record: 3I-11 Run Date: 6/22/2010 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 3I-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21932-00 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 Fax: 907- . - rafael.b ;. ~ ~c ~ ~i i ~, ~ '' Date: ~` ~~~ a35 ~ ~ ~a~ Signed: WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 3I-11 Run Date: 6/11/2010 June 25, 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 3I-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21932-00 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 Fax: 907-273 rafael.barreto ~ ~ F ~~,,~ Date: I ~ -~3~ s /~ Signed: ~ /~--- • • Jill Long ConocoPhilh ps Alaska, Inc. .~~'"~ ~~~}"' ~ ~ ~~~~`~ P.O. Box 100360 Anchorage, AK 99510 f ~3 ~~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 3I-11 Sundry Number: 310-178 Dear Ms. Long: 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, Daniel T. Seamount, Jr. /~ Chair DATED this ~ ~ day of June, 2010. Encl. ~"L~~~ ALAS (LAND GAS CONSERVA ON COMMISSI APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ~"; Rug for Redrill ~~~ Perforate New Pool ~`"` Repair well I~ I~ ,~ Change Approved Program " Sus end p ~ Rug Perforations ~ • Perforate Full Tubing "", Time Extension Operational Shutdow n Re-enter Susp. Well ~'~` Stimulate ~ After casing ~ Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~' , Exploratory 189-035 3. Address: Stratigraphic I°"` Service ~"` 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21932-00 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 No 31-11 9. Property Designation: 10. Field/Pool(s): ADL 25631 Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (n): Effective Depth ND (ft): Plugs (measured): Junk (measured): 6772 6560 6680' 6473' Casing Length Size MD ND Burst Collapse CONDUCTOR g0 16 116' 116' SURFACE 3348 9.625 3383' 3383' PRODUCTION 6728 7 6761' 6550' Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6437'-6454', 6457'-6486', 6494'-6503' 6245'-6261', 6264'-6291', 6298'-6306' 3.5 L-80 6437 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER -BAKER 84-SAB-40X32 RETAINER PROD. PACKER MD= 6146 ND= 5977 PACKER -BAKER 85-40 'F1' PERMANENT PRODUCTION PACKE MD= 6422 ND= 6231 SAFETY VLV - Camco 3 1/2" x 2.813"'X' ProTile TRMAXX-SE SCSSV MD= 2212 ND= 2212 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch 1- Exploratory '" Development ~` Service J"" 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/22/2010 Oil "' Gas WDSPL I~ Suspended 16. Verbal Approval: Date: WINJ J"' 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: Jill Long @ 263-4093 Printed Name JIII Lonq Title: e r Wells Engine ~ ~ ff l1 /,, V tlJ / D t Phone: 263-4093 Signature a e C i n Sundry Number: ~ ~ 0 .~'~g Conditions of approval: Notify Commission so that a representative may witness Plug Integrity "" BOP Test ~` Mechanical Integrity Test ~" Location Clearance J~ ~OP Se '~ 7~ SCl~U ~~V~~ !/ ~® ~ / Other: ~ ~,SDo ~, sc; ~n ~ ~c Ts'f" ~c~.~.r..~ J U N ~ 121310 Subsequent Form Required: ~~ _ YD ~ Alask a Oil ~ i~as Cons. CommiS510 AI1CIlOf APPROVED BY MMISSION `~ ~ ~ 0 D t Approved by: COMMISSION THE CO e: a Form 10-403 Revised 1/2010 ~ ~ C•/C/o Submit in Duplicat~~~ ~L, • • Sundry Application for Plugging Perforations ' KRU 31-11 and 31-11 L1 Objective The attached Sundry application requests permission to plug the perforations in the 31-11 and 31-11 L1 wellbores. The plugging is planned in conjunction with the drilling of three, A-sand. CTD sidetracks described below. Well History Well 31-11 was originally drilled and completed as an A-sand producing, single completion well in 1989 with 2- . 7/8" tubing. A workover was performed in May 2009 to replace leaking tubing. At that time the well had already been identified as a CTD candidate so the tubing was upsized from 2-7/8" to 3-1/2" and a subsurface safety valve (SSSV) was installed in preparation for the sidetracks. The original objective of the CTD sidetracks was to drill three lateral sidetracks out of the 31-11 parent wellbore targeting. the A1, A2 and A3 sands to access reserves from currently undrained areas to the south. The laterals were planned and permitted as 31-11 L1 (PTD# 209-1210), 31-11 L1-01 (PTD# 209-1220), and 31-11 L1-02 (PTD# 209-1230) because the perforations in the parent wellbore were going to remain open to production. Nabors CDR2 rigged up on 31-11 in January 2010 and began drilling operations. Unfortunately, after drilling the 31-11 L1 lateral and partially lining what had been drilled, the window became inaccessible. Drilling operations were suspended on February 13, 2010, to diagnose the problem with the window and acquire additional 13.1 ppg potassium formate .completion fluid. Laterals 31-11 L1-01 (PTD# 209-1220) and 31-11 L1-02 (PTD# 209- 1230) were neither drilled or completed prior to rig release. Post-rig diagnostics confirmed the whipstock had . released and moved downhole. After completing diagnostics on the window, 31-11 L1 was opened to flow to tanks in an attempt to bring the well pressure down before returning with the rig again. Initial production tests had 850 BLPD at 62.4% WC, 21.5 API, 0.75% solids at 950 WHP. As drawdown on the well was increased, the openhole lateral eventually collapsed and the tubing filled with solids. A fill cleanout was performed in April 2010 and the well has remained shut-in since then. Plan Forward The plan forward for this well is to set a plug in the 3-1/2" tubing above the previously drilled window prior to attempting the CTD sidetracks again. This will isolate the 31-11 parent wellbore perforations in addition to the 31- 11 L1 lateral and prevent solids production which could potentially plug the tubing again and prohibit production from the new sidetracked laterals. A whipstock will also be set pre-rig. Once the CTD rig arrives, a dual string window (3-1/2" x 7") will be milled from which the three lateral sidetracks will then be drilled. The laterals will be named and permitted as 31-11A, 31-11AL1, and 31-11AL2. (~~Lv!: ~~/r~ Page 1 of 2 6/11/2010. SundrvApplication for PI Operational Outline Perforations ~RU 31-11 and 31-11 L1 Pre-Rig Work Remaining 1. Tag fill and obtain a SBHP survey 2. Set a cast iron bridge plug in the 3.5" tubing at 6406' 3. Seta 3.5" monobore whipstock at 6397' 4. Prepare wellsite for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. ;P£~ 2. 31-11A Lateral (A2 Sand) a. Mill 2.80" 2-string window with high-side orientation at 6397' MD b. Drill 2.70" x 3" bi-center lateral in the A2 sand ~ P'('D c. Load well with kill weight fluid. Run 23/" slotted liner with an aluminum liner-top billet ~ 3. 31-11AL1 Lateral (A1 Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi-center lateral in the Al sand c. Load well with kill weight fluid. Run 2~/" slotted liner with an aluminum liner-top billet 4. 31-11AL2 Lateral (A3 Sand) a. Kick off of the aluminum billet b. Drill 2.70" x 3" bi-center lateral in the A3 sand c. Load well with kill weight fluid. Run 23/" slotted liner from TD up to 6385' MD, inside the 3'/" tubing 5. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Post-Rig Work 1. Obtain SBHP 2. Flowback for well cleanup 3. Begin production Page 2 of 2 6/11/2010 `/ • Conoco~illips l P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 11, 2010 Commissioner- State of Alaska Alaska Oil 8~ Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: L~ RECE~L~E® Alaska 4if ~ teas Cons, Commission Anchorage ConocoPhillips Alaska, Inc. hereby submits sundries to plug the Kuparuk A-sand perforations in the following wellbores: ~! 31-11 (PTD# 189-035) - 31-11 L1 (PTD# 209-1210) These reservoir perforations will be isolated utilizing a cast iron bridge plug. The plugging is being performed as /" part of the pre-rig preparation for upcoming coiled tubing drilling (CTD) operations. The isolation work is scheduled to take place in late June 2010 followed by arrival of the CTD rig (Nabors CDR2) in mid-July 2010. The CTD objective will be to drill three A-sand lateral producers from the 31-11 parent wellbore (31-11A, 31-11AL1, and 31-11AL2) targeting unswept reserves in the A2, A1, and A3 sands respectively that are currently isolated by faulting. Permit to Drill applications for those laterals have been submitted separately. Attached to this Sundry application is an outline of previous and future job operations planned for 31-11. If you have any questions or require additional information please contact me at my office 907-263-4093 or on my cell phone 907-230-7550. Sincerely, C; C~Q~Q.. ~j Jill Long ~-~ Coiled Tubing Drilling Engineer Page 1 of 1 ~~ Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected Prom: Davies, Stephen F (DOA) Sent: Monday, February 08, 201010:52 AM To: Foerster, Catherine P (DOA}; McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA}; Hubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRi3) Type Work Code in RBDMS 1. 1,Nhen a Form 10-403 is submitted requesting approval to plug a well for redrill, the initial reviewer {Art or Steve D. j wil9 check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. if the "Abandon" box is checked, we L1~iil cross that erroneous entry out and initial it an both copies of the Form 10-403 {AOGCC's and operator's copies). 2. On the Form 10-403 if "Abandon" is checked in Box 15 {Weil Status after proposed work), Art or Steve D. will cross that erroneous entry out and initia! it on both copies of the Form 10-403 {AOGCC's and operator's copies;. Instead, we will check the "Suspended" box. Guy and Winton wriil serve as quality control for steps 1 and 2. 3. When Steve iVlcMains receives the Form 10-403 with a check ir: the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "intent: Plug for Redrill" cede, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve 4vi!! also change the status on the 10-407 form to SUSPENDED, and dvill date and initia! his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he wil! enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status ftom suspended to abandoned. 0. The first week of every January and July, Steve i~. and Steve D. will check the "Wei! by Type Work Gutstanding"' user query in RBDMS to ensure that all of the Plug for Redrill wens have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended 4ti~eils for accuracy. Thanks, Steve D. file://F:\Daily_Document Record~Procedures Instructions~FW INTENT PLUG for RE-D... b/14/2010 `` ~d~ PIaoAerivE D'u-yNOSric SeavicES, INC. WELL LQG ~ TRANSMfTTAL To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907j 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~, x~}(~~~~} ~~~~ % `~ ZQ~~ 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 2) 17-Fe1~10 31-11 Signed Print Name: J~~ 1 Report / EDE 50-029-21932-00 ~ ~ ~i ~~ ~ _- _ Date PROACTIVE DIAGNOSTIC SERVICES, lNC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: {907)245-8951 FAx: (907)245-88952 E-MAIL : _ _ .. _~ WE8$ITE : ~~_ ~ ~~ C:~DocuaiercG and Settings~Diane Wdfiams~Destctop~Transmit. Conocodocx 1~ '. '~ 1~ • Memory Mutti-Finger Caliper Log Results Summary Company: ConocoPhillips Alaska, Inc. Well: 31-11 Log Date: February 17, 2010 Field: Kuparuk Log No.: 7831 State: Alaska Run No.: 3 API No.: 50-029-21932-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE Top Log Intvl1.: 6,349 Ft. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 6,421 Ft. (MD) Inspection Type : Post-Placement Whipstock Inspection COMMENTS This caliper data is tied into the 3,5" tubing collar @ 6,389' (MD), This log was run to assess the condition of the tubing after a whipstock was installed and millwork was ' ' attempted. The caliper recordings indicate an apparent partial mill window from 6,412 to 6,416 , with the orientation of the middle of the window recorded at 11:00. A 3-D log plot of the caliper recordings across the 3.5" tubing logged, including the apparent partial mill window, is included in this report. This is the third time a PDS caliper has been run in this well and the second time the bottom 3 joints of the 3.5" tubing have been logged. A comparison of the current and previous log (January 3, 2010) indicates new mill damage. i~ i~ i~ i~ C'~ i~ Field Engineer: J. Halvorsen Analyst: M. Lawrence Witness: C. Kennedy ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281} or {888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field office Phone: (907} 659-2307 Fax: (907j 659-2314 ~ - a35 ~ ~ `~3~~ • • PDS Multifinger Caliper 3D Log Plot ~.-, _~.. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 31-11 Date : February 17, 2010 Description Comments Depth Max. I.D. (ins.) Image Map (Off-Center) Image Map (Centered) 1ft:120ft~2.5 ~~ 3.5 0° 80° 180° 270° 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. 2.5 3.5 ,~ , 6350 E Joint 195 - 6360 -7-_ i i i 6370 ' Joint 196 6380 i ~_ ._i 6390 Joint 197 Apparent 8400 Partial Mill Window (6,412' 6,416') Window Orientation at 11:00 6410 i _,+•. _-~~' -a; s~ ;~.~_ __ seal Assembly 6420 hs,;== ,_._ _~ ' ~ KUP 31-11 ConOCOPhillip s ~ elI Attributes An le & niro TD Al,~y. .. ,, I / wdlhore WI 500292193200 Fld Name W IStXUS Ind l') ND B) KUPARUK RIVER UNIT PROD 24.02 5.300.00 Act6 ) 6.772.0 Comment M251ppm) DMe SSSV: TRDP 160 2/5/2008 Arrro[atlon Last WO: Errtl Date 6!112009 KB-Wtl Qq 35 91 Rig Release Date 414!1989 we taus -3w1 w vzooa s n a s AM . emabc- Aaual Amotalian De (NCB) tlDate tatlon Last Mod ... Entl Date Last Tag: SLM 6.516.0 6/6/2009 Rev Reason: SSSV not bdced open Imosbor 12/2/2009 Casin Strin s HANGER, 31 Casing DesMptlon CONDUCTOR S[Rng 0... 16 Sung ID ... 15.062 Top IrtlcBl 36.0 Set Depm (r... 116.0 Set Depth (ND) ... 116.0 String Wl... 62.50 Rng ... H-40 S[Rng Top Thrtl Casing DesMptlon SURFACE String 0... 95/8 String ID ... 8.765 Top (RKB) 35.0 Set Depth g... 3.383.4 Set Deph 1TVDl ... 3.383.3 Sung VR... 36.00 Rng ._ 1-55 Sung Top Thrtl t Casing DescRptlon PRODUCTION Sung 0... 7 Strng ID ... 151 6 Top (N(B) 33 0 Set Depth R... 6 761 5 Set Depm ITVD) ... 550 6 2 SfRrg VR... 26 00 Sung ... 135 Sung Top Thrtl . '. r< , . . . . , . Tubin Strin s 7Yrdng Descriptlon String 0... SIRng ro ... op ) set Depth (G.. set Depth (N ... Sung Wt... Sung ... String Top Thb TUBING-Upper 31/2 2.992 31.0 6.143.0 5.974.1 9.30 L-80 EUE Com le tion Details coNOUCTOR as-115 T lop Depth (NDj IN(B) Top lnd (~ NorN... ID Itt ,y o 31.0 31.0 tt 0.02 H em Desc on ANGER Comment FMC 6" x 3 tf2" Gen IV Tubing Hanger w/ pup H 2.992 sAFETVVLV. 2212 0 2,212.3 2,212.3 0.17S AFE!-YVW Carrico3l/2"x2.813"'X'ProfdeTRMAXX-5ESCSSV 2.813 6.123.0 5,955.7 23.60 N IPPLE Haliburton3l/2"x2.813"'X'Nipple 2.813 6,131.0 5,963.1 23.57 S EAL ASSY Baker 80-40 Seal Assembly (2' Space out) 3.000 F G S 7Udng Desalptlon TUBING-Mid Sedion SIRrg 0... 3172 String D ... 2.992 Top 6,132.1 Depth IL.. 6,427.5 Set Depth (TW) ... 6,236.7 rig _. 9.30 string ... L-80 Sung Top EUE A LI T, z 512 ~ Co e tion Details Top Deptl1 INDI lop lnd NoM... Top (fhCB) (~B) (") tt em DescRptlon Crxnmert ID PN suRFACE 35,383 6,132.1 5,964.1 23.57 P BR Baker 80-40 PBR 3.000 6,145.5 5,976.3 23.53 S EAL ASSY Baker KBH-22 80-0A-40 Anchor Seal Assy 3.000 6,146.4 5,977.2 23.53 P ACKER Baker 84SA8-40x32 Retainer Prod. Packer 3.250 cAS uFT 3.702 6.151.3 5,9$1.7 23.52 X O Redudng Xover Sub, 4 1/2' LTC pin x 3 1/2' EUE pkl 3.010 6,156.3 5.986.2 23.50 N IPPLE Har~unon 2.813"'X' Nipple 2.813 6,419.8 6.229.7 22.80 S EAL ASSY Baker 80-00 GBH-22 Seal Assy wlLocator 3.000 Turing Descrfptlon 3[rhg O... SIRrg ID ... Top QIICB) Set Depth p... Set ptl11ND)... Sung YV[... String ... Smng op Thrtl PACKER ASSY 5 4.000 6,422.1 6,438.0 6,246.3 ACME cAS UFT Com le tion Det ails a, tsc To Top Depm Rvo) p~Bl Top Ind 19 tt em DescR Ion Cranmert Nom... ID 1k4 6,422.1 6,231.8 22.76 P ACKER Baker 85~10'F7' Permanent Production Packer 4.650 6,425.4 6,234.8 22.69 S BE Baker 80-40 SBE (5' Long) w! XO Sub 4.000 cAS LIFT. 6,429.9 6,238.8 22.59 X O - Reduang X-0ver Sub 5" BTC x 3.5" EUE 3.000 5.666 6,433.4 6,242.1 22.52 N IPPLE Cameo 3l/2"x2.75"'D'Nipple 2.750 6 437.1 6,245 4 22.44 S OS Shearout Sub w/ WLEG 3.000 Perforations & Slots GAS LIfT. 6 ota TeP1~B1 8~11~1 ToP (TVDj I~B) Blm (TVD) CBI zone Date sha Dens 1~1~- Comment , 6.437 6,454 6,245.4 6,261.0 A-3. 31-11 3/6/1990 8.0 IPERF 21/8" Dyna Strip. 60 deg ph 6.457 6.486 6.263.7 6.290.6 A-2.31-11 5/18/1989 4.0 IPERF 4.5"HSD Csg Gun. 90deg ph 6.494 6,503 6,298.D 6,305.8 A-1, 31-11 3/6/1990 8.0 IPERF 21/8" Dyna Strip, 60 deg ph NIPPLE. 6.123 NOtes: t3e11@ral ~ Saf Entl Dale Amo[aaon 6/10/2009 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 sEA1 Assv. 6 131 , PBR, 6,132 SEAL PSSV, 6 145 , PACKER. 6.146 NIPPLE, 6,156 ~ SEPL ASSY, 6,420 PACKER, 6,422 I~! SBE,6425 I Ma ndrel Details NIPPl F.66?d Sm T lop Deem (ND) I~B) op Ind ('1 kdke Noad OD Iml Serv Valve M1e Latd1 1YM PoR Slze M) 7RORtn IPe1 Run Date Com... 1 2,511.6 2,511.6 0.09 Cameo MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 6!5/2009 ' sos, s,a3t 2 3,702.1 3,701.9 3.84 Cameo MMG 1 1/2 GAS LIFT GLV RK 0.188 1,261.0 6/512009 IPERP, 3 4,760.5 4.706.8 23.38 Cameo MMG 1 1!2 GAS LIFT GLV RK 0.188 1,254.0 6!5!2009 6p37-6A64 4 5,667.8 5,538.4 23.61 Camrn MMG 1 1/2 GAS LIFT GLV RK 0.188 1,245.0 6/5/2009 5 6,074.0 5,910.7 23.36 Cameo MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 6/5/2009 IPERF, 6 457-6 686 IPERF, 6,494-6 503 PRODUCTION, 336,]61 TD, 6 772 ~~~L ~~~~~~~~ II= PI~ACTIVE DIAf~NOSi1C $ERVN:ES~ ANC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C ~.~" f~~ ~`~~ ~, ~ `~~~~ Anchorage, AK 99518 '~ ~~~' ~ ~~"~ Fax: (907) 245-8952 1) Caliper Report 2j 03,Jan-10 31-11 l $~'a3S Signed Print Name: ~ i / - 1 Report / EDE 4i / l05 50-029-21932-00 Date ~ ~` ' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE,. AK 99518 PHONE: (907)245-8951 FAx: (907)245-88952 E-MAIL . _ WEBSITE ; :~„."" C-VDocuments end Settings\Diane Williams~Desktop~Trarurztit_ConQCO.docx • Memory Multi-Finger Caliper S Log Results Summary Company: ConocoPhillips Alaska, Ihc, Well: 31 -11 Log Date: January 3, 2010 Field: Kuparuk Log No.: 10609 State: Alaska Run No.: 2 API No.: 50-029-21932-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE Top Log Intvl1.: 6,100 F#. (MD) Pipet Use: Tubing Bot. Log Intvl1.: 6,437 Ft. (MD) Inspection Type : Restriction Inspection COMMENTS This caliper data is tied into the WLEG @ 6,437' (Driller's DepthJ. This log was run to assess the condition of the tubing with respect to cement sheath remnants prior to whipstock setting operations. The caliper recordings indicate remnants of cement sheath from -6,235' to -6,252', _6,281' to -6,291', -6,347' to 6,350', and 6,406' to 6,411', restricting the I.D. to 2.89" at 6,411'. A 3-b log plot of the caliper recordings across the proposed whipstock setting interval is included in this report. The caliper recordings indicate the remainder of the 3.5" tubing logged is in good condition with respect to corrosive and mechanical damage. Excluding the tubing punch intervals, no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 3.5" tubing logged. This is the second time a PDS caliper has been run in this well and the first time this 3.5" tubing has been logged. MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 15%) are recorded throughout the 3.5" tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: ~- No significant t.D. restrictions are recorded throughout the tubing logged. ~^ P Field Engineer: G. Etherton Analyst: C. Waldrop Witness: D. Rowelt ProACtive Diagnostic Services, Inc. J P.O: Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail; PDS'a~memoryiog.com Prudhoe Bay Feld Office Phone: (907) 659-2307 Fax: (907) 659-2314 > ~9 -03 S /~/r'o 5- • PDS Multifinger Caliper 3D Log Plot ~, _ ~~. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 31 -11 Date : January 3, 2010 Description : Detail of Caliper Recordings Across Proposed Whipstock Setting Interval • • • • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE Well: 31 - 11 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: January 3, 2010 Joint No. Jt. Depth (Ft) I'cn. Upset (Ins.) Pen. Body (Ins.) Nen. `~~ Metal loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 189.1 6121 (? 0 (1 +! 2.81 Haliburton 3.5" x 2.813" X-Ni le 189.2 6123 U 0.02 9 ? 2.92 PUP 189.3 6129 (1 0 U O 3.00 Baker 80-40 Seal Assembl 2' S aced out .1 6142 +? 0 U O 3.25 Baker 84SAB-40x32 Retainer Prod. Packer .2 6151 U 0 U i) 3.01 4.5" LTC in x 3.5" EUE in X-Over .3 6153 O 0.03 11 ~ 2.95 PUP .4 6156 U 0 O i? 2.81 Haliburton 2.813" X-Ni le .5 6158 O 0.03 1 > ~' 2.92 PUP Shallow corrosion. 1 6168 U 0.03 1 ~' 2.93 2 6199 U 0.30 lUi) 11 2.92 Tubin Punch 3 6231 U 0.04 C 5 2.89 Shallow corrosion. Cement Sheath. 4 6263 U 0.04 14 ? 2.90 Shallow corrosion. Cement Sheath. 5 6295 O 0.03 11 _' 2.92 Shallow ittin . 6 6327 O 0.02 9 ~' 2.89 Cement Sheath. 7 6358 U 0.03 12 2.90 Shallow corrosion. Cement Sheath. 8 6389 O 0.10 41 (~ 2.89 Tubin Punch. Cement Sheath. 8.1 6422 u 0 u u 3.00 Baker 80-40 GBH-22 Seal Assembl w Locator 8.2 6428 (~ 0 O a 4.65 Baker 85-40'E1' Permanent Production Packer 8.3 6430 i) 0 U O 3.00 5" BTC x 3.5" EU X-Over 8.4 6431 U 0.01 Z ? 2.91 PUP 8.5 6433 U 0 t) i 1 2.75 Carnco 3.5" x 2.75" D-Ni le 8.6 6435 U 0.01 4 2.94 PUP 8.7 6437 U 0 (1 +) 3.00 Shearout Sub w WLEG Penetration Body Metal Loss Body Page 1 `. j ~-`\~ KUP a 31-11 ConoeoPhillip s 1 Well Attributes An le & MD TD 11. ,,: _, i~ ., 1 Wdlbore APl/UWl 500292193200 Fldtl Name Well Stahrs Inc!( MD IM(B) KUPARUK RIVER UNIT PROD 24.02 5.300.00 AQ trn g[KB) 6.772.0 . Comment 25 (ppm) Dare SSSV: TRDP 160 2!5!2008 Amatation Last WO: Entl ate 6/1/2009 IBf7d (~ 35 91 Rig Release Date 4/4/1989 weu ova -. - I-11 Mem k rz o09 s. 7.3 ai 4 AM Amd[atlon Last Tag'. SLM Depm gtXe) 6.516.0 . Erltl Date Ama[atlat 6/6/2009 Rev Reason: SSSV not locked open Last Motl ... Imosbor EIW Date 12/2/2009 Casin Strin s NANGER. 39 Casing Descnptron CONDUCTOR S[dng 0.. 16 . Stdtg lD ... 15.062 Top ) S 36.0 et Deem g... 116.0 dDepthl )... 116.0 String WC.. 62.50 String... H-00 Stnng Top7Mtl Casing Descdp6on SURFACE String 0.. 9 5/8 . Stdrg ID _. 8.765 Tap gNB) 35.0 [ ._ 3.383.4 Set Depth )... 3,383.3 String NN... 36.00 "rig... J35 Strng lop Thrtl Casing DescdpNOn PRODUCTION String 0.. 7 . 5[drg lD ... 6 151 Tap gtlB) S 33 0 et Deptli n... 761 6 5 Sd Depth llYD)... 6 550 2 9rhg YYL.. 26 00 Skiing... 35 String Top Thrd . . . . . . . J Tubin Strin s tg escdpdon Smng 0... Sidrlg ID ... lop (RIB) Set Depm g... Sd Depth (lVD) ... String .. rg... String Top b TUBING-Upper 3112 2.992 31.0 6,143.0 5.974.1 9.30 L-80 EUE Com l etion Details CONUUCIOR, 36116 Tep ~~ (ND) (NKB) Top Intl ° Ndnl... To KB 31.0 31.0 ( ) N 0.02 H em Descd an ANGER Cammem FMC 6" x 3 12" Gen IV Tubing Hanger w/ pup ID gn) 2.992 SArETV vw, 22r ~ 2,212.3 2.212.3 0.17 S AFETY VLV Camco 3 12" x 2.813"'X' Profile TRMAXX{E SCSSV 2.813 6,123.0 5.955.7 23.60 N IPPLE Halburton 312" x 2.813"'X' Npple 2.813 6,131.0 5,963.1 23.57 S EAL ASSY Baker 800 Seal Assembly (2' Space out) 3.000 AS L IrT g Descdptlon TUBING-Mid Section Strmg 0... 312 Strtrg ID ... 2.992 op (RIB) S 6,132.1 e[ Depth ry.. 6,427.5 Set Dept (ND) ... 6,236.7 Strhlg NN... 9.30 Skittg... L-80 String Top 71rctl EUE , as,z Com le tion Details rop Deym (~) T op Ind Nomi... Top g[KB) gnt61 (°) tt em DescripNan Cammerf ID (fn) suRFACE 363 383 6,132.1 5,964.1 23.57 P BR Baker 80-40 PBR 3000 6,145.5 5.976.3 23.53 S EAL ASSY Baker KBH-22 80-0A-40 Anchor Seal Assy 3.000 6,146.4 5,977.2 23.53 P ACKER Baker 84-SAB-40~c32 Retainer Prod. Packer 3.250 cAS LIFT, 3 7oz I 6,151.3 5,981.7 23.52 X O Reducng X-over Sub, 4 12' LTC pin x 3 1/2' EUE pin 3.010 6,156.3 5.986.2 23.50 N IPPLE Hakburton 2.813"'X' Nipple 2.813 6,419.8 6,2297 22.80 S EAL ASSY Baker 80-40 GBH-22 Seal Assy w/Locator 3.000 ng Descd on String 0... 8trkg ID ._ Top ) Set pm g... set Depth (71lD) ... Rg WL.. Skiing... String Top Thrtl PACKER ASSY 5 4.000 6,422.1 6,438.0 6,246.3 ACME GAitIFT, _ Com le tion Details 4.760 To Top Depth (ND) T (IIKB) op kb (°) N em Descd an Comment Nomi... ID gn) 6,422.1 6,231.8 22.76 P ACKER Baker 85~40'F1' Permanent Production Packer 4.650 6,425.4 6,234.8 22.69 S BE Baker 800 SBE (5' Long) w/ XO Sub 4.000 ens uFl . 6,429.9 6,238.8 22.59 X O -Reducing X-Over Sub 5" BTC x 3.5" EUE 3.000 5668 6,433.4 6,242.1 22.52 N IPPLE Camco 3l/2"x2.75"'D'Nipple 2.750 6,437.1 6.245.4 22.44 S OS Shearoul Sub w/ WLEG 3.000 Perforations 8 Slots GA5 L IFT. 8 074 T Imce) Bkiri (IUCB/ Top (TYD) (NBI Bkin (TVD) 181 Zone Die sna Oerrs 1sh.. CommerN 6.437 6.454 6,245.4 6.261.0 A-3, 31-11 316/1990 8.0 IPERF 2 1/8" Dyna Strip, 60 deg ph 6,457 6,486 6,263.7 6,290.6 A•2, 31-11 5/18/1989 4.0 IPERF 4.5"HSD Csg Gun, 90deg ph 8,494 6,503 6,298.0 6,305.8 A-1, 31-1 t 3/6/1990 8.0 IPERF 2 118" Dyna Strip, 60 deg ph NIPP`e' 6''23 Notes: C4eneral & Safe Ertl Dffie Amo[akion 6/10/2009 NOTE- VIEW SCHEMATIC w/Alaska Schematic9.0 sEAi Assv. 6131 PBR.6132 SEHL ASSY. 6 ids PACKER, 6,'146 NIPPLE, 5,158 SEAL ASJY. 8420 PACKER.6422 S8E,6J15 Mandrel Details NIPPLE,6433 Stn T Top Dept (TVD) (NIB) h Top Intl 11 Make Model OD Pnl Serv Valve TYPe !.etch 1YPe Port Site IIM 7R0 Rtn (psi) Run Date Com.. 1 2,511.6 2,611. 6 0.09 Camm MMG 1 1/2 GAS LIFT GLV RK 0.188 1.285.0 6!52009 505,6437 ~ ~ 2 3,702.1 3,701. 9 3.84 Camrn MMG 1 112 GAS LIFT GLV RK 0.188 1,261.0 6/52009 IPERF, 3 4,760.5 4;706. 8 23.38 Camco MMG 1 1!2 GAS LIFT GLV RK 0.188 1,254.0 6/5/2009 s,437-apse 4 5.667.8 5,538 4 23.61 Carrico MMG 1 1/2 GAS LIFT GLV RK 0.188 1,245.0 6/5/2009 5 6,074.0 5,910. 7 23.36 Cartirn MMG 1 112 LIFT OV RK 0.188 0.0 6/5/2009 IPERF, s.as7~pas IPERF, 6,498-6$03 PP.ODUCTION, 33~ 761 TD, 6.772 • 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: 3I-11 Run Date: 12/13/2009 December 16, 2009 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 3I-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21932-00 ~~~~r 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 FaY:907;ZZ3-3535 ,., -_._ rafael.barreto@halliburton.com ,, ,~:. Date:.:.. ~$9_ b~- i9rsa Signed: ~~ • STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~ Alter Casing ^ Pull Tubing Q~ Perforate New Pool ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, IrIC. Development ^~ ' Exploratory ^ 189-035 / a 3. Address: Strati raphic 9 ^ Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21932-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 76' ' 31-11 • 8. Property Designation: 10. Field/Pool(s): ADL 25631 ` Kuparuk River Field / Kuparuk River Oil Pool ° 11. Present Well Condition Summary: Total Depth measured 6772' ~ feet true vertical 6560' • feet Plugs (measured) Effective Depth measured 6680' feet Junk (measured) true vertical 6473' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 116' 116' SURFACE 3348' 9-5/8" 3383' 3383' PRODUCTION 6728' 7" 6761' ~ ~ ; ~ ~*} ~~1~j .. ~ £. L' ~ ~~~~' ~ V '14r tri ~a+. , ~,. ~ECE~vEo Perforation depth: Measured depth: 6437'-6454', 6457'-6486', 6494'-6503' J~ L ~ e vertical de tr th 6245' 6261' 6264' 6291' 6298' 6306' ~ Z~~ ~' u p : - - , , - ~ v 1 ~~' Afaska Oit & Gas Cons. Cornmission Tubing (size, grade, and measured depth) 3.5", L-80, 6438' MD. AllChpiagB PaCkers & SSSV (type & measured depth) Baker retainer prod pkr, Baker'F1' permanent pkr @ 6146', 6422' Camco 'X' profile TRMAXX-5 E SCSSSV@ 2212' 12. Stimulation or cement squeeze summary: +~~~ ~- ^ ~-~~ l~ ~~ ~~ Intervals treated (measured) not applicab/e ~ ~,/~ Treatment descriptions including volumes used and final pressure: ~ 13. Representative Daily Average Production or Injection Data Oil-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation 115 • 719 816 -- 143 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: OilO , Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packer Titie Wells Engineer / Signature ~/~~., ~~ Phone: 265-6845 ~/~ ~ ~ ~ Date Pre ared b Sharon Allsu -Drake 263-4612 Form 10-404 Revised 04/2006 ~ a? . ~- ,i;.ai s~ ~ 2QOq ~ ,in 7.;. v`i' Submit Original Only ~a ,~~~/z~~ ConotoPhiilips ; ~` ~ .~..:. _ .. KUP 500292193200 KUPARUK RIVER UNIT TRDP 31-11 Slatus I~ncl (°) IMD (kKB~ Act Bhn Dala ~~. KB-Grd ~k~ ~ Riq Release Da~e 160 ~~ 2/52005 Last WO: : 6/12009 I 35.91 -__~ .._4/4/1989 )ata Annotation ~Last Mod By End Date 12009 IRev Reason: Workover. GLV C/O. Tao I Imosbor I 6l10/2009 Casin Dasen 9 'on S 6 0... String._ StringTopT~N Strin 0... Shin ID ... To ftK6 Set Da th f... Set De th ND I g 9 CON UCTOR 9 16 ~~ .p I i H-40 0fi2 00 6 15. 9 Casin Description ( ( ~ ~ 9 ) 9 String...lsfring7opihra 0... Strin ID ... Top (ftK8 Set Da th f... Se~ Da th ND) ... ~ Strin W~~" Strin ~ ISURFACE , ~_55 95/8 8J65 350 3,383.4 3,3A3.3 ~ 36.00 ~Casing Description String 0... String ID ... Top (itK6) Set Depth (f... Sa~ Dapth (ND) ... String WL.. I,String ... ~ String Top Thrd PRODUCIION 7 6.151 33.0 __ _ 6,76L5 6,5502 ~ 2G.00 ~i JSS __ ITubing Strings Tubing Descnption __ - - . . - __ IString 0... I String ID ... Top (ftKB) Set Depth (i... Set Dapth (ND) ... ~ String Wt... i5tring ... 'String Top ThN ~TUBING-Upper l 31/2 ~ 2.gg2 31.0 6,143A 5,974.1 ~ 9.30 L-80 EUE ~Completion Det ails I ~ TopDepth. ~~ i ~ (ND) ~~, Top Incl ~ ToQ(ftK6) ~.. (kKg) ~', (°) Item Dascription Comment ID (in) , 31_0 31.0 i 0.02 HANGER FMC 6" x 3 1/2" Gen IV Tubing Hanger wl pup 2.992~ 2,212.3 2,212-3 0.17 SSSV ,Camco 3 1/2" x 2.813"'X' Protile TRMAXX-SE SCSSV "LOCKED OPEN 2.813 iw/6200 psi om m~trol line" 6,123.0 5,955J ___ _ 23.60 NIPPLE Haiibunon 3 1;2" z 2813"'X' Nipple 2.813 6,13L0 5,963.1 23.57 SEAL ASSY Baker 80-40 Seal Assembly (Y Space out) ~~ ~ 3.000 ~Tubing Desenption String O._ String ID ... Top (HKB) Set Depth (t... Sat Depth (ND) ... Stri g Wt... String String Top ThN I I TUBING Mid I 312 2.992 6,133_6 6,429.0 6,238.1 930 L-80~ EUE ~ Section . .. Com letion Det - ~ . ~ _ __ _ l. . . _._ . ails Top Depth (ND) I Top Incl ~ Top (ftKBJ ~ (hKg) I (`I ~' Item Description Comment ID (in) 6,133.6'~~, 5,965.5~~. 23.ST~ PBR ~~~Baker80-40PBR J 3.000 6,14~A',~ 5,977J~ 23.53I SEALASSY ~BakerKBH-22S0-DA-40AnchorSealASSy I 3.OOOi 6,147.9j 5,978.6I 23.53I PACKER '~Baker84-SAB-40x32RetainerProd.Packer 3250 6,152.S~~~i, 5,983.1 ~ 23.51 _~ XO Reducing 'i X-over Sub. 4 12' LTC pin z 3 1/2' EUE pin 3.010 6,157.8~'~, 5,987.6 23.50 NIPPLE '~Haliburton2.813"'X'Nipple ~ 2.813 6,427.3~'i 6,231A 22J7 i SEAL ASSY ~~. gaker 80A0 GBH-22 Seal Assy wlLOCator 3.000 Tubin Descri ~ion g p Shin 0 I TOp (HKB) Set Oepth (t... Set Depih (ND) ... String Wt... String ... String Top Thrtl ... i5 ~ ~ PACKERASSY 5 I 4 I . 6.422.1 I 6.438.0 I 6,246.3 I ...I...__......I . ACME 000 _ Completion Det ails . .. . . . . . . .. Top Depth . I .. .. .. .. _ _ . . . . (ND) I Top Incl I ~TOp (ftKB); (ryKg) ' (°) Item Dascription _ CommaM _ . ID (in) I 6,422.1'~ 6231.8~1 22J6 PACKER IBaker85-00'F7'PermaneNProductionPacker 4.650 6,425.4 ~~. 6,234 8~~~. 22.69 . . SBE ~ Baker 80-00 SBE (S Long) wl XO Sub 4.000 242 8~ 1 6 2259 XO - Reducing X-Over Su6 5" BTC x 3.5" EUE 3.000 . 6 433 4 2252 NIPPLE Camco 3 72" z 275"'D' Nipple ~ 2J50 6,4371 6,2454~ 22.44, SOS ShearoutSubw/WLEG ~~ 3.000 Perforations 8 _._- -__ Slots I _ _ -- ---. snof Top (TVD) Btm (TVD) ~., Dens Top {(tK6) Btrn (ftK6) ~ (hK6) (flKB) Zone Date (s~~~~ Type Comment ~ 6,437 6,454 i 6,245.4 ~3/6/1990 8_0 IPERF 21/8" Dyna Stnp, 60 de7 ph 6,261AjA-3, 31-17 ~ 6.457 6,48f 6,263J __ 6,290.6~q_2, 31-11 ~5/78/1989 4.0 IPERF I4S'HSD Csg Gun, 90deg ph ~ 6.494i 6.503 ~I 6,298.0 ~~3/6/1990 8.0 IPERF 2 1/8" Dyna Stnp, 60 deg ph 6,305 8~A-1, 31-17. 1 Notes: General EndDate ~ 8 Safet y -~~-- -... Annotation -..- 6/10/2009 ~ NO I E: VIEW SCHEMATIC w/Alaska Schematic9.0 __ . ......__- _ . _. . ... Mandrel Details Top Depih Top . ~ ~ ~~~ Port (TVD) Incl ~ '~ OD ~ I~ Valve ~~ Latch Size TRO ftun Model (N Serv Typa Type I(in) (psi) RunDab Can__ SNTop(RKB)'i~ (HKg) (°) Make 1 2511.6 2,51 I 1.6 0.09ICamco MMG 112GASLIFT GLV RK ~0.188 7,26506/52009 2 3,702.1 3.701.9 3.84 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188i 1,261.0 6/52009 ~ 3 4,760_5 4 706.8 23_38 Camco MMG 1 V2 GAS LIFT GLV RK 0.188~ 1,254 0 6/52009 ..____-_ _ . _ 4 S,fi67B 5,538.4 23.61 Camco MMG 1 7/2 GAS LIFI GLV RK 0.188 1,245.0 6f5/2009 ~ 5 6,074.0 5,910J 23.36 Camco MMG 1 12 GAS LIFT OV RK 0.188 ~ 0.0 6/5/2009 31-11 Well Events Summary DATE SUMMARY 5/20/09 CUT 2 7/8" TUBING AT 5860' I IDDLE OF FIRST FULL JOINT ABOVE ~ING PATCH AT 5881'. GOOD INDDICATION AT SURFACE, TUBING PULLED FREE AfTER CUT. 5/22/09 DRIFTED TUBING WITH 2 1/8" DUMMY RUN. JET CUT TUBING AT 6225' IN MIDDLE OF FULL JOINT BETWEEN PACKER AND GAS LIFT MA~BE~~. CUT TUBING WITH 2 1/8" SCHLUMBERGER POWER CUTTER. 5/23/09 SHOT BACK OFF FROM 6259'-6271' ACROSS PACKER INORDER T~ A~LOW RIG TO PULL TUBING. RIG PULLED FREE AFTER BACK OFF. 5/26/09 SHOT 2 STRAND STRING SHOTS FROM 6260'-6270', FROM 6252'-6262', AND FROM 6238'-6248'. ATTEMPTED TO RUN CHEMICAL CUTTER BUT UNABLE TO GET 1.8" CUTTER PAST 6200'. RIG WAS ABLE TO COME FREE AFTER SHOOTING STRING SHOT AT 6238'-6248' 5/29/09 MAKE 2 JUNK BASKET RUNS WITH 5.98" GAUGE RING. SIGNIFICANT nFRRIS INCLUDING METAL SHAVINGS AND RUBBER ON FIRST DESCENT. VERY LITTLE DEBRIS ON SECOND JUNK BASKET DESCENT. SET BAKER Z" -" PRODUCTION PACKER AT 6422'. 6/2/09 ATTEMPT TO PULL BALL & ROD, NO SUCCESS. IN PROGRESS 6/3/09 BAIL FILL OFF RHC PLUG AT 6156' RKB AND PULLED BALL & RO~. IN PROGRESS 6/4/09 BAILED FILL OF RHC PLUG BODY AT 6156'. PtJLLED SOV AT 607~(1~LQ,T SHEARED) & DMY VALVES AT 5668', 4760' ,3702', 2511'. SET GLVs AT 2511'8~ 3702'. JOB IN PROGRESS 6/5/09 CMIT TO 2500 PSI PASS. SET GLVs @ 4753', 5659', SET OV @ 6205' RKB. TEST TBG TO 2000 PSI, GOOD TEST. PULLED RHC PLUG BODY C~? 6156' RKB. TAG FILL @ 6392' SLM (EST 25' FILL ON SHEAR OUT SUB) JOB IN PROGRESS 6/6/09 BAILED FILL OFF OF SHEAR OUT SUB (c~ 6437' RKB. PRESSURE UP O 3500 PSI & JAR DOWN TO SHEAR SOS Ca~ 6437' RKB. TAG W/ 5' X 2.25 BAILER @ 6516' SLM~PERFORMED INJECTIVITY TEST W/ LRS ( APPEARS. FORMATION OPEN) JOB COMPLETE. ~~n~~~~~~~~~s Time Log & Summary LNeftv}eev Web Raporting Re po rt Well Name: 31-11 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/18/2009 5:30:00 PM Rig Release: 6/1/2009 8:30:00 AM ..: ~,, ~'itl'l~: , N t , ..:: ;; . , ~~?~~~ . ~~ ~~~~~.: : ; ` ~ ~ o~~,~° ~ ' . .. .. . ~; ._ \'\ ~~ ; ~ > ~._ F T F ~ . . ~ ;;. ,... ~ : ~ ~.. . ~~~ ~~ ~ ~ ~ F,. ,.. ~ ~ ..~~ 5/18/2009 24 hr summarv Road N ordic Rig 3 from 2V-08 to 3 1-11, MIRU, Accept rig, Pull BPV adn Circ well w/ 13.1 ppg KWF. 03:30 05:30 2.00 0 0 COMPZ MOVE MOB P Moving Nordic 3 from 2V-08A to CPF-2. 05:30 07:30 2.00 0 0 COMPZ MOVE OTHR P Standby w/ rig crew for CPA! field 07:30I 17:30 I 10.00 0 I 0 ICOMPZIMOVE (MOB P lover~well and etd wtn on matspot 17:30I 19:00 I 1.50 ~ 0 I 0 ICOMPZI MOVE IRURD ~ P ~ Berm Up and spot auxiliary 19:00 22:30 3.50 0 0 COMPZ RPCOM MPSP T Pu Lubricater and attempt to fish BPV, Lubricator leaked, switch out lubricator and pull BPV. Open up weil and obtain pressures. SITP = 1,900 psi, SIIAP = 1 600 si SIOAP = 650 si. PT Hardline and circulating lines to 3,500 psi while waitin . 22:30 00:00 1.50 0 0 COMPZ RPCOM CIRC P Circ. well w/ 13.1 ppg brine @ 3 bpm w/ 2,450 ICP and 980 FCP. Circulated 280 bbls. Fluid returns were to aas cut weiqh. CBU 5/19/2009 CBU, Monitor well. Set BPV, ND Tree and NU BOPE. Start test BOP 250/3,500 psi., Pull BPV, Pull Seals f/ PKR, Circ. 1.5 hole vol. 00:00 02:30 2.50 0 0 COMPZ WELCTL CIRC P CBU @ 2 bpm @ 600 psi returning 13.1 ppg w/ pressurized mud balance and 12.1 ppg w/ Simple mud balance. 02:30 03:30 1.00 0 COMPZ WELCTL KLWL P Bull head 25 bbls down TBG and into perFs. @ 1.5 bpm @ 1,500 psi, Shutdown pumping operations, pressures bled down to 500 psi. over 20 minute period. SWI 50 psi build on oa in 10 minutes, 100 psi in 30 03:30 12:00 8.50 0 0 COMPZ RPCOM OTHR T Have 50 bbls of KWF on board weighing 13.1 ppg w/ Pressurized mub balance and 12.1 ppg wl Simple Mud Balance. On standby in Vac truck we have 180 bbis of 13.1 ppg w/ Pressurized and Simple Mud Balance. Ordered out additional 180 bbls of 13.1 ppg mud from MI Plant. ETA 10 to 12 hrs. While waiting, Rack, Tally, drift and PU 200 jts of 3 1/2 DP and stand back in derrick. 12:00 15:30 3.50 0 0 COMPZ RPCOM KLWL P Cimulate 220 bbl of 13_1 o~a 6rine down the tubin taking returns up the IA. Pumped at 2.5 bpm @ 780 psi, los 27 I 'r SITP = 0 psi, SICP = 10 psi (bleed IA several times and pressure up to 10 psi in -10 min). Circulate another hole volume (225 bbl) to shear ol mer and avoid potential sage during NU/ND down time. Pum in 2.5 b m 820 si. 15:30 16:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor well. SITP = 0, SICP = 0. IA pressures up to 10 psi in -10 min. Bleed several times. 16:00 16:30 0.50 0 0 COMPZ RPCOM KLWL P Pump 40 bbl down the tubing and up the IA. 16:30 18:00 1.50 0 0 COMPZ RPCOM OWFF P Monitor well. Pressures up to 10 psi in ~15 min. Open IA to atmosphere and leave open for 30 min. Shut in IA. Monitor IA, no pressure build u . 18:00 20:30 2.50 0 0 COMPZ RPCOM NUND P RD circ lines se BP install blankin lu . 20:30 23:00 2.50 0 0 COMPZ RPCOM NUND P NU 13 5/8" BOPE. 23:00 00:00 1.00 0 0 COMPZ WELCTt BOPE P Test BOPE at 250/3,500 psi. 24 hr notice was given @ 18:15 hrs on 5-17-09, Chuck Scheve requested update on 5-18-09 AM. Updated @ 17:45 hrs on 5-18-09 and witness of test was waived b Lou Grimaldi. 5/20/2009 Test BOPE, RU and unseat hanger, attempted to pull seal assembly free, called out SWS for tbe cut, RU SWS, RIH and cut 2 7/8" tbg at 5,860', RD SWS, CBU, POOH LD tbg and jewelry, RU and RIH with BHA #1, cont PU RIH with 3 1/2" DP to 1,583'. 00:00 03:00 3.00 0 0 COMPZ WELCTI BOPE P Cont testing BOPE at 250/3,500 psi. 24 hr notice was given @ 18:15 hrs on 5-17-09, Chuck Scheve requested update on 5-18-09 AM. Updated @ 17:45 hrs on 5-18-09 and witness of test was waived bv Lou Grimaldi. 03:00 04:00 1.00 0 0 COMPZ RPCOM RURD P RD test equipment,pull„biankin9 iu and BP well static, MU landin 'oint and circ hose, BOLD's. 04:00 04:30 0.50 0 0 COMPZ RPCOM PULL P Unseat hanaer. pull to 151 K up weight (80% plus block weight), hookload slowly dropped to 145K, broke circ at 1.5 bpm - 600 psi, increased up weight to 151 K, hook load still siowly dropping off, cont working pipe, called out SWS for 2 7/8" tb cut. 04:30 06:30 2.00 0 0 COMPZ RPCOM CIRC T Circulating hole while waiting for SWS to arrive on location. 06:30 08:30 2.00 0 0 COMPZ RPCOM RURD P SWS arrived on location, spot equipment. Set tubing in slips with 85 K# of up weight - 15 K# of tension. PJSM. RU E-line with 2-1/8" Power cutter. 08:30 09:30 1.00 0 0 COMPZ RPCOM ELOG P RIH with E-line, tie in and shot Power Cutter 'et cutter @ 5860'. Jewerly and collars shifted u hole 2' after cut. POOH. 09:30 10:00 0.50 0 0 COMPZ RPCOM RURD P RDMO SWS E-line equipment. 10:00 1130 1.50 0 5,860 COMPZ RPCOM CIRC P PU 2-7/8" tubina hanaer to the floor. PU wt = 65K# with no over uil. Circulate BU 2.5 b m 510 si. 11:30 12:00 0.50 5,825 5,825 COMPZ RPCOM PULD P LD landing jt., tubing hanger. Blow down top drive and change out elevators. 12:00 21:00 9.00 5,825 0 COMPZ RPCOM PULL P POOH with 2-7/8" tubing. Layin9 down, strapping and kicking out tubing. Pum ed 10 bbl d'ob. 21:00 22:00 1.00 0 0 COMPZ RPCOM RURD P Clean rig floor, CO handling equipment, load DC's and fishing tools, set wear rin . 22:00 23:00 1.00 0 227 COMPZ RPCOM FISH P PU and MU B t with hollow mill 23:00 00:00 9.00 227 1,583 COMPZ RPCOM FISH P pU single in hole on 3 1/2" DP from pipeshed to 1,583', up weight 55K, down wei ht 55K. 5/21 /2009 Cont PU RIH to 5,800', CBU to shear mud, singie in hole and engage fish at 5,860', attempted to jar seal assembly free of PBR, released from fish, CBU x2, POOH to 3,810', hole fili off, RIH and cire surf to surf, monitor well, well static, POOH from 5,740' to 5,457'. 00:00 03:00 3.00 1,583 5,815 COMPZ RPCOM FISH P Cont PU and single in hole on 3 1/2" DP with BHA #1 from 1,583' to 5,815', up weight 105K, down weight 95K. 03:00 04:00 1.00 5,815 5,815 COMPZ RPCOM CIRC P CBU at 2 bpm - 470 psi. 04:00 04:30 0.50 5,815 5,866 COMPZ RPCOM FISH P Singie in hole and tag top of fish at 5,859', u weight 107K, break circ at 2 bpm - 400 psi, rotate at 50 rpm's, wash/mill down over too of fish tn 5 866', stop rotation and PU to 150K, engaged fish, jarred on fish with 165 to 175K, flat ulled to 200K, 04:30 10:00 5.50 5,866 5,866 COMPZ RPCOM JAR P Jarrin on 2-7/8" com Ip etion• Fishing string up weight 107K#. Jars are being set off at 210K#, then over ullin u to 240K#. 10:00 12:30 2.50 5,866 5,866 COMPZ RPCOM JAR P Ordered out wash pipe and extema~ 12:30 ~ 15:30 ~ 3.00 ~ 5,866 ~ 5,866 patch and POOH. Continue to jar on fish while waiting on e ui ment. RPCOM FISH P Jars are wearing out, stop jarring. Attempt to release off of tubinq stub. Pulling up to 130K while rotating, torque stays below 4000. Pull without rotating to 245K. Unable to pull free. Start rotating and pulling up hole, gradually pulled up to 225K and torque climbed to ~ 8000 and released. Up weight is 107K, original strin wei ht. 15:30 17:00 1.50 5,866 5,830 COMPZ RPCOM CIRC P Circulate BU pumping 3 bpm @ 630 psi. Continue circulating due to an increase of gas circulated to surFace. Circulated 2 BU volumes. 17:00 19:30 2.50 5,830 5,830 COMPZ RPCOM SVRG P Monitor well, post jarring rig inspection prior to POOH, blow down top drive, CO saver sub, pump dry 'ob. 19:30 21:00 1.50 5,830 3,810 COMPZ RPCOM TRIP P POOH from 5,830' to 4,780', hole fill 2 bbls off, monitor well f/ 15 min, hole static, cont POOH to 3,810', hole fill 2. bbls off. 21:00 22:00 1.00 3,810 5,740 COMPZ RPCOM TRIP T RIH from 3,810' to 5,740'. 22:00 23:30 1.50 5,740 5,740 COMPZ RPCOM CIRC T Cire surface to surface at 2 bpm - 450 psi, 407 units gas max at bottoms u . 23:30 00:00 0.50 5,740 5,457 COMPZ RPCOM TRIP T Blow down top drive, POOH from 5,740' to 5,457', up weight 105K, down wei ht 90K. 5/22/2009 POOH stand back DP and DC's, MU BHA #2, RIH and engage tbg stub, RU e-line and cut tbg just above seal assembl , POOH RD SWS, POOH LD BHA #2 and 91' of tb , MU BHA #3 and RIH to 2,058'. 00:00 04:30 4.50 5,457 0 COMPZ RPCOM PULL P Cont POOH from 5,457', LD overshot and jars with 15' tbg stub, CO handling equipment and LD 8 jnts 2 7/8" tbg including patch, + 5' of stub. Recovered 273' of fish. 04:30 06:00 1.50 0 0 COMPZ RPCOM PULD P Clean rig floor, CO handling equipment to 3 1/2", break down ~ars, overshot and tubin stub 06:00 07:00 1.00 0 20 COMPZ RPCOM PULD P PU and MU BHA #2 overshot on 3 1/2" DP. 07:00 10:00 3.00 20 6,080 COMPZ RPCOM TRIP P RIH with 3 1/2" DP to 6,080'. Up wt = 105K#, down wt = 95K#. 10:00 10:30 0.50 6,080 6,131 COMPZ RPCOM FISH P RIH and tagged top of 2-7/8" tubing stub at 6131', sit down 2K#. Puil up 10K#, grapple has engaged tubing stub. Attempt to release from stub to replace DP joint with a pup joint for E-line RU. Unable to release, pulling 10K# over while rotating to the right. String would not torque up over 2000. tension. 10:30 12:00 1.50 6,131 6,131 COMPZ RPCOM RURD P PJSM. RU E-line unit and equipment 12:00 15:30 3.50 6,131 6,225 COMPZ RPCOM ELNE P RIH with E-line dummv run. Run 2-1/8" weight bar with CCL. Sit dowr on nipple reducer at 6299'. POOH_ MU 2-1/8" Powerjet Cutter assembl~r. RIH tie in and cut at 6225'. POOH, collars shifted u 1' after cut. 15:30 16:00 0.50 6,225 6,225 COMPZ RPCOM RURD P RD E-line tools and unit. 16:00 18:00 2.00 6,225 6,210 COMPZ RPCOM CIRC P PU wei ht 108K# (3K# pain afte~ cut . Circulate BU 3 bpm @ 650 psi. Gas units picked up during circulating, continue to circulate until gas units dropped off, 1.5 well 18:00 21:30 3.50 6,210 0 COMPZ RPCOM PULL P POOH with ra le and 92' of cut tubin . Stading back DP and DC. Break down overshot and LD tb . 21:30 23:30 2.00 0 411 COMPZ RPCOM PULD P Clean rig floor, load DC's, MU BHA #3 with overshot. 23:30 00:00 0.50 411 2,058 COMPZ RPCOM TRIP P RIH on 3 1/2" DP to 2,058' RIH to 6,231', engage fish, attempt to pull and jar seal assembly from PBR, attempt to release fish, call out SWS, RU SWS and perForm string shot in mandrel section of packer, POOH RD SWS, rotate and release ra le, PU and CBU, POOH LD NHA #3, PU and MU BHA #4 6" burnshoe and wash i e. 00:00 01:30 1.50 2,058 6,170 COMPZ RPCOM TRIP P Cont RIH with BHA #3 from 2,058' to 6,170', up weight 115K, down weight 100K, rot weight 107K, off bottom tor ue 2,000 ft/Ibs. 01:30 02:30 1.00 6,170 6,231 COMPZ RPCOM FISH P Break circ at 6 bpm - 1,100 psi, rotate at 80 rpm's and wash down to 6,200', reduce pump rate to 2 bpm - 500 psi, cont wash down over top of fish at 6,225' and stop pumpinq. 02:30 09:00 6.50 6,231 6,231 COMPZ RPCOM JAR P Engaqed tbq stub, commence iarrinq on fish at 200K, with straight puil to 245K. Jar for 4 hrs. Contacted HES for AVA packer info. Informed that packer also has a rotational release. Place in tension ~SK, rotate 1 turn for every 10K shear setting (60K shear = 6 turns). Made several attempts at 5K , 10K and 15 K. Cannot release from fish as the com letion s ins when there is no tension in the strin . Attempt straight pull to 285K#. Attempt to turn to the left to back off 2-7/8" connection. Attempt to pull up 250K# with 8800 torque. Unable to release, backoff or art tubin . 09:00 13:00 4.00 6,231 6,231 COMPZ RPCOM OTHR T Call out SWS for string shot to back off 2-7/8" tubing connection. Plan to burn over packer after fishing strin is out of the hole. 13:00 15:00 2.00 6,231 6,231 COMPZ RPCOM RURD P SWS on location. MIRU E-line unit. 15:00 18:00 3.00 6,231 6,231 COMPZ RPCOM ELNE P RIH with E-line 12' string shot. Shoot across the acker 6259' to 6271'. POOH Assumption is that the mandrel in the packer is spinning not allowing the grapple to slack off and turn to the right to torque up and release. Plan is to shoot across the packer and swell the mandrel so it will not rotate allowing the grapple to slack, rotate, torque and release. After the fishing string is remove the plan is to wash over the packer, this was another reason to try to swell the mandrel to keep it from rotating durin millin . 18:00 19:00 1.00 6,231 6,210 COMPZ RPCOM CIRC P Able to slack off, rotate to the riqht and tor ue u. Released rg p~a le from tubin stub. Circulate BU 3 b m 610 si. 19:00 22:00 3.00 6,210 0 COMPZ RPCOM TRIP P POOH stand back DP and DC's from 6,210', LD BHA #3. 22:00 23:00 1.00 0 0 COMPZ RPCOM OTHR P Clean rig floor, load Baker tools. 23:00 00:00 1.00 0 458 COMPZ RPCOM PULD P Pll BHA #4 (6" burn shoe w/ RIH, mill on PBR to 6,254', POOH LD burnshoe assembly, PU RIH with new 6" burnshoe and washpipe assembly, cut and slip drill line, cont millinq on PBR at 6,254'. 00:00 03:00 3.00 458 6 COMPZ RPCOM TRIP P Cont RIH with 6" milling assembly on 3 1/2" DP from 458' to 6,232' and tagged fill, up weight 120K, down weight 100K, rot weight 105K, off bottom tor ue 2K ft/Ibs. 03:00 03:30 0.50 6,232 6,250 COMPZ RPCOM WASH P Break circ at 5 bpm - 900 psi, wash down from 6,232' to 6,250' and ta ed to of PBR. 03:30 11:30 8.00 6,250 6,254 COMPZ RPCOM MILL P Mill on packer assembly, 2 bpm - 650 psi, on bottom torque 3K to 4K ft/Ibs, weight on bit 20K, 60 rpm's, from 6,250' to 6254'. 11:30 13:00 1.50 6,254 6,220 COMPZ RPCOM CIRC P Pre arin to POOH and chanqe out mill. PUH and circulate BU 3 bpm @ 600 si. 13:00 17:00 4.00 6,220 0 COMPZ RPCOM TRIP P Blow down top drive, POOH standing back DP and DC to change out miliin shoe. 17:00 19:00 2.00 0 461 COMPZ RPCOM PULD P LD 2 jnts washpipe and burnshoe, load new washpipe and burnshoe, MU BHA #5. 19:00 21:30 2.50 461 6,170 COMPZ RPCOM TRIP P RIH with BHA #5 (6" burnshoe and washpipe) on 3 1/2" DP from 461' to 6,170'. 21:30 22:30 1.00 6,170 6,170 COMPZ RPCOM SLPC P Slip and cut drill line. 22:30 00:00 1.50 6,170 6,254 COMPZ RPCOM MILL P Cont RIH, ta ed u at 6 254', up weight 120K, down weight 100K, rot weight 108K, off bottom torque 2K ft/Ibs, pumping at 3 bpm - 550 psi, 80 rpm's, cont milling on PBR with 2K to 20K wei ht on bit. 5/25/2009 Mill on PBR, made no footage, POOH to 3,366' and hole fill was 5 bbls off, RIH CBU, mud properties went bad, cont circ and cond mud, POOH LD BHA #5, cleaned tri tank of thick bad mud. 00:00 05:30 5.50 6,254 6,254 COMPZ RPCOM MILL P Cont millin PBR up weight 120K, down weight 100K, rot weight 108K, off bottom torque 2K ff/Ibs, on bottom torque 3K to 4K ft/Ibs, when pumping 3 bpm - 550 psi, 80 rpm's, 2K to 20K weight on bit. Made no foota e. 05:30 08:30 3.00 6,254 6,234 COMPZ RPCOM CIRC P PU off of PBR, CBU at 5 bpm - 1,100 si. 08:30 12:00 3.50 6,234 6,100 COMPZ RPCOM TRIP P POOH to 3360', 5 bbl light on hole fill. RIH to circulate. 12:00 18:00 6.00 6,100 6,100 COMPZ RPCOM CIRC P CBU 3 bpm @ 600 psi. Circulated BU, mud is slightly gas cut, pump and additional BU while run m~d through degasser. Mud properties are out of spec., continue circulating while conditionin mud. 18:00 00:00 6.00 6,100 0 COMPZ RPCOM TRIP P blow down top drive, monitor well, well static, POOH LD jars and washpipe, burnshoe had very little wear. 5/26/2009 24 hr Summarv MU BHA #6 (grapple and overshot), RIH and engage fish, attempt to jar seal assembiy from PBR, could not pull seal assembly free, decision made to perform string shot within the packer to lockup the mandrel and PBR from rotating, performed 2 string shots from 6,252' to 6,270', POOH RD SWS, attempted to release 2 7/8" ra le from fish, could not release, RU to cut tb below overshot. 00:00 01:00 1.00 0 0 COMPZ RPCOM OTHR P Re-dress pumpout sub, clean rig floor, service ri and to drive. 01:00 05:30 4.50 0 6,220 COMPZ RPCOM TRIP P RIH with BHA #6 (5 3/4" overshot with 2 7/8" grapple) on 3 1/2" DP to 6 220', MU top drive, up weight 118K, down wei ht 98K. 05:30 06:30 1.00 6,220 6,220 COMPZ RPCOM CIRC P CBU at 4 bpm - 800 psi. 06:30 12:30 6.00 6,220 6,231 COMPZ RPCOM JAR P Slack off and engage fish, commence jarring at 200K and straight pull to 250K, no movement. Shut down 'arrin . 12:30 17:30 5.00 6,231 6,231 COMPZ RPCOM SVRG P Call out E-line unit. While waiting on E-line, conducted rig inspection (derrick) SOP after jarring. Discussed options with WO En ineers on lan forward. 17:30 23:00 5.50 6,231 6,231 COMPZ RPCOM ELNE P Spot SWS unit, CO e-line head, RU SWS, MU 10' strina shot. RIH and locate packer, perform string shot inside mandrel portion of hanger from 6,260' to 6,270', POOH with e-line, MU new strinq shot, RIH and locate PBR, fire string shot from 6,252' to 6 262', POOH RD SWS. 23:00 00:00 1.00 6,231 6,231 COMPZ RPCOM OTHR P MU topdrive, attempt to rotate and release, top drive torque increased to 5K ft/Ibs~decision made to cut tbq just below overshot, break off 5/27/2009 RIH with 1 3/4" chem cutter, could not pass through 1.8" ID of pump out sub, POOH MU string shot, RIH and shoot across 2 7/8" coupler at 6,243', POOH RD SWS, attempt to blind backoff coupler at 6,243' with no success, rotate to the right to 7K top drive torque, increase up weight to 175K and lost string weight, circ surface to surface, POOH LD overshot assembly and 27.87' of fish, perform weekly BOP test, MU and RIH with burnshoe assembl , CBU, wash down and ta to of PBR at 6,250'. 00:00 05:00 5.00 6,231 6,231 COMPZ RPCOM ELNE P Pull 20K over string weight and set slips, MU 1 3/4" chemical cutter and RIH, could not pass through pumpout sub at 6,200' (1 13/16" ID), POOH LD chemical cutter, MU strin4 shot, RIH to 6 243' and erform strin sho across 2 7/8" cou ler on to of 7' from 6.238' to 6.248', POOH RD 05:00 07:00 2.00 6,231 6,221 COMPZ RPCOM CPBO P Rotate to the left and attempt to backoff overshot assembl and 19' cutoff 'oint from 7' pup, with no success. Rotated to the right bringing top drive torque up to approxiamtely 7K ft/Ibs and increased up weight to 175K, wt dropped and torque freed up. Came loose from fish. PU 10'. RD SWS. 07:00 08:30 1.50 6,221 6,221 COMPZ RPCOM CIRC P Circulate and condition mud at 3 BPM w/800 psi. SD monitor weil, static. 08:30 13:00 4.50 6,221 0 COMPZ RPCOM PULL P POOH standing back drill pipe and drill collars. Break out BHA. Retrieved art of fish from hole. Cut off stub of 2 7/8" tubing 19.82', 2 7/8" pup jt 6.05, crossover and seal locator 2.0'. Parted with clean break 'ust below locator on seal ass . 13:00 17:00 4.00 0 0 COMPZ RPCOM BOPE P Weekly BOPE test. Function test, pressure test BOP rams, choke manifold and annular to 250/3500 psi. Witnessing of test waived by AOGCC (John Crisp) @ 10:45 am 5/27/2009. 17:00 22:00 5.00 0 6,052 COMPZ RPCOM TRIP P Install wear ring, PU and MU BHA #7 (6 1/8" x 4 7/8" burnshoe), RIH on 3 1!2" DP to 6,052', up weight 115K, down wei ht 98K. 22:00 23:00 1.00 6,052 6,052 COMPZ RPCOM CIRC P Break circ and stage pump up to 4 bpm - 1,010 psi, CBU, at bottoms up obtained slow pump rates, 20 spm = 550 si, 30 s m= 620 si. 23:00 00:00 1.00 6,052 6,234 COMPZ RPCOM MILL P Adjust top drive torque, up weight 115K, down weight 98K, rot weight 105K, off bottom torque 3K ft/Ibs, reduce pump rate to 3 bpm - 930 psi, wash down and bumped over top of PBR 6232', rotated down to 6 234' 80 rpm's, bit weight 2K, start millin on PBR 6234'. 5/28/2009 Mill on PBR with 6 1/8" burnshoe from 6,234' to 6,244', circ hole clean, POOH LD burnshoe assembly, PU RIH with overshot, engage top of PBR and attempt to engage packer and PBR. Chased PBR/packer down hole and finally stacked out at 6,443', had 5K over previous up weight, PU 10' and circulated hole volume with ve little as at bottoms u, POOH from 6,433' to 2,144'. 00:00 07:30 7.50 6,234 6,244 COMPZ RPCOM MILL P Up weight 115K, down weight 98K, rot weight 105K, off bottom torque 3K ft/Ibs, on bottom torque 3 to 4K fUlbs, pump rate 3 bpm - 930 psi, 80 rpm's, bit weight 2 to 13K, milling on PBR from 6 234' to 6244' tor ue dro ed off and indicated mill was at the element on the acker. 07:30 08:00 0.50 6,242 6,242 COMPZ RPCOM CIRC P PU 2' and circulated hole clean @ 5BPM w/1600 psi.. Metal shavings and rubber from packer element in returns. 08:00 ~ 12:30 ~ 4.50 ~ 6,242 ( 0 RPCOM TRIP P Shut down pump, monitor weli, static. Blow down TD, fill trip tank. POOH from 6242' standing back driN pipe and drill collars, LD BHA. Empty outjunk baskets. Captured several siivers milled off the side of 12:30 17:00 4.50 0 6,111 COMPZ RPCOM TRIP P Clean rig floor and set tools up for RIH. MU BHA #8 consisting of Overshot for 4 3/4" fishing neck, BS &jars, 18 DC's and accelerator. RIH to 6111' obtained slow pump rate of 750 psi @ 2 BPM. Up wt 123K dwn wt 105K. 17:00 19:00 2.00 6,111 6,433 COMPZ RPCOM FISH P Attempted to taq up on fish Ca~ 6232'. packer had approximately 10' and was loose, chased to 6443' stacking 20K wt to engauge overshot. PU on fish was free~ up wt was 128K (5K extra). Stacked out 3 more times to make sure overshot was engauged and could not push downhole any more. PU 10'. 19:00 20:00 1.00 6,433 6,433 COMPZ RPCOM CIRC P Circulated hole volume to clear of any gas possiblv trapped under acker @ 3 BPM w/880 psi increased to 4 BPM w/1060psi. . Circulated until hole cleaned up, no as. 20:00 00:00 4.00 6,433 2,144 COMPZ RPCOM TRIP P Blew down top drive, slacked off and tagged/stacked 20K on string to ensure we still had fish to 6,443', POOH slow, up weight 130K with no indication of drag through perfs or milling location, to 2,144'. Had prooer hole fill entire trip. Cont POOH, no fish, CO grapple assembly to a basket grapple, RIH and attempt to engage fish, POOH LD PBR/Packer assembly, RU SWS and make junk baskeUgauge ring run, POOH, MU lower packer assembly, RIH and set at 6,422', POOH RD SWS, RIH with 6 stands 4 3/4" DC's for la down of same. 00:00 02:30 2.50 2,144 0 COMPZ RPCOM TRIP P Cont POOH with BHA #8 from 2,144' to surface and had no fish, no indication that top of fish entered uide, LD BHA #8. 02:30 04:30 2.00 0 0 COMPZ RPCOM TRIP T MU close catch basket grapple extensions, wrong size guide delivered, waited on delivery of correct uide shoe. 04:30 08:00 3.50 0 6,443 COMPZ RPCOM TRIP P MU correct guide for close catch basket carapple and RIH. a 08:00 ~ 08:30 ~ 0.50 ~ 6,443 ~ 6,432 08:30 ( 10:00 ~ 1.50 ~ 6,432 ~ 6,432 10:00 ~ 14:30 ~ 4.50 ~ 6,432 ~ 0 RPCOM FISH P Up wt 125K Dwn wt 105K. Taqqed fish aC"). 6443 w/rotating @5 RPM, 1 BPM W.350 psi. Pushed fish down to 6461' and worked overshot onto fish with 20K down wt. PU wt was 150K (25K over) dropped off to 133K (8K over). Puiled up approximately another 42' to see if packer would drag or catch on casing collar, small overpuli 1 K to 1500. Stopped here @ 6432' to circulate. RPCOM CIRC P Circulate bottoms up to remove any gas from under the packer. 2 BPM RPCOMITRIP I P down to 6411' set down 15K, no movement. POOH standing back workstring. Fishing run successful. Recovered AVA PBR w/seal assy inside, AVA RHS Retv. Packer, 2 jts 2 7/8" tubing, Camco 'D' nipple, and AVA SOS WLEG. 14:30 16:00 1.50 0 0 COMPZ RPCOM PULD P Break fish down and LD. Break out fishin tools and LD. Clean ri floor. 16:00 20:30 4.50 0 0 COMPZ RPCOM ELNE P PJSM w/crew and SWS E-line. RU E-line equipment. RIHw/gauge ring and junk basket to 6,539', POOH, junk basket full of rubber and metal shavings, decision made to re-run junTcTasket, RIH to 6,539', POOH and had ve little 'unk in basket. 20:30 00:00 3.50 0 0 COMPZ RPCOM ELOG P MU Baker'F-1' Packer and running tool, RIH on e-line to 6,422', correlated depth with CBL, set packer top at 6,422', POOH LD runnin tool and RD SWS. 5/30/2009 LD 18 jnts 4 3/4" DC's, PU upper packer assembly and RIH on 3 1/2" DP to 6,420', dispiace well to seawater, spot inhibited seawater and stab seal assembly, space out 1' from no-go, drop ball and rod, set packer, PT packer, shear PBR and POOH LD 1,000' DP, MU storm packer, RIH 100' and set, ND BOP, CO tbg head and ackoff, NU BOP. 00:00 01:30 1.50 0 0 COMPZ RPCOM PULD P RIH with 18 jnts 4 3/4" DC's, from derrick, POOH LD same. 01:30 02:00 0.50 0 0 COMPZ RPCOM PRTS P Test 7" csg x Baker'F-1' packer at 1,500 psi for 5 minutes on chart, ood test. 02:00 08:30 6.50 0 6,420 COMPZ RPCOM RCST P CO handling equipment to run 3 1/2" EUE, CO perforated joint on seal assembly and RIH, PU RIH 8 jnts 3 1/2" tb , PU RIH with Baker 84-SAB Packer Assembl , Anchor Seal Assy, and 80-40 PBR, MU XO, CO handling equipment to run drill pipe, cont RIH on 3 1/2" DP from derrick to 08:30 09:00 0.50 6,420 6,420 COMPZ RPCOM PACK P Established circulation 700 psi @ 1 BPM. Up wt 110K dwn wt 95K. Located seais pressureincreased as seals enter PBR, Shut down pump and stacked out on locator @ 6422'. PU to neutral wt plus 1', marked i e. Puiled seais back out 2' above PBR. 09:00 13:00 4.00 6,420 6,420 COMPZ RPCOM CIRC P Circulated and displaced 13.1 ppg KWF by pumping 40 bbl Hi Visc sweep (spacer) 50 bbls Sea Water, another 40 bbl Hi Visc Sweep (spacer) followed by seawater until hole cleaned up, saving the 13.1 ppg for future use. Spot 20 bbls of 13:00 14:00 1.00 6,420 6,427 COMPZ RPCOM PACK P Broke 1st connection and dropped ball and rod and allowed 15 min. to drop. Up wt 115K Dwn wt 108K. Lowered seals back down into PBR. Pressure up and set u er SAB acker. Packer started setting process at 1850 psi. Walked pressure up and PBR sheared @ 2350 psi. Bled pressure to 0. Slacked off 2500K on packer. Pressured un to 4000 psi and held f r 15 min. to full com ress acker. Bled pressure to 0. Pressure IA to 1500 si to ensure acker set. 14:00 16:00 2.00 6,427 5,527 COMPZ RPCOM PACK P Bled off pressure. Pulled out of seals on upper PBR. POOH laying down 1000' of 3 1/2' drill pipe. PU and RIH w/ storm acker and set 100'. PT to 1000 si. bled res 16:00 18:30 2.50 5,527 5,527 COMPZ RPCOM NUND P NDBOP. 18:30 21:30 3.00 5,527 5,527 COMPZ RPCOM EQRP P Remove tb head and packoff, install new packoff and tbg head, test to 3,000 si for 15 min, test ood. 21:30 00:00 2.50 5,527 5,527 COMPZ RPCOM NUND P NU BOPE. 5/31 /2009 Test breaks on BOP, retrieved storm packer, POOH LD 3 1/2" DP, pulled wear ring, PU RIH with 3 1/2" completion and jewelry to 6,133', located and no-go'd seal assembly, spaced out, MU hanger and landed same, tested tb and IA, sheared SOV, tested SCSSV, installed BPV, ND BOP. 00:00 00:30 0.50 5,527 5,527 COMPZ RPCOM NUND P Cont NU BOP stack. 00:30 02:00 1.50 5,527 5,527 COMPZ RPCOM BOPE P RU and test BOP breaks at 250/3,500 psi, good test, pull test plug, RD test equipment. Witnessing of shell test waived by AOGCC (Jeff Jones 2:00 m 5-30-2009. 02:00 08:00 6.00 5,527 0 COMPZ RPCOM PULD P RIH and retrieve storm packer, POOH LD same, cont POOH LD 3 1/2" drill pipe. Inspect seal assembly and it looks good for rerun. Remove wear rinq. 08:00 09:30 1.50 0 0 COMPZ RPCOM SLPC P PJSM. Siip and cut drill line. 09:30 18:00 8.50 0 6,133 COMPZ RPCOM RCST P Set up Elevators, slips and tongs for running 3 1/2' completion. PU & RIH w/ the 3 1/2' com letion to 6133'. 18:00 20:00 2.00 6,133 6,143 COMPZ RPCOM HOSO P Up wt 80K Dwn wt 77K. With pump running @ 1/2 BPM lowered seals into PRR until pressure increase to confirm seals are in place, shut down pump and tagged locator 12' down, LD 3 jnts, spaced out, MU FMC hanger, pup, control line and landing jnt, lowered seals into PBR until pressure increase, drained BOP stack, landed hanger, RILD's, seal assembl mule shoe set at 6,143'. 20:00 22:30 2.50 6,143 6,143 COMPZ RPCOM DHEQ P Ru and ressure tested tb at 3 000 psi for 15 minutes on chart (good test , bled tbg to 2,000 psi, ressured u on IA to 3,000 si for 30 minutes on chart (good test), bled IA to 0 psi, then bled tbg to 0 psi; increased pressure on IA and sheared SOV at 1,800 psi, tested SCSSV from below (throu h G~M) at 1,000 psi for 5 minutes on chart (good test), bled off to 0 psi, LD landin 'nt, installed BPV. 22:30 00:00 1.50 6,143 6,143 COMPZ RPCOM NUND P ND 13 5/8" BOP. 6/01 /2009 Install tree test plug, NU tree, tested tree and void, open SCSSV, pull BPV, RU and reverse circ 130 bbls inhibited seawater followed with 90 bbls diesel to freeze protect, u-tube well, set BPV, dress tree, RDMO well. 00:00 00:30 0.50 0 0 COMPZ RPCOM NUND P Cont ND 13 5/8" BOP. 00:30 02:30 2.00 0 0 COMPZ RPCOM NUND P NU tree. oull BPV. set test olua. test tbg hanger void and tree at 250/5,000 si for 10 minutes ood test . 02:30 03:00 0.50 0 0 COMPZ RPCOM RURD P P II test lu RU circ lines in cellar, spot LRS, test circ lines at 250/1,500 si. 03:00 04:00 1.00 0 0 COMPZ RPCOM CIRC P Reverse circ 130 bbls inhibited seawater off vac truck, at 4 bpm - 1,300 psi down IA taking returns to its. 04:00 06:00 2.00 0 0 COMPZ RPCOM FRZP P RU LRS circ lines and test at 250/3,000 psi, pump 90 bbls diesel down IA at 2 bpm - 700 psi, to freeze rotect well, RD LRS, put tbg x IA in communication and allow to u-tube diesel. 06:00 08:30 2.50 0 COMPZ RPCOM RURD P Disconnect hoses from U-tube. Set BPV. Dressed tree. Move rig off well. Cleanout cellar with Super Sucker. Released Nordic 3 ri 08:30 hrs 6-1-2009. ;~ ? ~~} ~' < a ~.. Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # __ ~~ ~ ^`~ i ~ a a~~.~ y~ n ~, ~-~ M AY ~ ~ 2009 ~~aska iii ~ has ~s• ~~'~rnassi0€~ Ar~chUr~g~ Log Description NO. 5228 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/12/09 3A-18 AYS4-00069 PERF/SBHP SURVEY - 6 -' 04/26/09 1 1 3C-08 B14B-00033 GLS ~ / 04/21/09 1 1 2M-25 B14B-00034 GR/TEMP LOG /9 (- 04/22/09 1 1 1 R-19A AYS4-00065 SBHP SURVEY -r G ' `'- 3Co 04/23/09 1 1 3G-13 AYS4-00067 SBHP SURVEY - ( 04/24/09 1 1 3G-05 AYS4-00066 SBHP SURVEY 04/24/09 1 1 3F-07 8148-00038 SBHP SURVEY - ~ 04/24/09 1 1 3F-08 B14B-00037 SBHP SURVEY '- 04/24/09 1 1 3M-25A B14B-00040 SBHP SURVEY 3 04/25/09 1 1 3K-OS B14B-00039 SBHP SURVEY C./ 04/25/09 1 1 2N-318A AWJI-00026 MEM BHP SURVEY -Q 04/27/09 1 1 2Z-07 B14B-00045 SBHP SURVEY L 04/29/09 1 1 2Z-01A 6148-00044 SBHP SURVEY ~-_ ~ d 04/29/09 1 1 3K-102 ANHY-00080 GLS 04/30/09 1 1 2W-06 B04C-00036 PRODUCTION PROFILE 05/02/09 1 1 2W-12 B04C-00037 PRODUCTION PROFILE - p 05/03/09 1 1 3C-02 B04C-00045 POWERCUTTER W/SBHP SURVEY 05/09/09 1 1 1J-120 604C-00043 GLS ~ ~ " ® 05/08/09 1 1 31-11 604C-00044 SMALL TBG PUNCH W/SBHP 05/08/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • ~~~ • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • ,- ~~~-;. , ~~., ,' b: ~F,~„3. ~~ ~ ~ ~ ` ~v1~~'" ~ 20C~ ~~~ ~~ 1 ~ ~' ~ ` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped April 7th , 2009. The corrosion inhibitor/sealant was pumped April 15th and 16th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 31-01 185-307 58' 10.10 4' 1" 4/7/2009 4.40 4/15/2009 31-03 185-309 69 '8" 10.20 4' 3" 4/7/2009 8.50 4/15/2009 31-04 185-310 26' 4" 4.10 2' 4R/2009 3.40 4/15/2009 31-05 186-036 76' 12.70 3' 6" 4/7/2009 8.50 4/15/2009 31-08 186-040 8' 6" 1.20 1' 9" 4/7/2009 3.40 4/15/2009 31-09 186-055 40' 5.10 1' 9" 4/7/2009 3.40 4/15/2009 31-11 189-035 1' 9" N/A N/A N/A 2.60 4/16/2009 31-12 186-060 44' 6.80 1' 11" 4/7/2009 2.60 4/16/2009 31-13 189-025 SF N/A N/A N/A 2.50 4/16/2009 31-14 186-062 77' 11.30 2' 11" 4/7/2009 8.50 4/16/2009 31-16 189-022 24' 3.54 1' 7" 4/7/2009 2.30 4/16/2009 31-17 189-024 37' 3.64 1' 7" 4/7/2009 2.00 4/16/2009 ~ II- ( WELL LOG TRANSM /TT AL (" \Sq 'CßS ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 Anchorage, Alaska 99501 RE: Distribution - Final Print[s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE LOG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH 31-11 1-11-04 Caliper Survey 1 Apt or 2 Color Signed: ~ - ="" ""~ê)~~ ~~~ Date: RECEIVED Print Name: I ^ ~'.I 2 0 f}OO4 \oJ) \¡. " Alaska Oil & Gas Cons. CO~n Anatøase PRoAcTivE DiAGNOSTic SERviCES, INC., PO Box 1 }b9 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com SCANNED FE B 0 2 2004 ~~b\\\~ Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 76' 1. Operations Performed: ~ ~ Abandon STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing D Perforate New Pool D 4. Current Well Status: Development - B Stratigraphic D Perforate D Variance D Annular Disp. D Stimulate D Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 189-035/ 6. API Number: 50-029-21932-00 Exploratory D Service D 9. Well Name and Number: 31-11 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: 10. FieldlPool(s): Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SURF. CASING PROD. CASING Perforation depth: measured 6772' feet true vertical 6560' feet measured 6772 feet true vertical 6560 feet Length Size MD 116' 16" 116' 3307' 9-5/8" 3383' 6685' 7" 6761' Plugs (measured) Junk (measured) Burst Collapse TVD 116' 3383' 6550' Measured depth: 6437-6454,6457-6486,6494-6503' RECEIVED MAY 2 0 2004 Alaska Oil & Gas Cons. Commission Anchorage " true vertical depth: 6245-6261, 6264-6291, 6298-6306' Tubing (size, grade, and measured depth) 2-7/8', J-55, 6334' MD. Packers & SSSV (type & measured depth) pkr= AVA RHS RETR. pkr-- 6262' SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Oil-Bbl 125 132 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 42 355 7 725 15. Well Class after proposed work: Exploratory D Development 0 16. Well Status after proposed work: oil0 GasD WAGD WDSPLD CasinQ Pressure 1262 1424 TubinQ Pressure 146 142 Service D GINJD WINJD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact Dethlefs/McConnell :~:::~:ame 1:~: ~~~~ ~ Title Problem Well Supen. Phone 659-7224 Date ø-# RBDMS Bfl MAY 2 V 2004 SUBMIT IN DUPLICATE Form 10-404 Revised 2/2003 . OR\G\NAL /,"",-, ~ ConocoPhilIips Alaska, Inc. Kuparuk Well 31-11 (PTD 1890350) Report of Sundry Operations 05/17/04 ConocoPhillips Kuparuk production well 31-11 tubing was patched 01/24/04 to repair a tubing leak at 5896' MD. The patch is 2-7/8", 20-feet long, permanent style. The patch set depths are: Top: 5881' MD Bottom: 5903' MD NSK Problem Well Supervisor 05/17/04 TUBING «().6334. OD:2.875. ID:2.441) sos (6333-6334. OD:2.875) Perf (6437-6454) Perf (6457-6486) Perf (6494-6503) /"""., ConocoPhilUps Alaska, Inc. 3¡";11 API: 500292193200 SSSV Type: Nipple ,-.., KRU 31-11 ."" Well Type: PROD Orig 4/4/1989 Completion: Last W/O: 4/21/1999 Angle @ TS: 22 deg @ 6401 Angle @ TO: 19 deg @ 6772 Annular Fluid: Reference Log: Last Tag: 6436' WLM LastTa~ Date: 11/10/2003 tasmjfStOnø: ~ ALL STRINGS Description CONDUCTOR SURF. CASING PROD. CASING Tùbinø.Strlng'~ TUBING Size I Top 2.875 0 PerforatlØns"Summary Interval TVD 6437 - 6454 6245 - 6261 6457 - 6486 6264 - 6291 Ref Log Date: TD: 6772 ftKB Max Hole Angl~: , 24 deg @ 5300 Rev Reason: GLV design, set patch Last Update: 1/29/2004 . "'C",.', Size Top Bottom TVD Wt Grade Thread 16.000 0 116 116 62.50 H-40 9.625 0 3383 3383 36.00 J-55 7.000 0 6761 6550 26.00 J-55 Bottom TVD Wt Grade I Thread 6334 6150 6.50 J-55 EUE 8RD AB MOD Zone A-3 A-2 6494 - 6503 6298 - 6306 Gas LlftMaì'ídtelSAlEllYes/' St MD TVD Man Man Type Mfr 1 2597 2597 Cameo KBMM 2 4250 4236 Cameo KBMM 3 5246 5152 Cameo KBMM 4 5736 5601 Cameo KBMM 5 6195 6022 Merla TGPD Oth~rctþlugS.;ØQul ).;.etC.):" JEWELRY Depth TVD Type 500 500 NIP 5881 5734 PATCH 6250 6072 PBR 6262 6083 PKR 6299 6117 NIPPLE REDUCER 6299 6117 NIP Cameo D Nipple 6333 6149 SOS AVA 6334 6150 TTL Gênel'a'. Nôtü . . Date I Note 10/23/200~TUBING LEAK CONFIRMED @ 5896' A-1 Status Ft SPF Date Type Comment 17 8 3/6/1990 IPERF 21/8" Dyna Strip, 60 deg ph 29 4 5/18/1989 IPERF 4.5"HSD Csg Gun, 90deg ph 9 8 3/6/1990 IPERF 2 1/8" Dyna Strip, 60 deg ph VMfr V Type VOD Latch CAMCO DMY 1.0 BK CAMCO DMY 1.0 BK CAMCO DMY 1.0 BK CAMCO DMY 1.0 BK MERLA DMY 1.5 RK Description Port TRO Date Run 0 12/28/2003 0 12/28/2003 0 12/28/2003 0 1/1/2004 0 4/27/1999 Vlv Cmnt 0.000 0.000 0.000 0.000 0.000 Otis 'D' Nipple 2.875" HES PERMANENT PATCH set 1/24/2004 AVA hydr. release AVA RHS Retr. AVA 2.25" X 1.81" NIPPLE REDUCER SET 1/22/2004 ID 2.313 1.860 2.750 2.347 1.810 2.250 2.441 2.441 ( (I 'DCf-O35 Memory Multi-Finger Caliper log Results Summary Company: CONOCOPHILLIPS Well: 31-11 Log Date: January 11, 2004 Field: Kuparuk Log No. : 5352 State: Alaska Run No.: 1 API No.: 50-029-21932-00 Pipe1 Desc.: 27/8" 6.5Ib. J-55 EUE 8RD Top Log IntvI1.: Surface Pipe1 Use: Tubing Bot. Log IntvI1.: 6,296 Ft. (MD) Inspection Type: Tubing Patch Assessment COMMENTS: This caliper data is tied into the GLM 5 @ 6,195' (Driller's Depth). This log was run to identify locations of TXIA communication and assess the condition of the tubing with respect to corrosive and mechanical damages for potential patching operations. The caliper recordings indicate that the 2 7/8" tubing is in good to poor condition, with 1 HOLE recorded in Joint 183 @ 5,895'. The majority of tubing appears to be in good condition with 197 of the 210 joints logged showing maximum recorded penetrations of less than 20% wall thickness. The damage is recorded in the form of Isolated Pitting. There are no areas of significant Cross Sectional Wall loss or I.D. restriction recorded throughout the tubing. A 3D Log Plot of the recordings area of the Hole is included in this report. Cross-sectional drawings of the most significant events recorded are also included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Hole (100%) Jt. 183 @ 5,895 Ft. (MD) Isolated Pitting. ( 36%) Ji. 192.1 @ 6,190 Ft. (MD) Isolated Pitting. (31%) Jt. 190 @ 6,095Ft.(MD) Isolated Pitting ( 29%) Jt. 192 @ 6,172 Ft. (MD) Isolated Pitting ( 28%) Jt. 193.1 @ 6,245 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No Significant Cross-Sectional Wall Loss (>11%) is recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: RECEIVED No significant 1.0. restrictions are recorded throughout the interval logged. ~. '1!\O4 !^'d?OiV ~i '\\ ~ L... ' . Alaska Oil & Gas Cons. Commisian Anchorage I Field Engineer: R. Richey Analyst: J. Thompson Witness: M. Channey I ProActive Diagnostic Services" Inc. ,I P.O. Box 1369,. Stafford, TX 77-497 Phone: (281) or (888) 565-9085 Fax: (281) 56,5-1369 E-mail: PDS(~})memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 ~(;A~~~~~~) rED Vi 2 200¿~, ~~~N\~ 1 I I I 5840 5850 Joint 182 5860 5870 5880 Joint 183 Hole @ 5895' 5890 5900 5910 Joint 184 5920 I 5930 I ew n IS Weli: :31-1Î Survey Date: januaryll,2004 Field: KUPARUK Tool Type: MFC 24 No 99628 Company: CONOCOPHILLIPS Tool Size: 1.69 Country: USA No. of Fingers: 24 Penetration and Metal Loss wall) Damage Profile wall) t t" . t II penetration metal loss pene ra Ion me a oss 50 100 200 r' ,. -,----, I i ! ! I I I 150 I I II I I I 100 I I , I I I I I I I ¡ I I . I [I I I ' 'I 50 ! I I I i O. I I, I I I 0 to 1 to 10 to 20 to 40 to over '[ i I 'II ¡'I' 1°/" 10°;\) 20'Yo 40% 85'Yo 85'Yo I! I I , I [ I I I I, \ I I. I I I pene. 0 1 11111'111' loss 0 0 I I GLM 1 I I ! I 1 I I I II i I Damage ( body) I I I I I I I i I I I I 100 I. ¡ I II 1 I I i I I I I 80 i I I I I I I GLM 2 I I 1 I I I I 60 I I . I ' I I I I i I 40 I 'I I I I \ i I II' I I I ' 20 I I I GLM:3 I 1 I I I I i I ! I I 0 ' I' isolated general line ring hole I I I pining corrosion corrosion corrosion ihle GLM 4 GLM 5 Bottom of Survey = 194 Analysis Overview page 2 jOINT TAB N Pipe: 2.875 in 6.5 J-55 EUE8RD 'vVell: 31-11 Body Wall: 0.217 in Field: I<UPARUK Upset Wall: 0.217 in Company: CONOCOPHILUPS NominaIID.: 2.441 in Country: USA Survey Date: Januaryl1, 2004 Joint Depth Pen. Pen. Pen. Metal Mi! J;mlri"p Profile No. (Ft.) Upset Body % Loss ¡D. Comments ('Yo wall) (Ins.) (Ins.) % (Ins.) 0 50 100 .131 0 0.03 13 3 2.37 IIi 1 35 0 0.03 12 1 2.39 1- ~ 1.1 66 0 0.03 I 11 1 1 2.38 I -- I!IiI f_12_____ZQ - 0 0.02 I 10 I 3 2.37 2 86 0 0.04 16 I 6 I 2.38 Shallow pitting. 3 1111 0 003 16 4 2. Shallow pitting. 4 149 0 0.03 1 (1 2 2. Shallow niuinl!.. Lt. DePosits. ¡; 1 R 1 0 0.03 1 S3 2. $_hiÜ!9_YVQ]tting. --- 6 I 212 0 0.0417 5 2. Shallow oittimL 7 _L43 0, 0.02 10 2 2.38 8 275 0 0.03 14 1 2.39 9 306 0 0.03 113 I 3 2.38 I Lt. Deoosits. 10 338 .. -0 0.03 15 3 2.38 I Shallo~=R.itifng. 11 i 369 n 0.04 17 6 2.37 Shallow Qi1:tjDg,_U,D~p_Qsits. 12 I 401 0 0.04 17 3 2.39 I Shallow pitting. 11 I 432 0 0.03 11 5 2.38 1 14 464 0 0.03 13 1 2.37 14.1 496 0 0.03 12 0 2.37 P JI Lt. 14.2 502 0 0 0 0 2.31 SSSV 14.i C;Oi 0 0.04 17 3 2.39 P JI II) 1') '513 0 0.03 14 ').39 Shallow pitting 1h 545 0 0.03 13 I 3 I 2.37 Lt. Deposits. ~ S7n 0 0.03 11 I -_::to_. ¡1__2.38 , 18 608 0 0.03 I 15 2 2.38 I Shallow oittin;z. Lt. DeDosits. , 19 640 0 0.03 15 9 I 2.38 Shallow oittin". I 20 671 0 0.01 3 1 I 2.37 r 21 702 0 0.04 18 3__2,1ß_~Shallow pitting. Lt. D~!LQ.iÍts, --L 22 734 0 0.03 I 15 1 7.37 I Shallow pitting. r' 21 765 0 0.)2 11 1 2.39 I ,.~ 24 797 0 O. )2 11 1 2.39 r-. 25 829 () O. Jl 7 1 2.017 'fP2 26 860 0 O. )3 13 1 2.38 I'" 27 12 0 0.03 15 3 2.38 Shallow oittina. 28 4 0 0.03 14 2 2.38 79 nO 0.02 10 2 2.39 iO ,f; 0 0.04 17 2 2.38 Shallow pitting !Jt 31 10tH -f) 0.03 15 3 2,17 Shallow pitting 32 lOS0 0 0.04 17 3 2.38 Shallow pitting. Lt. 33 1081 0, 0.02 '9 0 2.39 . 34 1113 0 0.03 1 14 ! 2 ! 2.39 I Shallow oittin". 35 45 0 0.03 14 2 2.37- 36 76 0 0.03 14 4 2.39 17f)f\ () 0.01 15 4 2.38, Shallow pittin".-.. u iB "19 0 0.01 1 ¡:; 2 2.37' Shallow pitting,_--_- 39 1271 0 I 0.04 1ß 5 2.39 Shallow oittin\!. 40 1303 0 0.05, 22 I 3 I 2.39 Isolatedpitting.- 41 1334 0 I 0.03 I 14 4 2.38 Shallow oitting. Lt. Deposits. I 42 1366 0 0.03 I 15 6 2.39 Shallow oittinR.. Lt. Deposits. --- I 43 1397 0 0.04 18 I 5 2.38 Shallow pitting. II 44 1479 0 0.03 13 3 2.38 . -- ---- I Penetration Body Meta! Loss Body Page 1 J NT TABU N Pipe: 2.875 in 6.5 J-55 EUE8RD WeB: 31-11 Body Wall: 0.217 in Field: KUPARUK Upset Wall: 0.217 in Company: CONOCOPHILLIPS Nominal I.D.. 2.441 in Country: USA Survey Date: Januaryl], 2004 Joint Depth Pen Pen. Pen. IVletal Min. ¡>. ¡;, No. Upset % Loss Comments (% wall) (Ins.) (In ;.) 'Yo (Ins.) 0 50 100 45 1460 0 0.0418 6 2.38 Shaliow I 46 1491 0 0.04 20 8 2.38 I,o! ted pitting. I 47 1523 0 0.04 19 6 2.38 I 41 554 0 0.04 17 4 2.38 ! 4' SBh 0 om 16 3 7.3h itting. I 51 6 7 0 0.04 1 c¡ 3 2.38' Shallow pin.ill~....._.._- S h49 0 0.04 18 7 2.39 Shallowoittino. 52 h80 0 0.04 18 6 7.37 53 1711 0 0.02 11 4 2.39 54 1743 0 0.04 19 4 2.37 Shallo\l\l~___-- 55 1775 0 0.03 14 3 2.37 ._-~-_._--_._- 5( 806 0.0 14 3 2.37 5 838 0.0 8 2 2.37 5: 870 00 12 2 2.40 5 901 0.0 12 1 2.37 6( 932 0.012 6 2.36 61 1963 0 0.03 13 1 2.37 6. 1994 0 0.02 9 2 2.37 !!II 6 2026 0 0.03 12 1 2.37 !I!II! 6, 2058 0 0.03 14 3 2.38 Shallow pitting. 6: 2089 ( 0.03 14 3 2.39 h( 2120 ( 0.03 16 1 7.36 ittino. 6 7152 ( OrB 113 ! 2 I :1.35 63 2183 0.02 9 2 2.37 . ' 69 2215 0.04 19 10 2.37 5ballow pitting. Lt. Deposits. ---~lfIiIj 70 2246 0 0.03 13 2 I 2.36 71 2278 0 0.04 16 3 I L37 I Shai!9wpitting,_- II 72 2309 0 0.03 4 7, 2.37 Shallow pitting. I 73 2341 0 0.03 2 2 2.36 74 7173 0 0.04 b 1 2.36 Shallowoittine.. It. npnn,it, 7S 2404 0 0.04 S 3 2.37 Shallow Dittine.. Lt. iii 76 2436 0 0.02 10 4 2.33 l 77 2466 0 0.03 16 1 2.37 haowpttine.. 7B 24' 0 0.0418 0 2.371aowptting. II!J 79 25: 0 0.03 15 2 2:7 ha ow ping. 8C 25()( 0 0.03 16 3 2 \6 ha ow ping, It. RO. 7.' 0 om 1 S 4 7!f) PUP Sh;¡llow Dittin2. RO.2 7.' J8 O. 0 0 0 !\ 'A GlM 1 No Deviation --I 80.3 2i )4 0 0.04 20 4 .34 PUP Corrosion. SI 2i 0 0 0.05 21 2 .35 Isolated oittine.. It. 82 2642 0 0.04 21 1 2.35 (-, 83 2673 I 0 I 0.04 18 2 2. \6 Shallow pitting. 84 2705 0 0.06 26 2. is Corrosion. 85 2735 0 0.03 15 2. :5 Shallow nittin2. REi 2767 0 o.m 12 2.Jf) ¡- 87 2798_-.......J!. OJJ4 17 2.36 ShallowRitting._~ ~111 88 2830 0 0.03 15 2 2.37 Shallowpìttíng. .~.... :J!J!!1 89 2862 0 0.03 13 2 2.36 It. Deoosits. 1 90 2893 0 0.04 18 2 2.37 Sbi!llowpit.ti~_----=-- '" 91 2925 0 0.03 12 2 2.35 1111 Penetration Body Metal Loss Body Page 2 PDS REPORT jO¡ ULA TION S Pipe: 2.875 in 6.5 J~55 EUE8RD Well: 3!~ 11 Body Wall: 0.217 in Field: KUPARUK Upset Wall: 0.217 in Company: CONOCOPHILUPS Nominal 1.0.: 2.441 in Country: USA Survey Date: Januaryll, 2004 Joint Depth Pen. Pen. Pen. Metal Min. 1m çp prom Upset Body % Loss to. Comments ('Yo Úns.) (Ins.) % (Ins.) 0 50 100 92 2,),)fi 0 0.04 17! 2 23fi S 1a ow nittim!. Lt. IIII~ 93 2988 0 0.03 16 1 2.37 S 1a ow Ditting. L1. IIII~ 94 3019 0 0.03 15 2 2.36 L1. IIII~ 9 r:; 1051 0, . 0.04 I 16 ! 2 2.36 fliF* 96 3082 0 0.03 14 1 2.36 l1li, 97 3113 0 I 0.04 17 2 2.37 ShaIIQ','V.....Qitting. L1. DeDosits. ~~ 98 3145 O! 0.04 18 1 2.36 I Shallow pitting. L1. Denosits. 99 3176 0 0.04 18 3 2.3 7 I Shallow pittil}g~~h ~-~~-- h~~h~~ 100 3208 0 0.03 16 3 2.37 Shallow oittin2. 101 i/i,) 0 0.O3! 13 I 1 ! 2.37 102 3271--'0'- -b.O3 14 I 5 2.37 103 3303 0 0.03! 16 3 2.39 104 3334 0 0.03 12 I 3 2.39 105 3365 0 0.03 I 15 2 2. 106 3397 0 0.02 10 3 2. 107 3429 0 0.03 14 7 7 108 I 3460 0 0.04 21 8 2. Isolated oittin2. ! 09 3492 0 0.03 12 2 2. 110 3523 0 0.03 12 2 2.38! 111 3555 0 0.03 13 2 2.36 112 3587 0 0.04 17 4~2.37 <"L.II. 113 3618 0 0.03 14 3 2.38 I JJ.1 1. 3650 0 0.02 9 .. 1 2.31 I L1. Deposits. I ~ 0.03 12 3 2.34 I L1. Denosits. I!ií 116 3713 0.03 0.04 18 I 4 2.35 I Shallownittin2. u.npnn<itc , 117 3744 0 0.03 1212.371 I!ií 118 3775 0 0.03 13 2 2.38. I!ií 19 3807 a 0.03 13 1 2.36 filii: ¡ 20 I 3838 I 0 I 0.03 I 12 ! 2 2.38 i21 3870 a I 0.02 9 2 2.36 i22 3901 a 0.02 7 4 2.35 I 23 3931 0 0.02 9 1 2.16 124 3964 (J 0.02! 9 3 2.34 125 1994 0 (J.02 9 1 2.38 126 4026 a 0.02 10 2 2.38 127 4057 0 0.02 9 2 2.37u 128 4089 0 o.~)]. 2.38 129 4120 0 0.04 38 Snallow.....QittiDK, 111 no 41S7 0 0.02 2.34 11 1 41 R4 0 0.02 9 I 2. if) I 132 4215 0 0.03 12 I 3 2.38 132.1 4246 0 0.03 13 I 2 2.36 I PUP L1. Deoosits. 132.2 4253 0 0 0 I 0 ! N/A GLIVI 2 No Deviation U2.3 4259 0 0.04 20 1 2.33 PLJr L1. I!ií l1li B 4265 0 0.03 15 3 2.36 Shallow pitting. L1. Deposits. 34 4297 0, 0.02 10 I 3 2.37 35 4328 0 0.03 I 12 I 3 2.37 36 4360 0 0.03 15 2 2.38_5bSlIlQv\lpjttillg.~--~~- 137 4392 0 0.03 12 3 2.37 138 4423 0 0.04 17 3 2.34 Shallow GiUing. I II I Penetration Body Metal Loss Page 3 JOINT U N Pipe: 2.875 in 6.5 J-55 EUE8RD Well: 31-11 Body Wall: 0.217 in Field: KUPARUK Upset Wail: 0.21 7 in Company: CONOCOPHilUPS Nominal 1.0.: 2.441 in Country: USA Survey Date: Januaryll, 2004 Min. n: Joint Depth Pen Pen. Pen. Metal 0, '" u"", No. Body 'Yo loss I.D. Comments wall) O.ns.) (Ins.) (Ins.) 0 50 100 139 4455 0 0.02 11 2 2.37 - 140 4486 0 0.03 14 4 2.39 ¡II! 141 4517 0 0.02 9 1 2.39 ill 14) 4548 0 (un 12 3 2.36 ¡II! 143 4581 0 0.04 8 2 2.37 iWno. ¡II! 144 4613 0 0.03 12 1 2.35 Lt. ill ! 145 , 4644 0 0.02 10 2 2.34 L1. Deposits. " 146 4675 0 0.02 9 2 235 147 4706 0 0.03 14 4 236 148 4737 0 0.03 13 3 2.37 149 4770 0 0.02 11 I 1 I 239 ISO 4801 0 0.02 11 1 234 151 4833 0 0.03 14 2 2.34 . {~i- ..... 4864 .g 0.04 17 4 2.37 rf.". '. ~ 4896 0.03 13 3 2.37 54 4927 0 O.O~ 2 2.3ï 55 4958 .0: 3 .3E 'Sf, 4990 .0" 3 .3ï N..II. 157 5021 .O~ } 3 .3ï 58 505.3 .03 12 3 .3; 159 5084 0 0.02 10 7 2.34 160 5115 0 0.03 15 5 237 Shallow DiUin". 161 5147 0 I 0.Q4 I 18 4- 2.36 Shallow Dittin\!. iii 162 5179 0 0.02 9 2 237 163 5209 0 0.03 2 1 2.34 161.1 524 0.03 3 1 2.34 PUP 161.2 S24(¡ ( 0 0 N/A elM 3 No 163.3 52.'1 O. T3 0.04 7 2 2.35 PUP e'" itting. II 164 525 ( 0.04 7 7 2.37 Shallow Dittinl2. Lt. ¡pnn, t< 165 5291 0 0.02 9 2 2.35 166 5321 0 0.03 14 3 2.36 167 5352 0 0.01 3 2.36 168 538L 0.03 3 3 .34 169 541 0.03 3 5 .3¿ 70 i1f; 0.04 7 8 .3: Shallow oittim!. 171 0.02 10 2 .3L 172 5508 0 0.04 18 4 2.3; Shallow Dittim!. ill 173 5541 0 0.02 10 3 2.37 174 5571 0 0.02 7 4 2.37 175 5f )4 0 0.02 '1- _3- 2.37 176 ' .5 0 0.03 14 3 2.34 177 ,7 0 0.02 9 2 2 \6 I 178 ' i8 0 0.04 1 17 3 2. n Shallow Dittim!.. 1 '8.1 '30 0 0.03 13 3 2. :') PUP 178.2 5735 0 0 0 0 N.A elM 4 No 178.3 5742 0 0.05 2! 2 2.37 Pl Dittinl2. - 179 57' 8 0 0.03 3 2 2.37 180 57; 9 0 0.03 6 2 2.32 Shallow Dittìng. L1. 181 581 0 0.04 8 4 2.33 Shallow L1. - 182 58" 2 0 0.03 4 3 2.34 Penetration Body Metal Loss Body Page 4 PDS JOINT U N Pipe: 2.875 in 6.5 J-55 EUE8RD Well: 31-11 Body Wall: 0.21 7 in Field: KUPARUK Upset Wall: 0.21 7 in Company: CONOCOPHILUPS Nominal 1.0.: 2.441 in Country: USA Survey Date: January11, 2004 Comments Penetration Body Metal Loss Body ~ ~ c ~ W ro 0 .- N - ~ ~~ ~ U 8~ I ,., \ N a lJ \, ".I -7 I- t/) :: :;;: èN ~ ~uO'> ~ ;;; ';1;: ~ ~ c ~<~ a ~ '~ U ~ CL -¡¡; 3: ?f- a a .. en ';; ~ ill ill en ill "¡;j iJj .. ~ c OJ} t/) 0 Q.~Ü:: ro d. 0 6~Vi Õ d (!' ~~~, a r-. :::J a 0.9 "¡:; ~ ~~~Z ~ ~ ill ~ U) ,S ~ 8 N ~- U U) N ~ 0 ro I U) 6 .~ ~ ~ ~ ill ~ ~ W ~ U ~ ill t)JJ C LL. ~ ~ ::J -' I /:L :LO ::JU ~ 0 0 ~Q...Z< S" ~::JO~ 0'> M:LU::J co C L() II 0 :;¡:~~:. ~ ro~Nro~ U ~ N l'iij C (l) I Rosa VJ 11 g 0 ;:o:~ VJ & ~ ~ 'ê iD VJ en ,- .- '@ u 0 ~EE;::~ '- OOO(¡jo U ~zzc¿~ I---.~ I I . ~ I ~ I ,..., I w I U ~ I g I .,,¡- '-.0 I <j) I 0 ()") I I I ~ ':: ! ü I "'::z I I II >-.,,¡- I ~N ~ U ()") ~ r C u.. '" .,,¡- I - "¿~N I ~ I I ~ I I - ì (¡j I I > ì I > I I ~ I i 0 I I '" : ~ [I '" I c iJ :31 i o:J N ~ ~ .. c low r..J') 0 p. g¡ ü:: I ci I '" iJ)~üïo I 0- ;:000 I <= :::Jooz ~ I ° <j) ¡- ¡- '+- ä:: 13 ~ v w "T <= 2 II ~ .- ~ '" ,....., co 0 I ? a::; ~~ I Ü ~ a I ~ ~ ° I j ~ u.. VJ CL ::::¡ -' I CL ~O ::JU CL:O =;î:z«"if. I ~::JO(/) '" I M~U::J ()") r.n II ~ '" ~ 0 ~~~r.n I ()") '" '" ~ II I ~NII= i.. II II 0 ~.9 ",è vgooo~ ....~c a;--,S.> I 'Q3::2t:::::J fj) 0-22cw I > woo fj) If>.-.-.¡;¡ v >iI:UU 0 oEEEo I ..... Ooowo U ¡-ZZCL:¡- i ':":'i tJo';:ì I ~U\jj 1 Q: 12 907f;5:f7( NSt< l<JELLS GROUP (" P~I;E £:::" Cono~oPhill.ptt:AI.~i..InG. KRU 3\~..11 '3 WelNG ~~-.; Ç:2!!i"5. , 102 ~..:!,: ¡ I ",,;,;,,:;,,-,! , \ i I 1 2 .3 1;'~"?~ ,;"'" "'~;"',;;;';~1~.;,~,:¡~>,.;:¡;,;':,",:~.',~""~~,,,';.'=J'~;'r.t.t~t¡~¡;,;:..;:í.:'i;a'; " illll:fiptlOf! ~_........,... ...---,.., , "-. """"""""1 . 'j1)"'" --- ~-~.J. '-3- . ~1.w 2.:J;~7 - 2.250 :i"M'1 <:,44"¡ t'.",: J:.," '~.;:,,-;ë:,:::""-;:~~"':.~,,::-.;:oi::""""-:.j!.~,~:;:::;:~~:~;:îi::; 589Ir - \ I , i I I I 50S --.- (~. C(I;"O1'S) !~ .,-.. (;¡,.IJ1-G4.1;.{) ~ =~ ) '-"'. ""'. J:.¡!""" . 11"'-" """"J ..,-.- I ( .. ! I ~. ~ ¡~~ - . ¡ .. i :.- -" "....- -_..._..-~ -- . - ---,--_._..__J, Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth NO. 3024 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 10/31/03 Field: Kuparuk Well Job # Log Description Date 'BL Color CD IY-19 ~c~'~--j(~)-~ PRODUCTION PROFILE/DEFT 10/09/03 3A-04 ~ ,~'r~)~ INJECTION PROFILE 10/11/03 3B-03 ~%~(c~"~ PRODUCTION PROFILE/DEFT 10/13/03 3B-08 '1~.~)-~'-~ PRODUCTION PROFILE 10114/03 3A-05 I ~-~J~ PRODUCTION PROFILE 10115103 3B-06 l~'O~ PRODUCTION PROFILE 10116103 2T-21 ~~~ LEAK DETECTION LOG 10,17,03 3B-04 PRODUCTION PROFILE/DEFT 10/18103 1E-20 ~ ~ SBHP SURVEY 10120103 31-11 .) ~ 'O~C LEAK DETECTION LOG 10125103 3G-11 PRODUCTION PROFILE 10127103 1B-20 ~-'~ PERF RECORD/STATIC SURVEY 10130103 Please sign and return one copy of this transmi~l t0 Beth at the above address or fax to (907) 564-8347. Thank you. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska ~9510-0360 Telephone 907 276 1215 June 21, 1999 Mr. Robert N. Christenson Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 31-11 (Permit No. 89-35/399-037) Report of Sundry Operations Dear Mr. Commissioner: Enclosed is report of Sundry Operations for the recent workover operations on KRU 31-11. If there are any questions, please call 265-6120. Sincerely, G. L. Alvord Drilling Engineering Supervisor Kuparuk Drilling GLA/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging m Perforate _ Pull tubing __X Alter casing _ Repair well __X Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X 76' RigRKE 3. Address: Exploratory__~ 7. Unit or Property: P.O. Box 100360 Stratagrapic __, Anchora,qe, AK 99510-0360 Service __~ Kuparuk River Field 4. LOcation of well at Surface: 8. Well nUmber: 147' FSL 48' FEL, Sec. 36, T13N, R8E, UN 31-11 At top of productive interval: 9. Permit number/approval number: 699' FNL, 493' FEL, Sec. 1, T12N, R9E, UN 89-35/399-037 At effective depth: 10. APl number: 50-029-21932 At total depth: il !. Field/Pool: 808' FNL, 558' FEL, Sec. 1, T12N, R9E, UN j Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total Depth: measured 6772' Plugs (measured) true vedical 6560' Effective Deptl measured * Junk (measured) * - frac sand from 6270' to 6680'. Coil Unit schedule( true vedical to clean out fill Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 250 sx CS II 115' 115' Surface 3348' 9.625" 330 sx class G & 544 sx AS III 3383' 3383' & 175 sxAS I Production 6728' 7" 250 sx Class G & 175 6761' 6550' Liner Perforation Depth measured 6437'-6454', 6457'-6486', 6494'-650 true vertical 6245'-6261 ', 6263'-6290', 6298'-630 Tubing (size. grade, and measured depth) RECEIVED Packers and SSSV (type and measured depth) AVA RHS Retr. Packer @ 6262' MD; No SSS~ J UN 2 1 199 ) i'3. Stimulation or cement squeeze summary ~l{a 011 & Gas C01~. ~mm~i0r, Intervals treated (measured; N/A Anchorage Intervals treated (measured) 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run m I Daily Report of Well Operations _X Oil _~ Gas _ Suspended m Service _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Well APl # PTD# $1TP 31-11 5002921932 89-35 lAP 2400 Packer fluid Tubing fluid Workover X , . New Well Completion Date WELL INFORMATION CAP BHP /Depth / Date / Inst. 0 Description Weight(ppg) Diesel/Sea Water I 6.8 / 8.5 Diesel/Sea Water I 6.8 / 8.5 DIRECTIONAL INFORMATION RKB 31 KOP 3700 Avg Hole Angle 23 Max angle of 24 @ 5300 Hole Angle @ TD 18 4/4/89 WELL HISTORY HANDOVER FO~ NEW, ADDED OR RE-PERFED INTERVALS Top Bot $PF Gun Type Date 6437 6454 8 2 1/8" Dyna Strip~ 60deg. Phased 6457 6486 4 4.5" HSD, 90 deg. Phased, orient. 6494 6503 8 2 1/8" Dyna Strip~ 60deg. Phased .. To Production X To Drilling Rig Name Nordic 3 I Approx Depths 2040' MD 2040' MD AFE Number 999282 Drillers TD 6,772 DOWNHOLE INFORMATION PBTD/Top of fill or Junk: 6270' Date Tagge¢. 4/18/99 BPV Installed I I IA VR Plug 2 Way Check CA VR Plug Downhole Plug CASING/TUBING DATA Depth Size Wt. Grade Conn. Top Bot Cond. 16" 62.5# H-40 Welded 0' 116' Surf. 9.625" 36# J-55 BTC-MOD 0' 3383' Prod. 7.0" 26# J-55 BTC-MOD 0' 6761' Prod. Tubg. 2.825" 6.5# J-55 EUE 8rd 31' 6334' KNOWN Communication Tubing ~'~ IA ~ OA ~ SUI~I=ACE EQUIPMENT Tree 2 9/16" FMC GEN IV, 5M Tree Cap Corm 5 3/4 4 pitch Otis ACK (Type/Pressure Rating) Tbg Hgr Conn 2 7/8 8RD COMPLETION INFORMATION De Item Model Vlv Size OD ID Valve Latch 500 D' Nipple Otis D' Nipple 2.313 - 2597' GLM Camco KBMM 2-7/8"- 1" 4.742 2.371 BK 4250' GLM Camco KBMM 2-7/8'- 1" 4.742 2.371 BK 5246' GLM Camco KBMM 2-7/8"- 1" 4.742 2.371 BK 5736' GLM Camco KBMM 2-7/8"- 1" 4.742 2.371 BK 6195' GLM Merla TGPD 2-7/8"- 1.5" 5.47 2.371 RKP ** 6250 PBR AVA Hydr. Release 2.75 . 6262' PKR AVA RHS retr. 2.347 - 6299' D nipple Camco 2.25 - 6333' Shear out AVA - 2.441 - 6334' tbg Tail - - 2.441 DPEN** Rig released subsequent to full well completion as required on State Drilling permit: Yes No If no, specify remaining operations: ENVIRONMENTAL SITE INSPECTION Location Clean/Cellar Clean GENERAL INFORMATION Frac sand in tail pipe F/6260' to TD ?? All equipment from PBR 6252' to 6334' Original. Ail new Equipment f/surface to PBR. LOCK's like bottom hole preseure @ +- 4400 psi. Changed Tb;I spool & Tree Open pocket In GLM @ 6195' Drilling Dept. Rep. Don Wester/Dearl W. Gladden D-08 Production/Oper Dept. Rep. Denise Petrash Title DrlgForeman Date 4/21/99 Title Prod Eng Date 4/21. TUBING DETAIL 2.-7/8" $ina_le Producer WELL:31-11 KRU ARCO Alaska, Inc. DATE: 4/19/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS DOYON 14 RKB TO TBG sPOOL 31.00 FMC 7-1/16" X 2-7/8" EuE 8rd tbg hanger W/3.17' pup 4.23 3i.00 jt#193 2-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 31.54 35.23 Space out pups (~ 10.14' & 10.14' ~) 20.281 66.77 jt#180-192 2-7/8" 6.5# L-8C] EUE 8rd AB- Mod tbg 409,11 87.05 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 5.94 496.16 2-7/8" Halliburton 'X' Nipple W/2.313" ID profile 1.21 502.10 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 10.18 503.31 jt#114-179 2-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 2077.26 513.49 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6.05 2590.75 GLM# 1 2-7/8" X 1.5'' camco 'KBMM" W/DV 'BK' Latch ID 2.371" OD 4.742" 6.67 2596.80 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup ,5.54 2603.47 jt#62-113 2-7/8" 6.5# L-80 EUE 8rd AB- MOd tbg 1635.65 2609.01 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 5.99 4244.66 GLM# 2 2-7/8" X 1.5'" Camco 'KBMM" W/DV 'BK' Latch ID 2.371" OD 4.742" 6.69 4250.65 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6.73 4257.34 jt#31-61 12-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 975.97 4264.07 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6.15 5240.04 GLM# 3 2-7/8" X 1.5" Camco 'KBMM" W/DV 'BK' Latch ID 2.371" OD 4.742" 6.68 5246.19 , 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup , 6,55 5252.87 jt#16-30 2-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 470,59 5259,42 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6,03 5730,01 GLM# 4 2-7/8" X 1.5" Camco 'KBMM" W/DV 'BK' Latch ID 2.371" OD 4.742" 6,69 5736.04 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6,59 5742.73 jt #2-15 2-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 440,51 5749,32 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6,16 6189,83 GLM# 5 2-7/8" X 1.5" Merla 'TGPD' W/DeR csg shear ID 2.371" OD 5.470" 9,58 6195.99 2-7/8" 6.5# L-80 EUE 8rd AB-Mod pup 6,02 6205,57 jt #1 2-7/8" 6.5# L-80 EUE 8rd AB- Mod tbg 31,56 6211,59 2-7/8" 6.5# L-80 EUE 8rd AB- Mod pup W/X/O And Seal Locator 7,28 6243.15 Spaced out from Seal Assembly being 1' From fully inserted 2,00 6250.43, AVA PBR OD 5.5" ID 3.375" 10,00 6252,43 7" X 2-7/8" AVA RHS RETV PKR PINNED FOR 60k Shear 4,35 6262.43 1 2-7/8" 6.5# J-55 EUE 8rd AB-MOD IPC tubing 32,49 6266,78 2-7/8" Camco 'D' Nipple OD 3.668" ID 2.250' 1,57 6299.27 1 2-7/8" 6.5# J-55 EUE 8rd AB-MOD IPC tubing 32,45 6300.84 2-7/8" AVA Shear Out Sub WLEG .66 6333.29 Tubing Tail 6333,95 Remarks: String Weights with Blocks: 52K# Up, 48K# Dn, 19K# Blocks. Ran 193 oints of tubing. Drifted tubing & hanger with 2.347" plastic rabbit. Used Arctic Grade APl Modified No Lead threac compound on all connections. Tubing is non-coated. All tubing is new Nordic Rig #3 Drilling Supervisor: Donald L, Wester Date: 4/29/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:31-11 RIG:NORDIC 3 WELL_ID: 999282 TYPE: AFC: 999282 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:04/14/99 START COMP:04/12/99 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-21932-00 04/12/99 (Cl) TD: 6772' PB: 6680' 04/13/99 (C2) TD: 6772' PB: 6680' 04/14/99 (C3) TD: 6772' PB: 6680' 04/15/99 (C4) TD: 6772' PB: 6680' RIG UP TO KILL WELL. MW: 0.0 SUPV:R. L. MORRISON JR. Move rig from lC pad to 3I pad. Rig on location ~ 0230 hrs. 4/13/99. UPCOMING OPERATIONS:KILL WELL. PULL TUBING. COMPLETE RISER MODIFICATI MW: 0.0 SUPV:DONALD L. WESTER Continue to move rig from iD pad to 3I pad. Accept rig ~ 0330 hrs. 4/13/99. MIRU. Pump seawater down tubing. N/D tree. N/U BOPE. UPCOMING OPERATIONS:CIRCULATE & KILL WELL W/ 11.5 PPG BRINE. CIRCULATE AROUND ~ 4234' P/U AND BULL HEAD 61 BBL'S OF 10.3 BRINE PAST PACKER @ 6264' COMFRIMED COIL TUBING TOP MW: 0.0 SUPV:DONALD L. WESTER NU BOPE and test 250/3500 psi. Coil tubing stuck in 2-7/8" tubing from 4948' to 6019'. Displace seawater w/brine down tubing. Pump salt pill. Attempt to bull head pill from 4234' down to perfs. Unable to squeeze away pill. Well flowing. Continue pumping pill. Circulate down tubing. Attempt to bullhead down casing annulus. Attempt to land tubing back over slick stick. Unable to get back down. UPCOMING OPERATIONS:KILL WELL DISPLACE 11.5 PPG BRINE W MW:ll.5 BRINE SUPV:DONALD L. WESTER Continue to RIH w/slick line. Tag stuck 1.75" coil tubing fish @ 4940'. Circulate brine fluid around. Shut well in. Well is not flowing. Well should not be be dead assume packed off below packer ~ 6264'. Pressure test tubing to 1000 psi circulated. Appears bleeding off through 1.75" coil tubing. RIH w/ Kenley 2-7/8" tbg punch and perf tubing @ 4947' MD. Run #2 perf @ 4944'. CBU. Bleed off well started to flow shut in. UPCOMING OPERATIONS:PULL 2-7/8" TBG Date: 4/29/99 04/16/99 (C5) TD: 6772' PB: 6680' 04/17/99 (C6) TD: 6772' PB: 6680' 04/18/99 (C7) TD: 6772' PB: 6680' 04/19/99 (C8) TD: 6772' PB: 6680' 04/20/99 (C9) TD: 6772' PB: 6680' 04/21/99 (C10) TD: 6772' PB: 6680' ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 CONTINUE RECOVERY OF 1.75 MW:14.9 LSND SUPV:DONALD L. WESTER Pump N-vis spacer and LSND mud. Displace with brine. Open well slight flow. POOH w/ tubing. UPCOMING OPERATIONS:P/U 3-1/2" DP C/O PBR SET STORM PACKER CHANGE TBG SPOOLS. SET BAKER 7" STORM PACKER MW:15.0 LSND SUPV:DONALD L. WESTER Continue pulling 2-7/8" tubing w/1.75" coil tbg stuck inside. Recovered all coil tbg fish. UPCOMING OPERATIONS:COMPLETE TBG SPOOL CHANGE OUT. RIH CHECK PBR L/D 3-1/2" DP & RUN COMPLETION RUNNING 2-7/8" PRODUCTION MW:15.0 LSND SUPV:DONALD L. WESTER30 Run 7" storm packer and set @ 35'. ND BOP. Install new 9-5/8" x 7" packoff. NU BOP and test. Pull storm packer. UPCOMING OPERATIONS:ND-NU CHANGE OVER TO SEA WATER FREEZE PROTECTION MOVE THIS AFTER NOON. RERUN 2-7/8" PRODUCTION T MW:15.0 LSND SUPV:DONALD L. WESTER Run 2-7/8" tubing completion w/seal assembly. Unable to get but 2' of seal stem inside PBR. Plugged w/frac sand. CBU. POOH w/ tubing. RIH w/cleanout assembly. Clean out PBR. Recovered frac sand & oil. UPCOMING OPERATIONS:N/D BOPE, N/U TREE RUN SLICK LINE PULL LOWER GLM DUE TO HIGH MUD WEIGHT. MOVING RIG FROM 3I PAD TO MW:iS.0 LSND SUPV:DEARL W. GLADDEN RIH w/ completion assembly. ND BOP. NU tree and test to 250/5000 psi. UPCOMING OPERATIONS:MOVE TO WELL 3H-11 RIG RELEASED 8:00AM 4/21/ MW: 0.0 SUPV:DEARL W. GLADDEN Continue to displace well over to sea water. Freeze protect well. Rig released @ 0800 hrs. 4/21/99. UPCOMING OPERATIONS:MOVE RIG TO 3H-11 ( 4.0 MILE MOVE) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Aban~lon _ S'UsPen(~ _ operationai ~'l~'~tdown _ Re-enter suspended well _ Alter casing Rel~r_.w~[-~X~ ~- Plugging Time extension Stimulate Other Change approved program _ ~! :.: Variance _ Perforate _ ~n 2. Name of Operator 5. TYPe-~)¥~W~iii 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. L~<~': RKB 76' feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__ Kuparuk River Unit 4. Location of well at surface 8. Well number 147' FSL, 48' FEL, Sec. 36, T13N, RSE, UM 31-11 At top of productive interval 9. Permit number / approval number 699' FNL, 493' FEL, Sec. 1, T12N, R9E, UM 89-35 At effective depth 10. APl number 50-029-21932 At total depth 11. Field / Pool 808' FNL, 558' FEL, Sec. 1, T12N, R9E, UM Kuparuk River Field/Kuparuk Oil Poc 12. Present well condition summar Total depth: measured 6772 feet Plugs (measured) I true vertical 6560 feet ORIGINAL Effective depth: measured 6680 feet Junk (measured) true vertical 6473 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 250 sx cs II 115' 115' Surface 3348' 9.625" 330 sx C~ass ~ & 544 sx AS m 3383' 3383' & 175 sx AS I Production 6728' 7" 250 sx Class G & 175 sx AS I 6761' 6550' Liner Perforation depth: measured 6437'-6454', 6457'-6486', 6494'-6503' RECEIVED true vertical 6245'-6261', 6263'-6290', 6298'-6306' I AR G2 1999 Tubing (size, grade, and measured depth 2.875", 6.5#, J-55 @ 6334' Naska 0il & Gas Cons. Commission Packers & SSSV (type & measured depth) Otis 10 TR SSSV @ 1790', AVA RHS pkr @ 6262' Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ " BOP sketch .._X 14. Estimated date for commencing operation 15. Status of well classification as: March 10, 1999 16. If proposaI was verbally approved Oil .~X Gae~ Suspended Name of approver Date approved Service 17. I hereby certify that the foregoing is true and Correct to the best of mY knowledge. Que~tion~? Call Mark Chambers 265-1319 Signed /~ ,, Date ChipAIvord~ ~. ~ Title: Drilling Engineering Supervisor Prepared by Sharon Allsu~Drake FOR COMMISSION USE ONLY C°nditi°nS of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~ Location clearance __ Mechanical Integrity Test _ Subsequent form required lo- ORIGINAL SIGNED BY Robert N Christenson ___Ap_proygd by order of the .,C...ommi ,,.~ion C~)~)~,,, Commissioner Date Form 10-403 Rev 06/15/88 · ~ SUBMIT IN TRIPLICATE KRU 31-11 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: 1. Pressure annulus to 3500 psi and hold for 15 min to test casing integrity. RU Slick Line Unit. RIH and tag top of fish w/LIB. RIH and pull Dummy Valve from GLM @ 4234' leaving an open pocket. Set BPV in robing. Install VR plug in annulus valve. Prepare Location for Nordic 3. GENERAL WORKOVER PROCEDURE: . 5. 6. 7. . 9. 10. 11. 12. 13. 14. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. Load pits with seawater. Displace well with seawater by circulating through open GLM @ 4234'. SI well and monitor pressure to determine kill weight. Load pits with kill weight brine. Displace well with kill weight brine by circulating through open GLM @ 4234'. SI well and monitor pressure to ensure well is dead. Set BPV. ND / NU and test BOPE. Screw in landing joint. POOH laying down 2-7/8" robing and jewelry to top of fish. RU to handle 2-7/8" tubing and 1-3/4" coil fish. Install Ram Punch and re-test all breaks. POOH laying down all remaining 2-7/8" robing and 1-3/4" coil. While POOH, punch 1-hole immediately above each tool joint, relieving any trapped pressure, prior to breaking connections on rig floor. RIH with cleanout assembly picking up 3-1/2" drill pipe of rack. Cleanout to top of packer. POOH laying down drill pipe. PU AVA seal' assembly and RIH with 2-7/8" robing and completion assembly as per attached schematic. Circulate into PBR and land seal assembly. Spaceout with tubing pups and land tubing hanger. RU Slick Line Unit. RIH and set a standing valve in D-Nipple below packer @ 6299'. Pressure test tubing and annulus. Install BPV. ND / NU and test tree. Displace well to seawater and freeze protect with diesel to +/- 2000' TVD. Lower Limit: 5 days Expected Case: 6 days Upper Limit: 8 days MAC 2/9/99 31-11 Proposed Comple~n M. 2-7/8" 5M FMC Gen IV tubing hanger with 2-7/8" L-80 EUE 8rd pin down. L. 2-7/8" 6.5~ L-80 EUE 8rd Mod tubing to the tubing hanger. K. 2-7/8" Camco 'DS' Nipple with 2.312" profile set @ +/- 500' MD. J. 2-7/8" 6.5# L-80 EUE 8rd Mod tubing to the 'DS' Nipple with 2-7/8" x 1" Merla q'MPD' mandrels w/DV's and BK latch (4102910), spaced out as follows. GLM # MD-RKB 2 TBD 3 TBD 4 TBD 5 TBD 6 TBD Note: Each GLM should have 6' L-80 handling pups installed on top and bottom. I. 2-7/8" x 1-1/2" Merla 'I'GPD' mandrel w/DCR Dump Kill Valve & RK Latch (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. (4102910) H. 1 Joint 2-7/8" 6.5# L-80 EUE 8rd MOd tubing G. Pup Joint 2-7/8" 6.5# L-80 EUE 8rd MOd tubing F. 5.50" x 3.375" AVA PBR @ 6,248'. E. 7" x 2-7/8" AVA 'RHS' Hydraulic Release Retrievable Packer @ 6,262'. D. 1 Joint 2-7/8" J-55 EUE 8rd AB MOd Tubing. C. 3-1/2" Camco 'D' Nipple w/2.25" Profile. B. 1 Joint 2-7/8" J-55 EUE 8rd AB Mod Tubing. A. AVA 2-7/8" shear out @ 6,333. Tubing tail @ +/- 6,334'. A3-Sand Perfs 6,437' - 6,454' A2-Sand Perfs 6,457' - 6,486' Al-Sand Perfs 6,494' - 6,503' PBTD @ 6,525' - Coil cleaned out to this depth prior to getting stuck. PBTD @ 6,680' - Actual 7" casing PBTD to LC. TD @ 6,772' 2/5/99 MAC 31-11.pdf at www.aai.arco.com Q Page 1 of 2 ,~, 31-1 1 ARCO Alaska, Inc. '~r Kuparuk SSSVT~pe: OisSedes 10TR OrigOomplaJcn: 4/4/89 ! TD. 6~772flKB Annular Fluid: LastW/O: 5/19'80 ! Max Hole An~le: 24de~ @5300 TUBIN3 LastTag: 6529 LastTa~Dat~ 1/15/98 Angle@TS: 22cbg@6401 RevReesor~ NewSchem LastUi3date.' 3/18/~ ~e ~ ~D: 19deg.6772 i iEi~/~t i :! i::.: i i:: i :.iiiiii:.iii::iiii::i~:ii:.~?:!:i !i!i~::.i!iiiiii}~!i!i;i.iiiiii::iiii!!!i~i:.ii:i i;i ii!;i i!i~i~:iii;ii::iiii :i: ;i!i:.i ii i iiii~:ii!il: :! i: ::~i i!!~!:.~ ~ii~!i~: Item I Btm I Jnts I Wt I Grd I Thd Item I Btm t Jnts Wt I Oro I mo Gm Lit_~_,.~, 9.6~5 inSUR. CASlqG I ami 30.oo J-SS I Item I Btm I Jnts I Wt I Grd I Thd 7.000~PmD. Cns!m I 6'7Sll I a~,ooI J*5~ I Item I Top I Len IJnts I Wt I Grd I Thd Ga 6,494- 6~503 6,437- 6 454 6,457 interval ' '*:::':'~': Stn ':~ ~Ei.~-~ *'~'"' ' 6,486 ~l~and.l~ah~.~:i.-.!-.~:.:::=.i.?::::.:?.~:.:::-*: ~:.::*-~:.::.=:.::.::~::: ~:i MD! A-3 A-1 A-2 Zone TVD ' Man ~:~ ~:i:~ :i:~::: ~:i i~:~;~. Mfr ~:!~:!!: :~ :!~:i ::::: i::: ~:. ~:~ :~:.: Status :::::: IMan :!~: ~:::~:~i:i. :.:~:~.i::::: ~:~:~!: Type ~:~i:~:!~:~ :~::: i:~!:~. Feet i:~. ~.i:.::: ;~:~i: 29 17 9 :~:~.i:i~: :i:.: !:! ::::. ~. ~:~ ~:~.:.: SPF ~.~. ~:~:. 4 8 8 :~:~: Mfr ;i. ~. ;: 3/6/903/5/905/18t89 ~ Date ~:~:::i. :~i:.:~ ~:~. ;~ ~:~.:i. :* Type ;' :'::: ~:~:~ ~:~:!~' ::: ~:~:i.~:. 2 i2 1/8" D~aSlrip IGun IType ~:i. 4 .~:.~ :~. ~i~:~:~.:~. 1/8" DjrlaSIrip 1/2" Latch ~i. :':'~:~ ::~.~. HSDGsg ;i. ;i.~:~.i~:~. :.i :~:~: ;~.:i Port :'::"?: :! ~' ;i.:~-;i. ~-!:. ':~:'~: :':'~:: ~'~ ' :!' i:.i:~:!~i;i 60 dl~ 60 de~' I::ltasira ~0 Comment ~:! !:!:~ dec :!. ~!:i. TRO :' ~:!:! I:tlasinfl pllaslng i:!.:i. ::'~ !:. ~. i,:.:. ~ 1 2,5741 2,574 IVerla !2 7/8 X 1TIVl=D DV BK GOO0 0.(~ 3/19,g8 Ga~l.J~ ~ 2 4,234 4,~1 Mefla 2 7/8 X 1TM=D DV BK G1300 0,0 3/10t~18 MErflrel/~ Va~ 3 5r243: 5~149 Merla 2 7/8X 1TIvF~ DY ElK G000 GO 3tlO'~t .-.i 4 5,734 5,5~t0 IVbrla 2 7/8 X 1TIvF~ DY i BK 0.OO0 0,0 5/19,88 5 5,968 5,813 IV'erla 2 7/8 X 1 TIVF~ DV i ElK GOO0 0,13 5t11~'8~t 6 6,201 6'1397 IV~rla 27/8X1 1/2TC-PD DV IF K 0,0130 0,0 Depth IType Description ID 1,790 SSSV OlisSeries'll7 IR 2.313 GmLiIt~ 6~248 PER AVA hy~. release 2.750 Mazlrel/Dum3j VaJ~. 6,3621PKR AVA'RHS' Reit. ~_347 6'299 ! NO GO Camco'J7 kil3ple 2_250 6,333 SFF_/~ ~ AVA 2_441 6~334 TUBHG T~NL i 2.441 Depth Description Comment IN HOLE w/19' of Ch~rrical Cutter Tool Siting (n Top of Coil Ma'd~ 6'5~ I 1/2"DY Err~ Fe~tora~ob TUBN:3 T/~L'~I 2/23/99 4:11:27 PM REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdo~ Stimulate_.~ Pull tubing _ Alter casing _ 2. Name of Operator: 15. Type of Well: ARCO Alaska, Inc. I Development X. 3. Address: Exploratory _~ P.O. Box 100360 Stratagrapic __~ Anchorage, AK 99510-0360 Service 4. Location of well at surface: Plugging _ Perforate _ Repair well t Other _ 6. Datum of elavaflon (DF or KB feet): 76' RKE 7. Unit or Property: Kuparuk River Unit 8. Well number: 31-11 9. Permit number/approval number: 89-35 10. APl number: 50-029-21932-00 11. Field/Pool: Kuparuk River Field/Oil Pool 147' FSL, 48' FEL, Sec 36, T13N, R8E, UM At top of productive interval: 699' FNL 493' FEL, Sec 6, T12N, R9E, UM At effective depth: 783' FNL, 543' FEL, Sec 6, T12N, R9E, UM At total depth: 808' FNL, 558' FEL, Sec 6, T12N, R9E, UM ; 12. Present well condition summary Total Depth: measured true vertical 6772 feet Plugs (measured) None 6563 feet Effective Deptl measured true vertical 6680 feet Junk (measured) Approx 1071' of coil tubing stuck in hol~ 6476 feet Casing Length Conductor 80' Surface 3348' Production 6728' Size Cemented Measured depth True vertical depth 16" 250 Sx CS II 115' 115' 9-5/8" 330 Sx Class G & 3383' 3383' 544 Sx AS III w/175 Sx AS Itop job 7" 250 Sx Class G 9811' 6553' Liner Perforation Depth measured 6437'-6454',6457'-6486',6494'-6503' true vertical 6245'-6261', 6263'-6290', Tubing (size, grade, and measured depth) 2.825", 6.5 #/ft., J-55 @ 6303t $EP I I Packers and SSSV (type and measured depth) Pkr: AVA 'RHS' @ 6262'; SSSV: Otis Se~i~-~0 @ 17~richors,{~8 13. Stimulation or cement squeeze summary Fracture stimulate 'A' sands on 3/11/98. OEtGI AL Intervals treated (measured) 6437' - 6454', 6457' - 6486', 6494' - 6503' Treatment description including volumes used and final pressure Pumped 237898 lbs of 16/20 and 12/18 ceramic proppant into the formation, final pressure = 9000 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 135 180 286 1255 179 Subsequent to operation None - coil tubing stuck in hole 15. Attachments 116. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _~ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~~~~~/_ Title: Wells Superintendent Form 10-404 R~ 06/15/88 ~ ~ Suspended _ Service _ ~UBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT A El(31-11 (W4-6)) WELL JOB SCOPE JOB NUMBER 31-11 FRAC, FRAC SUPPORT 1221971057.6 DATE '=DAILY WORK UNIT NUMBER 03/11/98 "A" SAND REFRAC ,, DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON "SUPERVISOR I (~) Yes O NoI (~) Yes O No DS-YOAKUM ..CHA~ ESTIMATE KD1236 230DS361L $140,114 $143,724 Initial Tbg Press950 PSI ' Final Tbg Press2000 PSI '"Initial Inner Ann150 PSI "Final Inner Ann350 PSI IInitial Ou I ' ~ DAILY SUMMARY "A" SAND REFRAC COMPLETED THRU FLUSH. INJECTED 237898 LBS OF PROP IN THE FORM. W/10# PPA OF #12/18 @ THE PERF'S. MAXIMUM PRESSURE 9000 PSI & F.G. (.83). TBG FREEZE PROTECTED TO 3000' W/DIESEL. TIME 06:30 09:30 09:50 10:45 11:50 12:55 LOG ENTRY MIRU DOWELL FRAC EQUIP, LRS HOT OIL TRUCK, AND APC VAC TRUCK. HELD SAFETY MEETING (14 ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 10,000 PSI. HAVING PROBLEMS WITH THE ACTIVATOR PUMP. STOOD-BY WHILE REPAIRING. PUMP BREAKDOWN W/40# DELAYED XL GW @ 25 TO 20 BPM. SLURRY VOLUME PUMPED 312 BBLS. USED 6660 LBS OF #20/40 PROP. MAXIMUM PRESSURE 8955 PSI AND ENDING PRESSURE 5500 PSI. STEPPED RATE DOWN AND ENDING PRESSURE 2675 PSI. S/D AND OBTAINED ISIP OF 2298 PSI W/F.G. @ (.81). MONITORED WHTP AND PULSED FOR CLOSURE. CLOSURE TIME 21 MINS @ 1857 PSI. PUMP DATFRAC W/40# DELAYED XL GW @ 5 TO 20 BPM. SLURRY VOLUME PUMPED 127 BBLS. MAXIMUM PRESSURE 5800 PSI AND ENDING PRESSURE 4700 PSI. S/D AND'OBTAINED ISIP OF 2431 PSI W/F.G. @ (.83). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 25 MINS @ 1955 PSI. PAD VOLUME = 150 BBLS. PUMP FRAC W/40# DELAYED XL GW @ 5 TO 20 BPM. COMPLETED THRU FLUSH. SLURRY VOLUME PUMPED 1314 BBLS. MAXIMUM PRESSURE 6600 PSI AND ENDING PRESSURE 6100 PSI. TOTAL PROP PUMPED 239014 LBS (13590 LBS OF #20/40 & 225424 LBS OF #12/18). INJECTED 237898 LBS OF PROP IN THE FORMATION W/ 10# PPA OF #12/18 @ THE PERF'S. LEFT 1116 LBS OF PROP IN THE WELLBORE AND EST FILL TO BE @ 6450' RKB. EST. BHP @ 3200 PSI. TBG FREEZE PROTECTED TO 3000' W/DIESEL. 14:30 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. MOVED HOT OIL UNIT OVER TO THE FRAC SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $200.00 APC "~ $4,800.00 $4,800.00 DIESEL $400.00 $400.00 DOWELL $131,614.40 $131,614.40 HALLIBURTON $0.00 $2,749.89 LITTLE RED $3,300.00! $3,960.00 TOTAL FIELD ESTIMATE $140,114.40 $14~1,724.29 TIME 15:30 16:00 LOG ENTRY ~ TANKS TO THAW OUT -~'-~ ~N TANKS. REMOVED TREESAVER (50% OF CUPS LOST). CONTINUED R/D. R/D COMPLETED AND ALL MOVING OFF LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. 'Name of O~3erator ALASKA OILAND GAS C, ONSERVATION coMMIssION 0 I~ I G ! N A REPORT OF SUNDRY WELL OPERATIONS Operation Shutd~)wn ' stimulate '~ Pull tubing Alter casing5. Type of' Well:Repair well. Development X Exploratory __ Stratigraphic __ ~BCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4.'" LocatiOn of well at' Surface 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 699' FNL, 1016' FEL, Sec. 6, T12N, RDE, UM At effective depth 783' FNL, 1066' FEL, Sec. 6, T12N, RDE, UM At total depth 808' FNL, 1081' FEL, Sec. 6r T12Nr RDE~ UM 12.'" Present '~ell 'condition summary .... Total Depth: Service ----... plugging . .. Perforate "X Pull tubing et h · r __ I 6. Datum elevatlbn (DF or KB) I 76' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well ndml:~r 9. Permit number/e, oproVal number 90-106 / ~-/~ 10. APl number so-029-21932 11. Field/Pool Kuparuk River Field , Kuparuk River Oil, Pool measured 6772' feet Plugs (measured) None true vertical 6560' feet Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured 6 6 8 0' true vertical 6473' Length Size 80' I 6" 3348' 9-5/8" 6728' measured 6437'-6454', 6245'-6261', Tubing (size, grade, and measured depth) ,, feet Junk (measured) None feet Cemented Measured depth 250 Sx CS II 1 1 5' 544 Sx AS III, 3383' 175 Sx AS I, & 330 Sx Class "G" 175 Sx AS I & 6761' 250 Sx Class "G" 6457'-6486' 6264'-6291' 6494'-6503' 6298'-6306' 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 6334' MD Packers and SSSV (type and measured depth) Otis 10 TR SSSV @ 1790' MD; AVA RHS @kr. ~. 6262' MD. 33, 'S{irnUlation or cement squeeze summary . add perforations in the A sand i'~ter~l's treated (measured) 6437'-6454', 6494'-6503' Treatment description including volumes used and final pressure Perforated at 8 spf with +30° V .phasing 1'4.' ................. Repre~.entative Daily Average Pr0du~i°n or Inlection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure True vertical depth 115' 3383' 6550' RECEIVED Tubing Prior to well operation 5 9 2 6 3 5 0 I 2 4 0 1 6 3 .... ,S,, u ,,b, s, ecl,ue,nt to operation ....5 9 3 5 5 3 0 1 2 4 0 1 5 2 'l~'51"'~t~chments ! 16. Statues' of well classification as: ' Copies of Logs and Surveys run ~ ~ ! I Daily Report of Well Operations X ! Oil ~ , Gas ~ Suspended __ Service ~ I"~ 7. ..... j"'here'b~ Certify that the foregoir~g l's' t~ue and correct 40 the 'bes~' Of my knowledge. ' ' ' ~!cjn..e.~ ..... ' Title Senior Operations Engineer Date "?" &]_~ Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, ~. ~ Subsidiary of Atlantic Richfield C(~ ........ ~y C~NTRACTOR OPERATION AT REPORT TIME Co~P~. ¢'r'*~. WELL SERVICE REPORT IDAYS DAT~ -- , ~EMARKS 18oo ~,OOD 1/ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK , I$1gned/.-, knot.I (p'. -~. ADDENDUM ~v'~LL: 3'I'tl 4/17/89 4125189 7/22/89 RU Gearhart, rn 6. 125" GR/JB to PBTD. Rn CBT f/5118'-6669'; good cmt bond. Rn gyro £/6600'-surf. Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. Frac Kuparuk A2 zone perfs in 9 stages per procedure dated 5/25/89 as follows: Stage 1: lhnp 40 bbls diesel w/5I Musol @ 5 BPM, 3500 psi Stage 2: lhnp 100 bbl YFGO III Pre-Pad @ 20 BPM, 6300-4550 psi Stage 3: lhnp 900 bbls gel diesel pad @ 20 BPM 4550-4375 psi Stage 4: lhnp 37 bbls gel diesel w/2 ppg 20/40 Carbolite @ 20 BPH, 4375-4265 psi Stage 5: lhnp 34 bbls gel diesel w/4 ppg 20/40 Carbolite @ 20 BPM, 4265-4530 psi Stage 6: Pmp 79 bbls gel diesel w/6 ppg 20/40 Carbolite @ 20 BPM, 4530-5070 psi Stage 7: Pmp 163 bbls gel diesel w/8 ppg 20/40 Carbolite @ 20, 5070-5480 psi Stage 8: Pmp 28 bbls gel diesel w/10 ppg 20/40 Carbolite @ 20-18 PHP, 5480-5030-5200 psi Stage 9:. lhnp 38 bbls gel diesel v/12 ppg 20/40 Carbolite @ 18 PM, 5200-5409 psi lhnp 38 bbls flush @ 18 BPM, 5409-6310 psi. Fluid to Recover: Sand in Zone: Sand in Csg: Avg Pressure: 1457 bbls 101,432# 20/40 Carbolite 432# 4500 psi - Oil & Gas Cons. Commission ~choraga -- Drilli~ Supervi~ STATE OF ALASKA ~ KA OIL AND GAS' CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1' St~t~s ;,f We, C~a.i,~.,0n of Se~ico We, · OIL ~ GAS r=-] SUSPENDED r-~ ABANDONED r'~ SERVICE ~ , .... 2 Name of O~ator 7 Pe~it Number ARCO Al~ka, Inc 89-35 3 Address 8 APl Number P.O. Box 1003~, Anchorage, AK ~51~0~0 .. ~-029-21932 4 Location of well at .u,ac. ~~~ ": ~" ~H '~'i 9 Unit or Le.e Name 147' FSL, 48' FEL, SEC ~, T13N, R8E UM ~ ~ { -~' ~ .~n~ [ 10 Weli Numar At Top Pr~uci~ewa, ~ ' ~ , ~ 699'~L,~FEL, SEC~,T12N, ROE ua ~ ~ ~aa/, ~ 31-11 ~ [ 11 Field a~ Pool' At To~l Dep~ ~ ~ I ~ ' ~~~~' ~ 808' FNL, ~1' FEL, SEC~T!2N,~ ua KUPARUK RIVER FIELD 5 Elevation in f~t (indicate KB, DF, e~.) ~ 6 L~ Designa~on ~d ~Hal ~. KUPARUK RIVER OIL POOL RKB 76'~ ADL: 2~31 12 Dam Spud~ 13 ~te T.D. R~ch~ 14 Date Comp., Susp. 0r A~nd. ~ 15 Wamr Dep~, if offshore ~16 No. of Comple~ons MARCH 28 1~9 APRIL4 1~9 MAY20 1~9 -.-~~ NA feetMSLI 1 17 To~l Dep~ (MD+~D) i8 Plug ~ck ~p~ (MD+~D) 19 Dir~onal Suwey ~ ~p~ wher~ SSSV set 21 Thick.ss of per.frost 6772' MD & 6~0' TVD 6~' MD & ~73' ~D YES ~ ~ ~ 1790' f~t MD 1650' (approximate) ,, ~ 22 Ty~ El~tric or o~er Logs Run DIL.,SFL,GR,CAL,SP,FDC,CNL, CBL,GYRO 23 CASING, LI~R AND CEME~ING ~C~D S~I~ DEPTH MD ' C~I~ SIZE ~. PER ~. G~DE TOP ~ ' ~ SIZE CEME~I~ RECORD AMOUNT PULLED .~ , , , , " 16" 62.5~ H-40 SURF 115' 24" 2~ SX CS II 9 5/8" 36e J-55 SURF .3~3'. 12-~4" 5~ SX AS III & ~0 SX C~SS G 7" 26~ J-55 SURF 6761' 8-1/2" 2~ SX C~SS G & 175 AS I , , 24 ~edora~o~ o~n to Production (M~D of Top a~ ~om and 25 TUBI~ RECORD '.~ntewal, size and numar) SIZE DEPTH S~ (MD) PACKER SET (MD) ~ 2-7/8"~ J-55 6334' 6262' 6457-6486' MD, 4-1/2" W/4 SPF 62~' - 62~' ~D , ~ . ACID, FRACTURE, CEME~ SQUEEZE, FTC DE~ I~ERVAL (MD) AMOU~ & KIND OF MATERIAL USED , 6~7'- ~6' 101~432 lbs 20/40 CARBOLITE , 27 P~DUCTDN TEST ~ .... Date First Production ~M~°d of O~afion (FIo~, gas li~ etc.) I , Date of Test Hours Test~ P~DUCTDN FOR OIL-BBL GA~MCF WATER-BBL CHOKE SIZE J GAS-OIL ~TIO :~.PER!OD ,~ ,~ I . Flow Tubing iCasing Procure cALC~D OIL-UaL GA~MCF WASH-UaL OIL GRAVffy-API (corr) Press. 24-~UR ~TE ~ 28 CORE DATA ~ ' Brief description of lithology, ~rosi~, fra~ms, ap~ent di~ ~ pms~ce of oil, gas or ~mr. Submit corn chi~. RECeIVeD /~ka.Oil & ~a; Cons. Commisst : gnchora~ Form 10-407 Submit In duplicate Rev. 7-1-80 ~NUED ON REVERSESlDE 29. 30. GEOL(~IC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP KUPARUK C 6401' 6211' NA BOTTOM KUPARUK C 6405' 6215' TOP KUPARUK A 6426' 6234' BOTTOM KUPARUK A 6456' 6262' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Mr. Brit Brown Drilling Manager ARCO Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510 May 8, 1989 Re: Boss Gyroscopic Survey Job No. AK-BO-90040 Well: 31-11 Field: Kuparuk Survey._ Date: April 17, 1989 Operator: T. McGuire Mr. Brown: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. As per A. Thompson, copies have been sent to UNOCAL and SAPC. Thank you for giving us this opportunity to be of service. Sincerely, Ken Broussard District Manager Directional Services Enclosure RE¢ IVEI 'JUN 07 BB.e 8537 Corbin Drive (99507) · RO. Box 231649 · Anchorage, Alaska 99523 (907) 267-0200 · Fax (907) 522-3432 A Baroid Company ARCO ALASKA": INC',~: _3.._I-_i_l. KUPARUK ALASKA ANCHORAGE'~ALASKA ~ . = COMP_UTAT I .(IN~ DATE_ ....... MAY 2, 1989 vE~:ICAL SECTION CALCULATED .ALONG CLOS,URE T~_u_E SuB'S£8 CP_URSE VERTICAL VERTICAL INCLINATION DEPTH DEPTH DEG MIN CQ.URSE DIRECTION DEGREES DO~.-L£-~ SEVER I TY DEG/100 dOB NUMBER AK-BO-90040 KELLY BUSHING ELEV, = 76.00 FT, TO~AL · RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECTION 0 0,00 -76~00 0 ' 0 100 100,00 24,00 0 6 200 200,00 124,00 0 13 300 300,00 224,00 0 25 400 400,00 324,00 0 ~'~ 500 499,99 423,~9 . 0 22 ~ot ........~: ~'~ 523.99 N O. OE 0.00 N 13.69 E 0,10 N 17.69 E 0.12 N 22.19 E 0.21 N 17,10 E 0.07 N 40.89 E 0,16 0,08 N 0,35 N 0,88 N 1,55 N 2,11 N 0': 20 N 52.30'E 0,08 2.53 N' o.oo~ : ..i: 'o:0o o. 02 E .-o:. 08 O. 10 E . -0, 3~ O, 30 E -0.92 0.54 E -1,62 o? 85__~ ..... =2, I 29 E'" ". -2":84 700 ~99.99 . '623.99 800 7~9.~9 '723.~9 900 .=.oo 99 823 ~9 0 16 ~Z~m · . · . 1000 999.98 923.98 0 19 0 :23' N 57,89 E 0 :: 23 N 46,10 E. O. 07 .. O. 08 N 18.80 E 0,20 N 14.39 W 0,18 1100 1099.98 1200 ' .1199~98 1300 1299.98 C'' 1400} 1399~7 ' 1500 1499,97 1600 1599,97 1700 1699,96 1023, 98 0 '--"--' N 56, 80 W 0,~ : ':.::' 11-23.9'8' . :, ": ":0 ::i::::::~24,.::::''::, :N 17~. IO,'W.. ':::' :':~:' :: '0 27 '::::': :: · '. 1~-~' · r,:.."::.::. :::.: . -- ..::'..'. ~-, ' ::::...::".::. :~ :':C:= ' ... .:...' ::: '::' ....=...9~ . ,:::..: 0:::..o0:: ...... N :o,.=.~.W .... 0. I4 1323.97 : '::" 0:::::..::3::.': '::' N': :::::2' _~ :E_: .... ::. ,:: ? :::_. :.: : o 'j 1423,97 0 25 N 19, 0 E . 0,24 1='-~'-~- 97 0 15 N 35 19 E 0 lg a,,.,! ~- o~,. m m ..162~.9(:~ .... 0 ..~!... 2.90 N. 1.82 E. '-3.41 :, 3. :-!---~... N::..2~5__~. : ::': ~ ......... · _. _-_._4. ~ :3.77 N 2.67 E w -4.59 4.27 N' 2.68 E -5.02 4.7_1.~ ~ ... 2.34 E__ -5-~26 6.02. N.::~::: .:::~ ::.:. 1..~.1.~ E :::. :..~6:,:,16 .... 7.89 N 1.94 E -7.88 8.43 N 2.19 E -8.47 ,~, ~ ~-~ , o.,=,.- N. 2.18 E -8.87 : .:. -- : . . . ~:.,, : 1800 1799.96 "1723.96. : :0 · 1900 1899.96 '1823 · 96. ': 0 ........... .'2_!:.>.!;,0 ......... _l ?_.m?_, 'P~.. : :t~~..~, :':' :' :' O__ 2100 2099.96 2200 2199.96 2300 o.~o 95 2400 2399,95 2500 2499,95 .......... ~9~ ......... 2700 2699.95 2800 2799,95 __ ~Q~ ........... 2023.96 2123.96 2323.95 .2423,95 "2523.95 .N 27.60 W._ 0,.33 · , . .... : :: . · .. . ::.. :/..: ...,... ':. t;::: ~'..'.' :'..:::',:: · . : . , .... :.:: · , ?y, ~t, 0'~: ::::: :3 N'38,39 E '::':"'0 33"':'::::. '::::::': 9 20 N:::.. ::. ":'2, 07: E ::': ''-~::::::: ''" · :':18 .N.:35'30. W :::.::: 0'29~: .. 9,46 N" 1.95. E :::. : :: ~:7~. 60: W : .,0.::39:.: ..... '..9' 61 .N_ L_4_~.F__ .-~. 0 2'2 S 48,89 W 0,25 9,26 N 0,78 E -8,54 0 11 '-" ~ 60, 19 W 0,30 8 '-""' ,o~ N 0.30 E -7.99 0 ........... .~: ....... S 48.30 N ,, _P.__-~!9_ ~.N O. 08_E ~-7.75 .... :.:.... : : · ·.:.:!'. .. . . .... . ...:...:: :___::: : ......: ..... . ..... ::.--: :.. ::: : :.. :i?' I :::'~. S:'.53.30:'::W:...::'.: . :~:0.09.... ":':'~ .... . ' 8.67'N ~ :'::. 0.01 W .' '0:: :4 ::N :29.39: E. 0:.09 :::'. 8..71 N 0.01 E :" ?7.69 :: 0 "::1:3 .N._i3.~...:.3_~-E:: ::';" :':: '......0.-1~-:: .':::::::' ':::': :-- ~- ;~. --':::' O. :t.6_E,:, .... -7, 0 19 N 27,89 E 0,10 9,:34 N 0.40 E -8, 43 0 13 N 33, 30 E 0,10 9.75 N 0,64 E -8,90 ........ P. ...... 37 ..... I~;?....E;Q_E ............ CS..~(:!. .......... 1Q...~;2._N :L..~!'F~_.F._ ......... ,9,62 _ 2623, 95 2723.95 ......... 26.~.3,_~ ARCO ALASKA, 3I=11__ KUPARUK ALASKA INC. SP._EF~~U~J_~ELI._~UBVE~[ ti i~..OMP_ANY ......... ANCHORAGE ALASKA __C~MP_U];AT IDN_i).ATE MAY 2, 1.989 COURSE 'DOG-LEG ~DATE OF sURvEY APRIL 17, ....... BO.~GYROSCOEIC~_UFLVEY dOB NUMBER AK-BO-90040 KELLY BUSHING ELEV. = OPERATORTMCGUI~E .... . ... · .: T~TAL :: :' ... 1989 · · 76.00 FT. VERTICAL SECTION CALCUL~TED'"ALONG CLOSURE :.~:::.. . .: TRUF ":iSUB-$EA COURSE ~,~ASURED VERTICAL VERTICAL L?TH DEPTH DEPTH INCLINATION DIRECTION DEG MIN DEGREES SEVERITY RECTANGULAR DEG/IO0 NORTH/SOUTH COORDINATES EAST/WEST VERTICAL SECTION 3100 3200 3300 3400 3500 3600 35.9.9,.92 3700 369.9,84 3750' :3749.65 2.923..94. 3023..93 3123..93 3323..93 3423..92 0 48 N 26, 30 E 0 25 N 33.~59 E 0 1.~ ......... __N.__4_7_.._3_'.a E 0 1.9 N 29.50 E 0 25 S 67./=.9 W 0 30 S ~.2.80 W 0.25 11.36 N O' 38 12.30 N ,___C..!.. 15 __12.80 N O. 10 13.22 N 0.71 13.32 N O.08 12.~8 N 1.75' E -10"85 ~ 2.26 E -11,.92 __2.67_ E -12' 55 3.01 E -13.08 2.80 E -13.07 2.0~ E -12.42 '.'.:' 12,:!56 N .. :::¥.. :" .9,.73 N ' . . : . · '"': :?::. :6.22 N 3800 3850 3900 3.950 4000~ii~ 4050' 4100 37.9.9.31 3723.31 7 28 S 32.50 W 3.24 1.27 N ~.60 W ~ 1..9.9 3848.83 3772.83 8 15 S 33.~9 W 1.5.9 4.47 S 10.34 W 8.81 38.98.29 3822.29 8 37 S 33.50 W O. 74 10. 58 ~ 14.40 W 16 ~ ~. 2 ........ ~' " ":?.... ~:~:~, '",': ... ~..:..:.' '" :~i?:.?''''!'' .?,:ii? ':'.'~ ..::i': "' "./':; ~ ? ':. :-:::!i.::.~'::.: ~..:~:~'.. ":?.'~ ~...'i:¥: ~. :: i ' .~iii::i.:." ' :'..:' ~.' ~':: .~!::;::¥...: :..:.. ..... -~ --. ~'~ ~'~ ~i?~=' i~?==~?=~='=" ?~i~ ~ .3~47, 54...:~:~871,54 ..::: ': .... 11 ~?:.~:~.:~ .:8.?::~::.~:: ...~:~ ::S:: ..:~ 1:.,.~ ~.:.:H:~: .:. :i: ~...~: ~. 5,::~.::' ~..~::~....~:~ ::. 17, ~3 ::: ~ ~:~:~::::~.: %~:. 18,?,.. W:.. .:'?~?:~.::. :':.; :?.~:::::24'~8 :.:~:,. 40~. 8~, 401~. 85 15 ~ S ~.~. ~o W o. ~ 4~. ~8 ~. ~.8. ~,4 W t. 1. ~3 4150 4200 4250 4300 4400 4500 4140,85 4064.85 17 I S 33. 0 W 3.09 ~,1.04 S 46,12 W 75.57 4188 45 4112 45 18 38 S 33,60 W _S..',28 ........ 7~.~!~'.~!~_:::~= :54.~.W_ ~0.82 ~ ~ i . ,'.. · :,. :~i; .:-:::: .......... . .... ,,~ . . , · ::,.,::....::...::.:,:.....,,.....::. : :.,:::~,... 4235: 78 ':'~ ?? ::"~ 1'59,:78 :: "."' '.:~:/':: :. 18 ?? 57:::~' ::~::~S' 33'~: 60: ~ W: :?::. '?~ :: .:?~:'~ ~ ;~::~2'¥' :~'~ ' ':~ :~:::87:; 26:' :S:~ ::''::. :. 63, 45' .W' . ..'::.: :~:~:~:!'06 ~':86:~':.~:.:.:.:::~ 4~82:84 :: :': 420~,::84:~..::/:~::::':' .~?'20:;:?:28. ::::..:::: :s' .'~l.8~.?u:: ':~.. :~'~?.~e::25....~::10~.,45:::s .. · 72 57 u: :.::.:~::~:~: ::::::::::::::::::::::: . ,, ,. :::: '... ~.: :..: . :... . , . : : ~:~:" .,. . :: . ::,: . m , · ::::: . ......... ........... 4~2~,:~.~..--.:~3. ~3 ~ '.'L 3~ '::_.~_~,.,~P~ W.,_/i~.::::~,:,~.:L ....... !..!.7~~__ ~ ..... 8.!.,.~6 ~. ' : _ 4375.40 4299.40 23 4 S 2~.50 W · 0.85 134.14 S 4467.39 4391.39 23 6 S 29.80 W 0.12 1~8.22 S · =,.=_~ ~- -' '_-~_C). , . 'T.~" ~ ~, ,-- 4700 4651 18 '. :4575,1 ':': ~ ': : '=.'~ '9':~' ' .: , 8 . 29 '.;.17 .: S.28,.87~'N 0,~96:~' ' .:'236:,81 S ' 2~ '~' ''~ .:.22. :::~....:': :.S' 28 .80. N 0,0~. ': .':..:. ~...~.:.~.271. ,': 50' S 4800 4743,01. .~.4~67,0~ :.. · . .: ................................................ ~1._ 5:28~:~ ' OJ& "' :306,3LS 4~00 4839~ 8~ .... ::~.Z~,.81.,_...:~..~.3. '~' "" ~' _ ........................ 5000 4')26.5'R 4850.59 23 24 S 27.80 N O, 24 341.33 S 5100 5018.32 4942.:32 23 32 S 27.3'~ W 0.20 376,63 S 91.5~ W 161.45 110.9~ W 200. 1.~2,.,=.,_Z_..u .... ~, .... :..- 23:~ .c.,,~ ' 14.9.88 W 27~~ .:i 225. ~2 w 438.27 ARCO ALASKA. ~INC. KUPARUK ALASKA ........ COMP_ UTA. T_I.~.N_I:!ATE ....... MAY 2. 1989 VERTICAL SECTION CALCULATEI~ ALONG CLOSURE · ::: f.. '::... VERTICAL INCLINATION DIRECTION SEVERITY DEPTH [meg MIN DEGREES [,EG/1OO ~E-~SURED--VERTICAL C TH DEPTH 5300 5201.38 5400 5292.75 ..... ~.~o ......... ~.--~3 5600 5476.09 5700 5567.76 5125,38' 5216,75 5308.33 24 I' 23 .' 54.:i, 23 : 26 ~ _ BOS~__~.YE~.I ~L_IRMF~y JOB NUMBER AK-BO-.gO040 KELLY BUSHING ELEV. = 76.00 FT. ........ I~"' I __ ___QPF~TOJ~_-~P.~ I RE .- ,. · ' ~_ToT~LS -~ "' . ::. ~ ... RECTANGULAR COORDINATES VERTICAL NORTH/SOUTH EAST/WEST SECT I ON 5400.09 5491.76 23 23 23 43 26.69' W O. 36 26.10 W 0.27 26. 0 W O. 46 25.30 W O. 28 24.69 W O. 42 5800 5659.34 5583. 5900 5750.97 5674. 6000 5842.61 '5766. 34 .448,34S~. · 484,73 S . .. 556.64 S 592.87 S 261.78 'Wi" 279, 84 W 314.6~ W 331.58 W ~.:518;80'.',. ..559.40 639.25 679.16 6100 5934.30 6140 5971.02 5895. 6200 6026.11 5~50. 6300 6118.00 6042. 6400 6210.35 6134' 6500 6303.36 6227. · i~:6321. 61 30 02 11 O0 ~ 37 S 24 50 W 0.13 23'2136 'S'23.30 W : O. 23 ' 36:.i..'i? ~..~i~ S'22.80 W O. · : ~3":':~:26' S: 22.60 ~ .... O. 23 16 S~.~ 60 W O. 23 23 ~ 23.19 W O. 20 6 ~ 25.69 W 1. 35 36 21. 7 6700 6491.80 6415.80 19 6772 ~559.87 6483.87 19 1 629.38 S ';'~-' . . · ;,~.~.29 W 719.24.. 48 .::: "665.99' S~ i '364.~52 W: :.':~!/!' ::~i~;'75~;:.~ !8 20 "702 83 S ::J 380.1~ :.W ' !::.: .:.7~ 06 ' ? "' : ':.:: ' .... :,.: :,i: .. '.' ..:.' .. ti:: 40 754.29 S 401.69 W- , 854.58 44 776.18 S '410.94 ~ 878.25 03 ,c:t'., ~,', c: ~27.2t_._~. 917262__. - ~.~.~I .............. S'30.19 W 2.05 845.96 S 445.19 W 955~3 S '30.39 W 0.87 877.68 S , 463.72 N .992. ,~.~, ..o..,' ~;~-,'- u ~ ....... --.~._~;~ .... . ,-.~~.z~s'" .~' :,' ....: ':.:':.~_.. ..:.:::'~a.~~_w_.'~ :--,_ ~:o~.;: ~s S 30.89 W 0.00 9:35.19 S 497.96 W 1059.50 S 30.89 W 0.00 ~55.33 S 510.01 W 1082.95 HORIZONTAL DISPLACEMENT. - i082.~$: 'FEET':':~'f'"".S'~IUTH::'28:'::DEG,::::/' ..... 5:i"i!MI~'''' WEsT'AT MD =" 6772: ."::~:!:::.:..: :;~::.i: ::"i::.i i.:!:ili:i''~. ARCO ALASKA, '.3_!~-11 KUPARUK ALASKA INC. ...... ~.R_EY_:~UN_k~ELk ~URVEY.IN~_ ANCHORAGE ALASKA ¢OMPUTfiTO~ATE MAY 2, 1989 DATE OF SURVEY APRIL 17, 1989 '~ - . '. .. dOB ~NL~MB'ER AK-BO-90040 KELLY BUSHING ELEV. = 76.00 FT. OPERATOR-MCGUIRE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH· · TRUE VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NO~TH/SOUTH __EAST/WEST DIF_F.~_E.N_C:E VERTICAL CORRECTION 0 0.00 1000 999.98 2000 1999.96 3000 2999.94 4000 3996.31 5000 4926.59 6OO0 5842.61 6772 -76.00 923.98 0.00 0.00 0.00 4.27 N 2.68 E 0.02 1923.96 9.61 N 1.45 E 0.04 2923.94 11.36 N 1.75 E 0.06 3920.31 27.22 S 24.69__W__ 3.69 .~ 5766,61 ~ 6559.87" ~ :~483.87 .' .-', :' c~41. ~m · s 206.67 w 702. m~ s :~::,'i'i~':: ..~8o- 19 w · · ., 9~5.33 ~ S.:::~':.~:i :510.01:. 'W ,' ' O.g.2 O. 02 O. 02 3. 73, 41 .:69.72 :: ,:: 157, 39 .. ::83.99 ' .' 21__2,'!.3 ' 54.74 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE DIMENSIONAL RADIUS OF CURVATURE METHOD. ARCO ALASKA~ ' INC. 31-11 KUPARUK ALASKA SURED TRUE VERTICAL DEPTH INTERPOLATED VALUES* FOR *EVEN· 100 FEET OF suB-SEA DEPTH* SPERRY.SUN WELL .$UI~VE¥ING COMPANY. _. P~G£. '" :~':. ~ "- .......... ":. "DATE OF "SURVEY MAY 2, 1989 JOB NUMBER AK-BO-90040 KELLY BUSHING ELEV. = 7~.00 FT. ~_ OPER~T~MCGU '~. . . . SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE ;/ 0 0.00 76 76.00 0.00 176 176.00 100.00 276 276.00 200.00 376 376.00 300.00 476 476. O0 400, O0 576 576. O0 .'~ 500. O0 · . ..... ........... 600.00 776 776.00 700.00 876 876.00 800.00 976 976.00 900.00 ! 076 1076. O0 1176 · 1176'00 · 1276 ' 1276~00 1376 1376. O0 1476 1476. O0 VERTICAL CQBR_E. .T_I ON · ' 0,00 0.04 N 0.26 N 0.72 N 0.01 E 0.00 O' OD 0.07 E 0.00 0.00 0.23 E 0.00 0.00 1.40 N 1000' O0. ":::: 1100.:00 ::? :::::..: '?::ii::::12QO. 00' " :' '1.99 'N · 2.45 N 2.81 :N 3.20 N 3.66 N 4 · 1_4_~ .:4.63. N .:::::"5:· 07':. N :!:::::'. 5, 1300.00 1400. O0 1500· 00 · ::"I700.00-': ' ' 6.74 N 1.78 E 7.72 N 1.88 E ':' 35 N 2 13E ,, .1~.1 · .......... · - . .~ · ': 8.'76::. N '.' ::::::.. .. 2,, 25 '" 9.:18 N . '::::': :".':'2.06: E' '"': 0.03 O. 03 _C.! ,_.Q;3_ __ .':' 0'04 ":" 0,'O4 . O. O0 O.01 0':.00 '. O. O0 ARCO ALASKA, 3 !,_1.._1_ ...... KUPARUK ALASKA INC. ANCHORAGE ALASKA , ': ":. " "--: ::i "jif:%'.' '::' :': DATE OF.SURVEY APRIL 17, 198.9 - CO~PUTATIO~J_~O~E ..... ~ ': '' MAY 2, 1.98.9 JOB NUMBER AK-BO-.90040 KELLY BUSHING ELEV. = 76.00 FT. OPERATOR-MCGUIRE FH 'INTERPOLATED VALUES. FOR. EVEN :1'00 FEET' OF SUB-SEA DEPTH ':;;i~.i : .: -TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MB-TVD VERTICAL DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 1876 1.976 2076 2076,00 2000,00 2176 2176.00 2100.00 2276 2276.00 2200.00 2376 2376.00 :..!,2300.00 2476 2476.00<i :.2400,.00 2576 2576.00 :i::.2500.00 ..:: 1876. O0 1800, O0 .9.35 N ...... 1_ .976:.00. ....... _1900.._0..o.'.. ................... ~,,_&_.4_ _..N .9,40 N 8..93 N 8,77 N 2.03 E I_..62__E_ .... 0..9:3 e 0,38 E 0.11 E . e, e5.:'N: ': :,,.:?:!,.:::!" O, 10 £ . 0,04 O. 04 O, 04 0.04 O. 05 :' .0'.05~__ .... :;.0,105 O. O. O0 _ c.).,..O0 O, O0 O, O0 O, O0 ::! ':0.00 !i! O, O0 · O. O0 2676 2676.00 2600,00 9.22 N 0.34 E 0.05 0.00 2776 2776.00 2700.00 .9.67 N 0.59 E 0.05 0.00 2876 2876.00 2800,00 10,12 N 0,.93 E 0.05 0.00 ~:...? :1 :'7~:::: ::: ::: :::::::§:17~'~ O0 ~::: :::::::: :'~: :::::::~ :::::::::::::::::::::::::::::::::::::::::::::::: 7:::: ::: ::?i:::~:: ~ :i': :::::~:::: :::::::::::::::::::::: :::::::: i: ::~:::: :~:~: ::Se ::: ~: :~:::: i:i::: :::: :!::: ::::::::::::::::::::::::::::::::::::::::::::: ::: ::: ~::~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: i 00· , ::i::::: :! :::: :: :::: :::::::::::::::::::::::::::::::::::::::::::::::::: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .... '~':' 3276 '3276.00 3200.00 13.11 N 2.94 E 0.07 0.00 3376 3376. O0 3300. O0 13.39 N 2.96 E O. 07 O. O0 :3476 ~76, O0 ~g00.00 ..... 13..Oe N 2, 25 E ...... 0._07 : 0.00 "- , ~75 <'.< ':~,75;:oo:?: .':"'~uOo;':Oo: '"~'?'?::':::":':::"~' l'2;:s~':N:~':::::':::.~::::~:::.:~l o~':63::::':::':'<':~:~ ':'~?":'~:'6.00 .......... ' ....................................................................... ' ...................... ...~7~ :' ~7~.'oO.' ':::~ ;:56oo.'oo'..'.: :~:.~':~::~:::;:..:. :lo; emN:~ :::~?:.::7~:~:::~o. 41.~:: :' ====================== o;,'12 :':, ::: .. :.' .: .,::': ::,:. '?:" o. o4 ~ ~ ~,, ..~.. ,'~,' ,' . .,,. . ~ ....:::.L ... :. ., . . : .:<; . . ~ . ... : .... ,,. ,,,,..~ .- '~:i~;: '- - . ANCHORAGE ALASKA :i'-~ ~:.. : :::i:;.- ::.~;' .3.._I.-..1. 1_ ..... '~' ....... COMPUT~I:ION._~.AT.E" "' . ._ . -~..: KUPARUK MAY 2, 1989 dOB NUMBER AK-BO-90040 ALASKA KELLY BUSHING ELEV. = 76. O0 FT. 6,. _~PE[~R--MC6U ! RE ~'"L~;;::": ~:' .... " ': '" ~"'"' '"~' '" ' . INTERPOLATED VALUES FOR EVEN :100 FEET OF SUB-SEA' .DEPTH.,. . ::.: · " ' ' '. ~ :",,. '.:i: .. TRUE SUB-SEA TOTAL ~r~SURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERT I CAL ~r'TH DEPTH __DEPTH N_ORTH/SOUTH __EAST/WEST D_~_F.F~.R__EN.C.E .......... "' " 3776 3776. O0 3?00. O0 ':3.79 N ~. O0 ~ O. ~0 .' Oo 38 ' ..... 38?7 3~76. O0 $~00. O0 7'. 77 S 12. ~4 14 1.4~ O. 95 ............................ 3979 3976. O0 :3.'::>00. O0 23.0:2-{ $ 22 o ! S 14 ~. 11 1. 4082 4076. O0 4000. O0 45 · 35 S :36.03 W 6.51 3 · 41 4186 4176. O0 4100. O0 70.34 S__ 52 · 21 W 10 · 87 ......... 42~2' 4~6.00 !"4200.00 . ..' 99'28 S 71.22 W 16.70 ': · ~''~ 5.83 .' ' ' ~ :' · ;'' 4400 4376'00 ..4300 O0 ' 134.36 S ¥.~ ~ ¢1"~69 Wi.' 24'6.5 .... ~: 'L::'":i 7.~5 .'.i · . . . , l; ' ' ' · ": "' ':' " :':!:" :'~ i:' ' "' "i i i. ' ': ' 4.5__(!9 4476. O0 ii~:~400. O0 ':'"" 171.41' ':' S 112.7~ .:W . ~ · ': 33. L~_~_. ~ ' ..~.~_7~ ....... · ii::. .?~::iiii!.. ~?:!:i ,?i~ .~:i~:!- 4618 4576. O0 4500 · O0 208 · 59 S 134 · 08 W 42 · 16 8.80 4727 4676. O0 4600. O0 246 16 ~-' · c. 155.04 W 51.02 8 · 86 4835 4776.00 .4700._0o ........ ~._.~.,.~ _175. L~6..W . 59.. ~4 ........... C4 ..... '~.~. ~ ~.~::¢;~00.00 · ...... Z1~...~7..~,. ~,.. 196,43...W.. ~..~;~:.&8:87 ~.~;:...;..,,~:,~;~..: ..... 8...3 4944..:.. '~:~.:4,.876.'00 r..r <? .o. '. ~:.:~?i.::~ '.::': .2". '~' ~:~'.c:' '~ .... ~:::= '. · .... ~:.. ..i=:.:~=~'= r:~.. ::i':?'= '. 5053 ' :" :.4~76;00 "'?,g ~ ':': ~:?~":?:' : ''~' :~' '~': ~/~'~ '-~ :'~ ''~ ~ ':'~'~'~ :'~:~' : ' '~ ''' ???''~::' :~':~';:~;;: ~ ~-'.' .......... ?.,,4.00.,00....~.;~.~: :.. :..~0.27..~.S ..¥.. ~ 16. ~.4 ~.W .~ 77. ~: ..: .~.;~.?~ . 8... ~ ~., ,_,~?~ 5!76 O0 5tO0. O0 438.2:3 :-': 256.70 W ~6.21 9.28 5~8! 5276. O0 5200. O0 478.06 S 2?6 · 58 14 ! 05 · 6? __5490 5376,00 5300.00 517,57 S ....... 295..,90 W ..... 1!....4.~,72. · , 5599 5476. O0 ::'.:: ~:5400.00 "' :': ' ' 556:" 61 ''~''::S :.::.:::::: 314,67: W : ::: '?'::123· 90': : ::' 8 98 : : ' . , ., :., . ' , : # : :..: :!:, ,. 5709 5576.00 .5S00.00 5'F.~6.16"S ':'333.09 W : .133 '00 : 9 11 ': ::!:' '~".:.' ,.. · . ::: # : . ·. · :::..: ,. · .. ,. ARCO ALASKA~ 3. I.-_! ~_ KUPARUK ALASKA INC. _.~P_EE~~UNJ_, WELL SUliVE.Y_~I'J~'._~N¥ ANCHORAGE ALASKA CQ[¥!p_~TAT_i_O_N_~A TL___ _ -'- MAY 2, 1989 /~"~!SURED '~TH DATE OF SURVEY APRIL 17, PAGE 8 ~:. ~:, .. JOB NUMBER AK-BO-90040 KELLY BUSHING ELEV. = OPERATOR-MCGUIRE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH :.. TRUE SUB-SEA TOTAL VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 76.00 FT. 5818 5676.00 5600.00 636.01 5927 5776.00 5700.00 676.04 6036 5876.00 5800.00 716.28 6145 5976.00 5900.00 756.27 6254 6076.00 6000.00 795.93 351.32 W 142· 18 3_68.84 w 1_~ z__. J:2 385.85 W 160.44 402.51 W 169.42 419.53 W 178.34 6362 6470 6577 6176.00 · :6100.00 833.97~ S 438,21 6276,00 · 6200 , 00': :: 6376. O0 :: :' i.:' ~300~~'00 ;~;: /~';" "?. 9~0.~'~2'~;iS':i:.!:" ':;:,~::~;;':':"477i~45 9.18 9.13 9.12 8.91 ~.: 8.62 " 7.72 '::::!' 6.83' 6683 6476. O0 6400. O0 930 · 51 S 495.16 W 207 · 29 5.78 , 1/6772 ~/6559.87 6483.87 ~/955.33 S ~/510.01 W 212.13 4.85 THE CA'LCULAT::!.'oN :. '.' PROCEB~R'E~ '~iilUSE::::~:.'!'~",:::;:."L'!'N:E~'~!i':! ::·i:NTE~:~!~i~.:!:~N .::BE~NEEN"'..':' ::' r....:.~;::::~::::~::~..;?::~ ??.~.~:~:.:.~ ~?.: :?~:~.: ;:.~i~:" ::. :.:/::::~ ::?.~.'~:; >~?:~;?~: :?.?~:.;~' :. ?/':. :?~;:~;:=~?'/~;~;~]~ii~?~. :.'!~:= ~?.; ;:~. · THE NEAREST.:: 720 FOOT ;.MD..~:(~EROM...'R~DI:US .:.:~F .;'COR~TUEE).;::;~O'I'.NTS ::.L:;::;:::-. ~;'t:: .::. :::?. ':?~?.::;~.?...~:': :..:~.;t:~;:?.:j~;::~:~:r:~:~i::.:: ~.::.~:~t:: ~:~;:'~.~::;~it' ..::; ?::~: :?:::? ;:':.??: '~:;?t~?;~/~/::?~;?:~:~?~::/?.: ARCO ALASKA. INC..:: :: 31-11 KUPARUK ALASKA MAY 2, 1989 TOTAL RECTANGULAR COORDINATES TRUE SUB-SEA VERTICAL VERTICAL JOB NUMBER AK-BO-90040 KELLY BUSHING ELEV. = 76.00 FT. .OPERATOR=MCOU!RE ......................... DEPTH DEPTH 6401 6211.28 6135.28..: 6405 6214.99 6138.99 6426 6234.46 6158.46 6456 6262.31 6186.31 6600 6397.27 6321.27 NORTH/SOUTH EAST/WEST MA_R.K__ER : 84'6'~28., ~ . i:i?::.~. 445,38; W' . TOP KUPARUK: 'C :::': :!: .. !::" .' "i.. 847,'58 ": : 446 · 13". W' : BASE KUPARLIK C : - 854,37 864.01 907.21 450.09 W 455.70 W 481.21W TOP KUPARUK A BASE KUPARUK A SURVEY DEPTH ~ ~ 'ARCO ALASKA. : ~!! '. :: ~. DERIVED USINO DIL DEPTHS AND SPERRY SUN SURVEY DATA .MARKER-· COORDINATES ............. _ ----..-. .... .--.-.- --.----.-.-...._.. ..... ..... ,... F..JL .....m..J.... ,? ......... ...:. ...... .:..- - · ':'i?. ::: ::ME~RED"DEPTH: :~:-'-':"'~':' ?:':? ?L:'~'~-~-TVD':F':~?~, :?"":"::: ': ..... THICKNESS'-:' ''?' :~:.:~ :"":'::~' W I TH RE ;~::.?~:. TO' WELLHEAD ~:.~ F~OP K~PARUK C '~'BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD 6401 6405 '6456'": 6680 6211.28 6135.28 6214.99 6138.99 '.L16234,:46 :i::~:76158,46 '.".~ :<' :i~: :':.::.!....:'. · ':'::i:':6262'31 · .618~,'31 .: :~: 6472.89 6396.89 846.28S 445.38W 847.58S 446.13W :..:.,... :r 92~. 59S 4~4.61W 6772 6559.87 6483.87 955.33S 510. O1W .... ii.i,?ii!!i::: ,.'.i'i::ii:i:?::!.:: 2)" cOMpuTER': pROGRAM~ -- SPERRY'! SU~':::'T:HRE'~' · · . . · :.::. · . :::::.::, .... .D~..T~_.~ALGULOTJ E!N_.., AN_D.... !_I~!T_EB_.O., ~i~_T_!:__ON--B_Y. ?_~_D I LIS .--C~F.~L~U.RVATL/.,R_'E:?!:,::.,,, ..::"~: ' ' . ~;'.~: DATE OF SURVEy._...A~]. 7, 1989__ ::.COMPUTATION:~::i DATE.::;:/.:i.:'~;,:i~!i?!:.i/?~:i:i :::.:~.i~!i!i?: i' :;:...?.!'~::: i!.: :::. :' i~!: '. ': :., ;~ii!:ii::: iii~',:. :,.;: :' .~' :':'MAY. 2' .1989 : · :'' : :"~.:" ' iii:i;'::'::,:ii:ii:~'IOB!i'iNUMBER:!:AK:'BO-~O040 .' " : .. KELLY BUSHING. ELEV. = 76.00 FT. " , ....... SPERRT -SUN 5CRLE :- 1 INCH TO 500.00 / SO0. O KUPRRUK 31-11 AK-BO-gO040 TRUE NORTH RRCO RLRSKR. INC. RPRIL t?. t989 -sob. oo --500. O0 ~* 6772 ,-1000. OD SPERRY -SUN 5CRLE :- 1 INCH TO 1500.00 / 1500.0 KUPRRUK RRCO RLRSKR, INC. 31-11 RPRIL 17. 1989 RK-80-9OO4O 0.00 - 1500.00 3000.00 4500.00 6000.00 7500.00 i VERTICFIL -6772 15~0.00 PROJECTION ' APPLICATION FOR SUNDRY APPROVALS '~'.' ~ype 0f 'Request: Abandon ~ .... sUSPend ' Ope~ati~n shutdown_ ' ...... Re-enter suspended well ~ ....... Alter casing _ Repair well _ Plugging _ . Change approved pr,ogram ,-- , Pull !ubing ~ '~i' '~'~m'e of Operator 15. Type of Well: I Development ARCO Alaska. Inc. Exploratory 3. Address I Stratigraphic P. O. Box !00360, Anchorage, AK. 99.510I Servia ... '~t.' '1' 0'cation of well at surface 147' FSL, 48' FEL, Sec. 36, T13N, R8E, UM At top of productive interval 699' FNL, 1016' FEL, Sec. 6, T12N, R9E, UM At effective depth 783' FNL, 1066' FEL, Sec. 6, T12N, R9E, UM At total depth .... 8.0.8' .FN..L.,.. 1081'. FEE, . Sec~ .6,T12N, RgE, UM 12. Present well condition summary Total Depth: X measured 6 7 72' feet true vertical 65 60' feet i i Plugs (measured) Time extension _ Stimulate _ va,fiance ..., ,, Perfor,a, te ..~..' Other_ 6. Datum elevation (DF or KB) , 76' RKB, 7. unit or Property name Kupar,uk River Unit, 8. Well number .31-,11 ..... 9. Permit number 89-35 ....... 10, APl number so-029-21 932 .. 11. Field/Pool Kuparuk River Field Ku,.paruk River Oil Pool Effective depth' measured 6 680' feet Junk (measured) true vertical 6 4 73' feet Casing Length Size Structural Conductor 8 0' I 6" Surface 3348' 9 - 5/8" Intermediate Production 6 7 2 8' 7" Liner Perforation depth: measured 6457'-6486' true vertical 6264'-6291' Cemented Measured depth True vertical depth 250 Sx CS II 1 1 5' 544 Sx AS III, 3383' 175 Sx AS I, & 330 Sx Class "G" 175 Sx AS I & 6 761' 250 Sx Class "G" Tubing (size, grade, and measured depth 2 7/8", 6.5# J-55 AB mod. tubing set at 6334' MD Packers and SSSV (tyPe and measured depth) .. Otis 10 mR SSSV @ 1790'' u,p; ,AVA EHS pkr. @,.,62,6~' MD. 13. Attachments Description summary of proposal _ Detailed operation program .~. .... Add,.perfora.~ions to the A sand 14. Estimated date for comm~n'cing oPeratiOn '~ I1'5. status of weii classificatio~ as: . February 1990 . i Oil _~L Gas _ 16. If proposal was verbally approved '1 Name of approver Date a,p,Proved ...... I Service , , , 1~'7" I' hereby'(~ertify that th~,~omg0ing is true arid Correct to the best of my knowledge. Signed ~O_.,x[.~ <~//'/~.t~(~..~_~~ Title Senior Operations Engineer .... FOR COIV~ISSION USE ONLY ~;~di~i'~';~'s 'of a'ppr~al': Notify"commiss'ion so repm~entativ~'' m'a'y witness ......... Plug integrity _ BOP Test _. Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-~ 115' 3383' 6550' RECEIVED /~iaska Oil.& Gas Cons. Commission ~ch0ra~ i BOP sketch_ Suspended _ i , IApproval APproved by the order of the C.o, mmission Fnrm 1D-4~3R RAv ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner ,~11RMIT IN TRIPl I~ATI:: · © © Application for Sundry Approval Kuparuk Well 31-11 February 5, 1990 The estimated bottom hole pressure is 2400 psig at-6200' ss based on data taken on November 3, 1989. 2. No workover fluids will be required for perforating. . There will be a lubricator with a 5000 psig rated BOP used during the perforating work. FEB .t 6 ]990 ~': ~.~. '~:.ska Oil & Gas Cons· Anchor~a Kuparuk Well 31-11 Perforating Procedure (2/S/90) AFE #AK4117 *** A CTU cleanout is required prior to perforating *** 1. Obtain at least one 12 hour test prior to perforating the well. 2. MIRU perforating unit and pressure test equipment. 3. Shut-in well. 4. RIH with 2-1/8" through tubing perforating gun below tubing tail. The following charges are acceptable for perforating Well 31-11' Vendor ~ Char_~e Weight Atlas Wireline Silverjet (2-1/8") 16.0 grams Halliburton Dynastrip (2-1/8") 20.5 grams Schlumberger Enerjet (2-1/8") 13.5 grams 5. Open well and tie in to the following logs: DIL/SFL dated April 3, 1989 CBL dated April 16, 1989 Short Joints: 6410'-6449' MD-RKB (from CBL) 6. Once thc tools have been tied in, perforate the following intervals at 8 spf (+/- 30° V phasing) with the well flowing: 6437'-6454' MD-RKB (A3 interval) 6494'-6503' MD-RKB (Al interval) 7. Shut-in the well and POOH with perforating guns. 8. RDMO perforating unit. 9. Return well to production. 10. Obtain two 12 hour test as soon after perforating as possible, in order to help quantify the benefits of perforating Well 31-11. RECEIVED ~.:~:;~a Oil & Gas Cons. Cornmjs~io:~ ~nchor~ ,.~ 2 '3. H00 I~1 4 l/e" LUImml~ 4. ~Q00 PSi 4 l/f' tq.~ ~ PAC:IC-~r I il I I I I II · -- ' STATE OF ALASKA ' · A~ OIL AND GAS CONSERVATION COMMI~N /~ REPO OF SUNDRY WELL OPERATIONS0 8 1 & IN 1. Operations performed: Operation shutdown __ Pull tubing _.._ Alter casing 2. Name of Operator ARCO Alaska~ Inc. . _ 3. Address P. O. Box 100360~ Anchorage~ AK ., 4. Location of well at surface 147' FSL~ 48' At top of productive interval 699' FNL~ 1016' At effective depth 783' FNL~ 1066' At total depth 808, FNL~ 1081 ' 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical StimUlate m Plugging Perforate ..~ Repair well Pull tubing 5.. TYPe of Well: ' ' ," Development ~ Exploratory.._ 9951 Stratigraphic __ - 0360 Service w . FEL, Sec.36~ T13N~ R8Es UM FEL~ Sec.6, T12N, RgE~ UM FEL, Sec.6, T12N,.RgE~ UN FEL~ Sec.6, T12N~ RgE, UN 6772' ND 'feet 6560' TVBfeet 6680' ND feet 6473 ' 'TVDfeet Size Cemented ' . Plugs(measured) Other jf~. Comp1 ere 6.' DatUm elevation (DF or KB) R K B 76 ' feet 7. Unit'or Property name Kuparuk Rtver Untt i 8. Well number 31 -11 9. Permit number/approval number 89-35/9-310 10. APl number '50-- 029-21932 11. Field/Pool Kuparuk R~ver Oil Pool None Junk (measured) N o n · Measured depth True vertical depth 16" 115' TVD 9-5/8" 3383' TVD 250 sx CS II 115~ND 330 sx Class G & 3383'ND 544 sx AS Ill & 175 sx AS 250 sx Class G:& 6761~ND 175 sx ASI 6550~TVD Casing Length Structural Conductor Surface 80 ' 3348' Intermediate Production 6728 ' Liner Perforation depth: measured 6457'-6486' ND true vertical 6263'-6290, .TVD Tubing (size, grade, and measured depth) '2-7/8' 6 5# J'55 w/tail (~ 6334' ND Packers and SSSV (type and measured depth) Otis 10 TR SSSV ~ 1790' MD~ AVA RH$ pkr ~ 6262' MD 13. Stimulation or cement squeeze sUmmary I nt~s treated (measured) RECEIVED IUN o? Co.,. Treatment description including volumes used and final presSure 14. N/A Representative Daii' Average prodUction °r'lnjeCtior~ Data II OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation . . . 15. Attachments 116. Status of well ClasSificaUOn as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations ~ Oil .~. Gas ,__ Suspended ._. 17. I hereby certify that the foregoing iS true and correct to ~he best of mY knOWledge. Service Area Drilling Engineer . Title '' SW01'/6 SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 ARCO Oil and Gas Company Wall History - Initial Report - Dally Instmctlone: Prepare and .submit the "leillal Re~'. on the-fires Wednsudoy after & well Is 0puddad or workover operations are started. Dally work prior to sPuddlnt ~.hould_be summarized on the form giving Inoluelvt dates only. District I County, pari~h or bm:'ough ARCO ALASKA IHC, I HORTH 8LO~B Field ILea. or U'~lt ' ' KOPAROK RIVRR I ADL: 25631 Auth. or W.O. no, JTItlo' AK4117 I COM~LETIOHS I Stat~ 3I-1[ Well no. 50-029-21932 Operator ARco Spudded or W.O. begun IDato ACCEP?ED. I 05/18/89 Complete record for each day reported llORDIC 1 Date and depth as of 8:00 a.m. 05/19/89 TD: 6680 PH: 6682 SUPV:LP I ARCO W.I. IPrlor ssa'Sue If a W,O. IHour I 55 · 8533 1'/ 00 RXH #XTH SSSV & CONTROL LIMB 7"9 6760' ~M:XX.8 NaB= MOVB RIG FROM 3X-10 TO 3X-11. ACCBPT RiG AT 1700 HR 5/18/89. H/D TREE. H/U & TRST BOP. R/U SOHLOMMID ~BRIP F/ 6457'-6486' WITH 4-1/2" 48~F 90 DBGRBB ~IUk~XHG HSD G~tla. R/D SCHI,UM, R/U FLOOR TO ROll COI~LBTIO~. R0tl COML~I,BTZOH. OTIS 8SSV 9 1790', AVA RH8 ~HR J 6262', TOBXHG TAlL J 6334' DAILY:S48,327 C0M:$869,538 BTD:~869,538 BF¢:$1,330,000 REEEIVED Alaska Oil & Ga~ Con& Commission '.Anchorage The above ia correct see Procedure8 M~lt'dal, Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D INumber ,,ti dally well hi~tory fermi ooniooutlvely as they ire prepared for oaoh well. Page no. © ARCO Oil and Gas Company Dally Well History-Final Report Instructions: Prepare and submit the "Flail RaINier" on the first Wednesday after allowable hal been aeltgned or well II Plugged, Abandoned, or 8old. "Final Report" should be submitted also whe. operations a~ suspended for an indefinite or appreciable length of time, On workovare when an offiolal tilt Ii not required upon completion, report completion and representative test data In blocks provided Tile "Final Riled" form may be u#d for report ng the ant re operation if space is available. District AECO ~T. Ji~S~ INC. Field KOPARUK RIVER Auth. or W.O. no. AK4117 Operator ]~RCO Spudded or W.O. begun ACCEPTED Date and depth as of 8:00 a.m. 05/20/89 ( 1 'I'D: 6680 PB: 6682 SUPV:LP ICounty or Parish ILease or ~i~L: 25631 I TItle COMPLETIONS API: 50-029-21932 A,R.Co. W.I. Date 05/18/69 Complete record for each day reported NOEDIC 1 I,~ooountlng StateA,~, COlt center code 3Z-11 IweJt no. I 0tal number of wells (active or Inactive.) o0 th_is oat center prior to plugging and 55 bandonment of this well Our 17 ~00 IPrlor Itstus If'e W.O. I RIG RELEASED 7"9 6760' MW: 6.8 DIESEL HUN COMPLETION. PRESSORE UP ON TEG AND 8BT P~Q% W/2S00 PSI. HELD FOR 20 MIN TO TEST T~. P~S8 ~ ON ~8-8~ OUT PBR WITH 44,000J. S~CK V~ NITH 2300 PSI. S~ OUT B~ NITH 3300P8I. SET BPV ~ N/D BOP. ~D TEST S~ ~ 5000 PSI. R/~ OTIS ~D P~ AVA C~CK V~. ~D P~- P~CE WZTH~ORZFZCE V~. DZSP~E WITH DIESEL. SET BPV ~D ~B RIG. DAILY:S113,281 C~:$982,819 ETD:$S69,819 EFC:$1,443,000 Old TD I New TD IPe Depth Released rig IOate IKind of rig Classifications (oil, gas, otc,) I Type completion (single, dual, etc,) I ] '~)fflclal roslrvolr name(e) Producing method Potential test data Wall no. Date Reservoir Producing Interval OII or gasTint time Production 011 on reit Gas per day Pump size, gPM X length Choke size T.P. C.P. Water % OOR Gravity Allowable Effective date corrected The above is correct I=/ , Drilling, Pages 86 and 87. AR3B~5~3-C INumber ell oantecutlvely prepared for each well, las they are dally well history fermi iPage fiD. Oi~lMofl of AtlafltJe~loMleldCemlMmy ARCO Alaska, Inc. Date: April' 24, 1989 Transmittal #: 7461 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 31 - 1 6 OH US Tape and Listing 3 - 1 7 - 8 9 # 7 31 9 0 ~"1-1 I OH LIS Tape and Listing 4- 0 8 - 8 9 # 7 3 2 6 9 31 - 1 0 OH LIS Tape and Listing 4 - 1 3 - 8 9 # 7 3 2 8 5 31 - 0 6 OH LIS Tape and Listing 4 - 2 0 - 8 9 # 7 3 2 9 0 Receipt Acknowledged: DISTRIBUTION; Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: April 24, 1989 Transmittal #: 7458 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 31-06 5" Dual InduCtion 4-17-89 3459-7083 31 - 0 6 2" Dual Induction 4 - 1 7 - 8 9 3 459 - 7083 31-06 Cyberlook 4-1 7-89 6390-7030 31-06 2" & 5" Raw FDC 4-1 7-89 5490-7057 31-06 2"& 5" Porosity FDC 4-1 7-89 5490-7057 31 - 1 0 5" Dual Induction 4 - 1 0 - 8 9 3 411 - 7080 31-10 2" Dual Induction 4-1 0-89 3411-7080 31-1 0 Cyberlook 4-1 0-89 6450-7050 31-10 2" & 5" Raw FDC 4-10-89 6450-7050 31-1 0 2" & 5" Porosity FDC 4-1 0-89 6450-7050 5" Dual Induction 4 - 0 3 - 8 9 1 000- 6720 ~i' 2" Dual Induction 4-03-89 1 000-6720 ~'~i:1~1'~-~1 Cyberlook 4- 0 3- 8 9 61 50- 6700 ~1i~,1i~ 2" & 5" Raw FDC 4-03-89 61 50-6694 3i~!~1~:1~ 2" & 5" Porosity FDC 4 - 0 3 - 8 9 6150- 6694 Receipt Acknowledged: DISTRIBUTION; ........................... Date i-:=. NSK Drilling L. Johnston package) Ott & 6as Co~s, C0mmtssioa 1. Type of Request: Abandon __ Alter casing __ Change approved program __ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ APPLICATION FOR SUNDRY APPROVALS-- Operation shutdown ~__ Re.enter suspended well __ Plugging __ Time extension __ Stimulate __ Variance __ Perforate ~ Other 2. Name of Operator ARCO Alaska, Inc. Suspend __ Repair well __ Pull tubing 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 147' FSL, 48' FEL, $ec.36, T13N, R8E, UN At top of productive interval 550' FNL, 1000' FEL, Sec. 6, T12N, RgE, UN (approx) At effective depth 764' FNL, 1073' FEL, Sec. 6, T12N, RgE, UM (approx) At total dep_th 789' FNL, 1088' FEL, Sec. 6, T12N, RgE, UN (approx) 6772 'ND feet 6563 'TVD feet 6680 ' MD 6476 ' TVD feet feet Plugs (measured) Junk (measured) 12. Present well condition summary Total depth: measured true vertical None None 6. Datum elevation (DF or KB) RKB 76' 7. Unit or Property name Kuparuk River Unit 8. Well number 31-11 9. Permit number 89 -35 11. Field/Pool Kuparuk River 0il Pool Effective depth: measured true vertical Size 16" 9-5/8" 7" feet Cemented Measured depth True vertical depth 250~ sx CS II 115'MD 330 sx Class G & 3383'ND 544 sx AS !11 & 175 sx AS I 250 sx Class d 6761 'ND Casing Length Structural Conductor 80 ' Sudace 3348 ' Intermediate Production 6728 ' Liner Perforation depth: measured None true vertical None 115'TVD 3383 'TVD 6553 ' TVD Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Description summary of proposal 13. Attachments Wel 1 History 14. Estimated date for commencing operation Nay 1989 16. If proposal was verbally approved Date approved RECEIVED Alaska 0il & Gas Cons. C missi0n Aprhnr~NR Detailed operations program __ ' .... -BOg sketch __ 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance Mechanical Integrity Test_ Subsequent form required 10- //'-~ '~ --Dyed Copy /kOp~U .... · Retur0,ea,,~ ORIGINAL SIGNED BY Approved by order of the Commission LONNIE C. SMITH Commissioner Date 071/SA4 IApproval No. Date "~'-,~/" ~' SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well HIitory - Initial Report - Dally Instructions: Prepare and submit the "lld#M Rel~.~' on the first Wednesday after a well II spudded or worl(over optrltlonl ail ltlrtld. Daily work Prior to spuddlng;41muld be summarized on the form giving Inclusive d&taa only. A~CC Operator J County, pa r illl~RS~'.,OpE Loam or U~IlDL: '25631 Title DRILL . Date and depth as of 8:00 a.m. ?D: 0' ( SUPV: LP ~I: 50-029-21932 Spudd.d o, w.o-?. {~. l oots 03/28/89 Complete recod~h ~11~1/reported o) 03/29/89 ( TD: 1878'( SUPV:LP 03/30/89 ( TD: 3403'( SI~V:L~ 03/31/89 ( TD: 3403'( SUPV:ZR 04/03/89 ( TD: 6742'( SUPV:ZR 2) 878) Th..be~i. e?.,~t , $1gn/~.~ ~ For form prepa~ip~n and distribuM('mv. see Pmcedurea~.M'anual, Section Drilling, Pages 86 and 87. IHour 14:00 Stele ~ 31-11 A~C05~'. 8533 Prior status if · W.O. ~.,vz,~ L<~.u uaTo WEL~ 16"~ 115' ~: 0.0 ~VING RIG FROM 31-17 ~ 31-11. RIG NOT ACC~P~D AT ~PORT DAILY: $0 C~: $0 Z~: $0 EFC: $1,330,000 D~ S~ACE HO~ 16"~ 115' ~: 9.4 VIS: 68 FINISH ~VZNG ~IG, NU DZ~R~R BY8~, SLIP ~D CUT DRIVING LI~, ~ UP B~ ~ST DZ~R~ 8YS~. SPUD ~ ~ 1400 ~S, 3/28/89. D~I~ S~ACE HO~ TO 1878'. DAILY:II01,295 C~: $101,295 ~TD:~Z01,295 EFC:$1,330,000 3) P~H ~ R~ 9-5/8" ~ING 9-5/8'e 3384' ~: 9.3 VIS: 53 ~25) DRZ~ FROM 1878 ~ 1957. LOST 700 PSI. P~H ~X FOR W~HOOT. C/O BIT ~I ~ZP ~ HO~. ~TS PLO~ED. ~H C~ O~F BIT. EZH, ~/~ 60' ?OM ~. DRZ~ ~ C~ZNG. DAZLY:$73,589 C~:~174,884 ~TD:~174,884 gFC:$I, 330,000 ~) D~ OUT ~ 9-5/8'e 3384' ~: 0.0 VIS: 0) LD B~ ~D ~O ~ R~ 9-5/8" CSG ~/ ~C AT 3302' ~ F8 3384'. ~ ~SING W/ 544 SX ~ III ~D 330 SX C~S ;~{(. ~~ ~ 3000 ~SZ. P~ ~ ~ RZH TO ~C AT 3302'. D~ OUT DAZ~Y:'~49,432 c~: $234,316 ~TD:~224,316 EFC:81,330,000 i DRIVING 9-5/8"e 3384' ~: 9.2 VIS: 35 ~2) DRILL DOT F~AT E~IP ~ C~NT. ~ST SHOE TO 12.5 PPG ~ZT~ NO ~ OFF. ~. DRZ~ F~ 3413 TO 4834. P~H ~OX W~HOUT. FO~D S~ IN DRI~ PIPE. TZH ~ DRZ~ ~ 5171. P~H FOR ~H OUT IN DRI~ PIPE. FO~ S~. RIH ~D DRI~ TO 5235. DAILY: $~63,708 ~: $388,024 ETD: $388,024 RFC: $1,330,000 CIRC ~ ~IGHT ~. 9-5/8"J 3384' ~:10.6 VIS: .4) DRI~ ~ 5235 ~ 6228. ~ 8~y ~ CBU. P~H ~ 9-5/8" SHOE. CBU. ~ST S~B ~ 12.5 PPO B~ W/ NO ~ OFF. L/D ~INB ~D' ~. RZH N/ BIT J3 ~H ~D ~ FROM 6136 TO 6228. DRI~ ~ 6289. C~ ~ ~IQHT ~ ~ 11.8 DAILY: $55,663 C~: $443,687 BTD:$443,687 EFCi$1,330,000 P~H ~ ~ 9-5/8"~ 3384' ~:1~.8 VIS: 42 3) CIRC ~ INC~R ~ ~IGHT'.~ ll. SPPQ. DRILL FROM 6289 TO 6415. CBU. DRI~ ~ 6742. CBU SHORT ~IP CB~. DROP SINGLE SHOT. SPOT PI~ ~ P~H ~ ~. narT'V' $0!-~ C~; ~:::, 37'5 ~;~a5, ~ s= ~FC:~I, 330,000 IWell no, AR3B-459-1-D INumber all prepared for each well. lei they are dally well hlltory forms rmnlecutlvely iPege no. ARCO Oil and Gas Company Dally Well History--Interim Instructions: This form is used during drilling or workover operations. If testing coring, or perforating, show formation name in delcrlblng work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Seotlon will be repolled on "lnlll'im" ih..ti until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oll string until completion. District ICounty or Parish ]Stat. AK ~1~CO ~L~I~[,~ INC. NORTH SLOPE Fie,d iL..or U]~o 31,1:], KUPARUK RIVER Date and depth as of 8:00 a.m. 04/04/89 ( TD: 6772'( SUPV:ZR Complete record fEiroe~lda~. ~hile drilling or workover in progress 8) 30) RUN 7" CASING 9-5/8"% 3384' MW:11.8 VIS: 44 POOH. RET SURVEY. R/U SCHLUMBERGER AND LOG HOLE. M/O BIT AND BHA. CUT AND SLIP DRILL LINE. RIH. DRILL FROM 6742-6772'. CCM. POOH L/D DP+BHA. R/U AND RUN 7" CASING. (LOG W/ DIL/SFL/GR/SP/FDC/CNL/CAL) DAILY=S96,719 CUM:$622,094 ETD=S622,094 EFC:$1,330,000 no. The above is correct · Signe~.~ ~ For form preparatj6~nd distributi~3~~ see Procedures IrWin]ual Section 10, Drilling. Pages 86 ~'nd 87 AR3B-459-2-B Number all daily well history form, consecutively as they are prepared for each well. Page no. a ARCO Oil and Gas Company Dally Wall History-Final Report Instructions: Prepare and submit the "Flail Rlpo~t" on the first Wednesday after allowable has been assigned or well iS Plugged, Abandoned, or 8old. "Final Report" should be submitted alee-when operations are suspended for an.indefinite or appreciable length of time. On workover$ when an official test la not required upon completion, report completion and representative test data in blocks provided. The "FIItal Report" form may be uled for reporting the entire operation if space is available. I A0countlng Dost oenter code District ~,g~.CO ~T~lt.~ TNC, State I county or P~t~iII:tTH SLOPE I Well no. Field KUPARr~K RIVER Lease or Un~= 25631 3Z-ll Auth. or W.O. no~4117 lTItle D~Z~ Operator ~CO Spudded or Date and depth as of 8:00 a.m. ~I: 50-029-21932 04/05/89 ( TD: 6772 PB: 6682 SUPV:ZR IA.R*C°.W*~5.8533 Date 03/28/89 Complete recol~dil~(~chld~Y reported 9) Old TD New TD Released rig Date Iotel number of wello (aotivo or ina~five) on this, oat center prior to plugging end I bandonmont of this well IPrior status our 14: 00 I If a w.o. Classifications (oil, gas, etc.) Producing method Potential test data RIG RELEASED 7"0 6760' MW:11.8 N&Br RUN AND CEMENT 7" CASING WITH 250 SX CLASS "G" CEMENT. DISPLACE WITH 11.SPPG BRINE. BDI~P PLUG WITH 3500 PSI. CIP 1445 HR. P/U STACK AND SET SLIPS AND N/U TUBING H~AD. TEST TO 3000 PSI. RELEASED RIG AT 1945 HR, 4/4/89. DAILY:S199,117 COM:$821,211 ETD:S621,211 EFC:$1,330,000 IPB Depth Kind of rig IType completion (single, dual, eta.) Official reservoir name(s) Well no. Date Reservoir Producing Interval 011 or galToot time ProdUction 011 on test Gas per day , Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct sFeO~ f;~n~d~erPe~r~la~t~ualn,%edic~roinbUl,o.C~ Drilling, Pages 86 and 87. AR3B-459-3-C INumber iii dally well hlitop/fermi oon~lcutlvely as they are prepared for each well. iPage no. Dlvllien et Atlontl~ioMlddComlMny · - ~MO:RANDUM State :of Alaska '~SF_.~A OIL AND ~ CONSERVATION CONMISSION .. TO: Lo~J[~, C, S~.~t~'(c~'~ DATE: Apr~. 13, 1~9 Co~issioner / FILE NO: D. BDF. 049 TELEPHONE NO: THRU: Michael T. Hinder ~, -~,~, SUBJECT.' BOP Test AAI KRU 31-11 Permit. No. 89-35 Kuparuk Rv F~e ld FROM: Petrol~ inspecE~or ~rs.day, ~rch,30, 1989~. T~ cesc began ac 10~00 pm and was ~ie~'~d-a.t:':~ii:45-'-:;pm? ::~:'"is the a~ta~ed ~P test repor~ shes chere ~re no fail~es ~-~ In summary, i wicnessed the BOP test on Arco's 31-11. Attacha~nt 02-001A (Rev. 8/85) -y 5/84 ©. STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COHHISSION B,o.p.g, Inspection Report ~ud Systems , Visual luffio Pump incr. clos. pres. 200 psis -- ,mi~ sec. ~ip ~an~ .... ~ Full Chars, ~ressur, A~ained~~min~ Flo~ Honitor :. -~ , , : Concrolsl Has~er ~~,. , ,, , Cas Detectors ~ ' R~mote~~Blinds s~i~ch cover Kelly and FI:0~r Safe~y Valves . ' }OPE Stack ~est Pr,~ssur~ ~" Upper Kelly. // _Tes~ Pressure Annular Preventer ~~ ' Lo.er Kelly /, Test Pressura ..... ~ .... Pipe Rams .~~ Ball Type "] Test Pressure Blind Rams ~~- Inside BO[,. j Test Pressure ~ Kill Line Valves .......... ~ No. flanses ~ ~ .... Check Valve ' ~/~ _ Adjustable Choke~ /,, ' ', .. Remarks ~ ' a,,,, ,, ~ , , ,1 11 , , 11 , i i i ~1 I I II II Iiiii ~ I I II I I I I I Distribution ortg, - hO&GCC ce -.Operator cc - Supervisor March 21, 1989 (907) 276 7542 l~.z.M.B. Wtnfree P. O. ~ I00~0 ~~r~ge, a~a,~ 99510-0360 S~. ~. 117'~, i8'F~, Sec. 3t, TIIS, ME, ~. Brash Loc. 970'~, i255'F , See, 6, Ti , a9E, ~clooed lo ~b tpp~o~d applt~a~ ~or ~~ ~o dr~ll ~he ~e re~er~eed The pe~t to 4x~.i. ll does no~ ~~ you from obtalntn8 additional pe~.s required.by !~ ~r~ o~r gove~~al agencies, ~d doe~.~ auC~t~e eonduc~tn~ ~tlli~ operantes ~til all ocher required pe~~i~. ~e~tion-s ~ a~e M~, To aid us in-s¢'~duting f ~teld'work, please notify this o££ice 24 hours prior ~o eomnanCing i~allaC~on o~ ~he bl~u~ prevision ~uip~c so ~ a repres~a~i~ o~ t~ C~oet~ my be presen~ co v~ess testing o~ ~ .equ~nC ~fore che surface casing ah~ ~0 drilled, ~re a...~$yercer syoc~ ~0 required, please diS? ~i? '~h~S o~ee'-2~ ~urs prior co co~e~g equt~nc ~.~ta~at~on so t~t tb C~,asion'-my ~cneoo teotins before drill.s bei~ ~a $~e of ~h e~d~or . t~Aly you~rs ,f Aias~ Oil and ~as ~servacion Couantoston Enclosure cos- Depar~nt o£ Fish & ~, tLsbi~a~ Section w/o encl, ~psr~a~ o£ Envir~~al .~nservattonw/o enel, PERMIT TO DRILL 20 AAC 25.005 - la. Type of work Drill [] Redrill []1 lb. Type of well. Exploratory [] Stratigraphic Test [] Development Oil ~' Re-Entry [] Deepen©1 Service [] Developement Gas [] Single Zone I~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Pad 40' KB 76 feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River 0il Poe P.O. Box 100360, Anchorage, AK 99510-0360 ADL 25631 ALK 2564 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see20 AAC 25.025) Kuparuk River Unit Statewide 147'FSL, 48'FEL, 5ec.36, T13N, R8E, UM At top of productive interval 8. Well nurpber Number 550'FNL, 1000'FEL, Sec. 6, T12N, RgE, UM 3']'-11 No. U-630610 At total depth 9. Approximate spud date Amount 970'FNL, 1255'FEL, Sec. 6, T12N, RgE, UM 03/28/89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MO and TVD) property line Well 31-12 7566 'MD 9 7 0 ' feet ~' 's.u r f a c e 2 4 ' feet 2 4 3 7 7 31 5 ' T V D feet 16. To be completed for deviated wells 2 2.6 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 3800~eet Maximum hole angle 0 Maximum surface 2010 pslg At total depth (TVD) 6136 3000ps~g 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 37' 37' 117 117' ±200 cf 12-1/4' 9-5/8 36.0# J-55 BT~C,;~ 3422 37' 37' 3396 3396' 735 $.x C$ II I 'IF- ERI ~' 330 sx Class G 8-1/2' 7" 26.0# J-55 '-BTC 7016 36' 36' 6699 6515' 200 sx Class G ($1~T OFF B(TTON) JF-ERt 19.To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length,...~.~ Size · Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Surface Intermediate MAR 1 5 1989 Production Liner AlaS~'~ 0il & Gas Cons. Commission Anchorage Perforation depth: measured true vertical 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program ~ Time vs depth plot ri'Refraction analysis [] Seabed report [] 20 AAC 25.050 requirements ~ . 21. I hereb~certify that the foregoing is true and correct to the best of my knowledge Signed'~'//')/'/'~ ~..~J~ Title Area Drilling Engineer Date~/~/',~ · I r~ /,] Commission Use Onl~/ (JTZ) PD3/069 Permit Number __ I APl number _ I Approval date I See cover letter 3'?-- 3' 5 I 50- 0 z? - z/9 I 0 3 / 21/8 9 [ for other requirements Conditions of approval Samples require, d [] Yes _~ No Mud log required L--J Yes ~l~No Hydrogen sulfide measures [] Yes ~No D, irectional survey required ~i~Yes [] No Required working pj;e~s, ure fg4,'/BOP~2M; ]XI 3M.;, [] 5M; [] 10M; [] 15M Other: ' ' f /~")///'"/~'~/? ~ by order of ~'/ f__ Approved by L t .../, k ~/~~ Commissioner the commission Date '~'/~,1~/~ir Form 10-401 Rev. - ~/ Subrn~ :ate GENERAL DRiLLiNG PROCEDURE KUPA~ RIVER-FIELD DEVELOPHENT ggLLS 1. HIRU. 2. Install F~¢ d~verter 3. Dr211 12¥' hole co 9-5/8" surface cas~n$ point accord2n$ to d~rect~onal plan. &. Run and cement 9-5/8" casXn$. 5. Install and cent blow out preventer. Test cas~n$ to 2000 Psis. 6. Dr~ll out cement and 10' ney hole. Parlors leakoff Cast. 7. Dr~ll 8¥' hole to losg~ns point accord£ng co dLreccioual plan. 8. Run open hole logs. 9. Continue dr~ll~n$ 8¥' hole co provide 100' between plug back total depth and bottom of Kuparuk sands. 10. ~un and cement 7" casing. Pressure oeec Co 3~00 11. Do~aqueeze Arctic Pack and cmenc Ln 7".x 9-5/8" ~ulua. 12. Nipple do~ blow ouc preventer ~d ~ecal~ ce~ora~ ~a tree. 13. Secure veil and release r~g. 1~. ~un ~aed hole 15. ~ve Lnvo~ver rLg. Nipple up bl~ ouc preventer. 16. PLck up 7" casing scraper and cub~n~, cr~p ~ hole co plu~ back cecal depth. C~rculace hole v2ch c~ean br~ne and trip ouc of hole cub~back. 17. Perforate and ~n conpleciou asee~ly, eec and oeec 18. Nipple d~ blow ouc preventer and install ~s 19. C~use ~er co d~esel. 20. ~l~vell co ca~. Shuc in. 21. Secure veil and release 22. Yraccure 23. Perforate resinOuS zones. MUO CLIANIII RECEIVED MAR 1 5 1989 Oit& Gas Cons. Commission Anchorage IdUO CLIANIR TYPICAL MUD SYSTEM $CHEIdATI ARCO ALASK~ Inc. Pad ~I, ~e[?No' 11 Revised Pnopo~ Kupenuk Fleid, Noeth Slope, Alaska .! 000 .2000.. ;4OO0. SO00. 6000 _ ?000 _ 8000 _ ._ RKBELEVATION~ 76'- B/ PERMAFROST TVD-1651 T/ UNOU SNDS TVD-2216 T/ ~ SAK SNDS TVD'2796 K-12 TVD=3196 9 5/8" CSg PT TVD-$396 K-lO TVD=3471 KOP TVD-3800 TMD-3800 DEP-O 2t EOC TVD-4535 TMD-4555 DEP-147 K-1 0 TVD-4$?6 TMD-4599 DEP- 1 64 I% C L. !: ] V l::: L) ~ AVERAGE ANGLE MAR 1 5 1989 \ 22 DE G 38 M I N Alaska Oil & Gas Cons. Commission Anchorage ~ TARGET TVD'6136 TM0"6289 DEe-B1 ~,~ T/ ZONE A TVD-6220 TMD-63.80 DEP ~ e/ KUP SNDS TVO-6:~O THO 6499 OEP 896 Z" csg PT TVD=6515 TMD"SS99 DEP'97;3 TD TVD--?315 T"D'?566 DEe-1306 I I 1000 2000 VERTICAL SECTION TARGET TYD,,8135 THD,,,,6~8G DER-81 $ SOUTH HOR I ZrON T AL PROJECT ! ON SCSLE 1 IN. y 1000 FEET 1000 :3: 1 000 _ 2000 _ iRCOALASKA lno. ed :~I. I~el~ No~ 11 uperUk Fl~ld., North~ i WEST-EAST ZOO0 1000 Rev 1 8ed Propose I SI ope. AIqeke 1000 S 31 815' DEO 1 2 r'lI N W (TO TARGET) 9URFACE LOOAT [ ON ~ 147' FSL. 40' FEL SEC. 36. T13H. RSE TARGET LOCATION t $50' FNL. 1000' FEL GEO. 6. TI2N. R~E TD LOCAT l ON ' G?O' FNL. 1255' FEL SEC. 6. T12N. RGE 35O 3O0 25O 200 150 100 5O 5O 250 200 1 50 1 O0 50 0 I I I ~1/~ I I : ~ ~ ~ ~40 50 100 150 200 250 I / I ~ / I I 115 / //~ ~1 ;H I 200 I 250 350 300 250 .200 - 150 .100 so _0 _ 50 KUPARUK RIVER UNIT' 20" DIVERTER SCHEMATIC 6 DESCRIPTION 4 3 I I MAINTENANCE & OPERATION ,. 1. UPON INITIAL INSTALLATION, CLO~E PREVENTER ANO VERIFY THAT VALVE OPEN~, PROPEIRLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR TH;K:RX3H OlVERTER LINES EVERY 12 HOUI~. 3. CLOSE ANNULAR P~ IN THE EVENT THAT AN ~ 11 ~ INFLUX OF WlI~ IILUII~ OR ~ I~ OET'E~TED. ~A~ 1 5 1989 Gas Cons. Commission ~chorage DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCEg iii i 6 5 4 2 RECEIVED MAR 1 5 1989 Alaska Oil & Gas Cons. CommlssJoa Anchorage -. Well 31-11 DRILLING FLUID PROGRAM Density Spud to 9-5/8" Surface Casing 9.0-9.8 Drill out to Weight Up 8.7-9.2 Weight Up to TD 9.9-10.2 PV 15-30 5-15 11-16 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-50 Initial Gel 5-15 2-4 3-5 I0 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.0-10.5 % Solids 10± 4-7 12-15 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 and a gas gradient df .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 61' of departure, there are no well bores within 200' of. this proposed well. JTZ/14 ih In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. R EC E IV E D MAR 1 5 ]989 Naska 0il & Gas Cons. CommJsm(m Anchorage III _z.. - MAR 1 5 1989 TlaN ~ THI~ ~TES _ h C~~TES A~ A.S.R, ZONE 4. 2. ~710N LINE DISTANCES ARE TRUE. ~ ~ZONTAL ~SlTIONS ~SED ON ~-PAD CONTROL ~R L.H.D. · ASSOC. 4. ~ICAL POS~IONS BASED ~ TBM 5[ - 4 PER LHD ~ AS~. ~ ~ ELEVATES INTER~A~D FROM S/C DWG. CED- RlXX - ~O50 rev.~ I m m LOCATED IN PROTECTED SEC.~I,TI~N, RgE, U. MER. LOCATED IN PR~~D~C.~Ti3~, ReE, U. MER, [- Y= 6,007,285.50 LAT. 70°25'52.0592'' 'g' Y= 6,007,~2~.00 ~T. 70'25'50.44~ X= 508,056.44 L0,G. [4g°56'03.sg6" X= 507,867.g[ L~.[49'56'09.~34' [Tg' F~L, 345' FSL 0G. 33.6', PAD 39.9' [80' FSL, [0' FEL ~. 35.0', PAD 39.9' 2- Y= 6,007,26g.06 LAT. 70°25'S1.SgTB" [0~ Y= 6,007,~04.59 ~T. 70~25'50.282[ X= 508,037.66 LONG. 14g°56'04.148" X= 507,849.~1 LONG. ~49~56'09.686I ~60' F~L, 3~' FSL 0G. 33.7', PAD 3g.g' ~64' FSL, 29' FEL 0G. 35.0, PAD 40.0 3- Y= 6,007,252.70 LAT. 70°25'5[.7370" [~' Y= 6,007,088.~6 LAT. 70°25'50.~206'' X= 508,018.80 LONG. [4g°56'04.702" X= 507,830.23 L~G. ~49~56'~0.240" 14[' F~L, 312' FSL 0G. 33.7', PAD 40.0' ~47' FSL, 48' FEL 0G. 35.0, PAD 40.~ 4- Y= 6,007,236.23 LAT, 70°25'5~.5752" ~2- Y= 6,007,07[.76 LAT. 70=25'4g.g595" X= 507,999.99 LONG, 14g°56'05.~55 X= 507,8[1.32 LONG. ~4g=56'~0.796" ~22' F~L, ~95' FSL 0G. 33.8', PAD 40.0' [3~' FSL, 66' FEL 0G. 35.0, PAD 40.~ 5- Y= 6,007,21g.81 LAT. 70°25'5~.413g'' 13- Y= 6,007,055.32 LAT. 70~25'4g. Tg81'' X= 507,g81.16 LONG. 14g~56'05.808'' X= 507,792.36 LON~. 14g~56'll.353'' 104' F~L, 27g' FSL 0G. 33.g', PAD 40.0' llS' FSL, 85' F[L 0~. 35.0', PAD 40.1' 6- Y= 6,007,203.20 LAT. 70°25'51.2507'' 14- Y: 6,007,038.82 LAT. ?0°25'4g.635g" X= 507,g62.12 LON~. 14g°56'06.367" X= 507,773.63 LON~. 14g°56'[l.g03" ~5' F~L, 262' F~L 0G. 34.0', PAD 3g.g' 9~' FSL, 104' FEL 0G. 35.0, PAD 40.1' 7- Y= 6,007,186.78 LAT. 70°25'51.0895" 15- Y= 6,007,022.42 LAT. 70o25'4g.474g'' X= 507,g43.27 LONG. 14g°56'06.g20" X= 507,754.83 LON~. 14g°56'12.455" 66' F~L, 246' FSL ~, 34.2', PAD 3g.~" 82' FSL, [23' FEL 0G, 35.0', PAD 40.2' 8- Y= 6,007,170.37 ~T. 70°25'50.9282" l~ Y= 6,007,006.02 LAT. 70°25'4g.3137'' X=. 507,924.40 L~G. 14g°56'07.475'' X= 507,736.04 LONG. 149056'[3.007" 47' F~L, 230' FSL 0G. 34.5', PAD 3g.~' ~5' FSL, 142' FEL 0G. 35.0', PAD 40,2' ' MADE aY ME OR UN~R MY SUPERVISION, AND ~ ' THAT ALL DIMENSIONS AND OTHER O~TAIES , , , ' I1~ C,RvCyED FOR' Jk ARCO Aloska, Inc. ~ :2::~""' DRILL SITE 5Z CONDUCTOR , , , ~J~rctic 8ou/evard, Suite 20 ~, Anchorage, A/aska 99503 IIs~E AS' llUO. m. , I I STATE OF ALASKA AJLASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 · ;' CHORA6E Re: THE APPLICATION OF ARCO ) ALASKA, INC. for an order ) granting an exception to ) Rule 4(c) of Conservation. ) Order No. 173 for wells to ) be drilled from 15 drill ) pads in the Kuparuk River ) Field. ) Conservacion Order No. 209 Kuparuk River Field Kuparuk River Oil Pool May 23, 1985 IT APPEARING THAT: I · ARCO Alaska, Inc., by letter dated April 30, 1985, requested the Alaska Oil and Gas Conservation Commis- sion to issue an order granting an exception to Rule 4(c) of Conservation Order No. 173 to allow surface casing to be set as deep as 4150 feet true vertical depth in development wells to be drilled from drilling pads iR, 2A, 2H, 2T, 3A, 3B, 3C, 3F,..:3X, 3J, 3K, 3M, 3N, 30 and 3Q. · Notice of public hearing was published in the Anchorage Times on May ?, 1985. · FIND INGs: There were no protests to the request set forth in the notice of public hearing. I · The Ugnu sands and the West Sak sands are hydrocarbon- bearing and potential reservoirs in some areas of the Kuparuk River Field· · The West Sak sands are or could be hydrocarbon-bearing in the area of drilling pads IR, 2A, 2E, 2T, 3A, 3B, 3¢, 3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q. · The oil in the West Sak and Ugnu sands has a low solution GOR and has no known gas-oil contact· RECEIVED MAR 1 5 ]989 Alaska Oil & Gas Con~. Commissio~ Anchorage Conservation Ot r No. 209 Page 3 May 23, 1985 NOW, THEREFORE, .IT IS ORDERED: Development wells to be drilled to the Kuparuk ~iver Oil Pool on drilling pads IR, 2A, 2H, 2T, 3A, 3B, 3C, 3F, 3I, 3J, 3K, 3M, 3N, 30 and 3Q may be drilled to a maximum ~150 feet true vertical depth before surface casing is set provided that'conductor casing is set and cemented in accord with Conservation Order No. 173, a diverter system is used in accord with 20 AAC 25.035(b)(1) and a drilling fluid of at least 9.0 pounds per gallon is used in the drilling. DONE at Anchorage, Alaska and dated May 23, 1985 _ C.V. Chatterton; Ohafrman .... Alaska Oil and Gas Conservation Commission I er ', Alaska Oil and Gas Conservation Commission , - nxe C. smi~h,~mmissioner Alaska Oil and Gas Conservation Commission RECEIVE , MAR ! Alaska Oil & Sas Cons. Anchorage ITEM APPROVE DATE ( 1 )'",Fe~' /~.~ ' ~_~/ (2) Loc (2 thru CHECK LIST FOR NEW WELL PERMITS (8) (9 thru 13) ' -- (10 and 13) (4) Casg (14 thru 22) (23 thru 28) ('29 thru 31) Company _ ~-~_~ .. 1 Is the permit fee attached" ' · · eeee.e)~.eee.·eeeeeeeeeeeeeeeeeeeee .eel. 2. Is well to be located in a defined pool ............................. 3. Is we~~ located proper distance from property line ....... ~,.. ..... 5. Is su~iCient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... · 10. 11. 12. 13. 14. 15. rev: 01/30/89 6.011 Lease & Well No. YES NO 16. 17. 18. 19. 20. 21. 22. Does operator have a bond in force .................................. ,~ Is a conservation order needed ~-" e·ee·eeeeeeeeeeeee··eeeeeeeeeeeeeeeeee Is administrative approval needed ................................... ~: Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source o~ drinking water ..................... 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 ....................................... 23. 24. Is the drilling fluid program schematic and list of equipment adequate~ 25. Are necessary diagrams and descriptions of diverter and BOPE attached· 26. Does BOPE have sufficient pressure rating - Test to ~e) psig .. 27. Does the choke manifold comply w/API RP-53 (May 84) .................. 28. Is the presence of H2S gas probable .................................. For,.exploratory and'"Stratigraphic wells· . ;: , ~. . . . .. ~ · ~29.'~A~r~' da~a pre~ented on ........ ~poten~ial overpressure zones? ......... 30. Are seismic analysis data presented on shallow gas zones ............ 31. If an offshore loc., are survey results of seabed conditions presented 32. Additional requirements ............................................. INITIAL GEo. UNIT' ON!OFF POOL CLASS STATUS AREA NO. SHORE , Additional Remarks: 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 roadability 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. ALASKA COMPUTING CENTER ........ SCHLUMBERGER -- ..... COMPANY NAME :' ARCO ALASKA~ INC. WELL NAME : 3 I-1! FIELD NAME : KUPARUK STATE : ALASKA BOROUGH : NORTH SLOPE API NUMBER : 50-029-21932-00 REFERENCE NO : 73269 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 8-APR-1989 16:21 0~** REEL HEADER ~**~ SERVICE NAME : EDIT DATE : 89/04! 8 ORIGIN : FLIC REEL NAME : 73269 CONTINUATION ~ : PREVIOUS REEL : COMMENT = ARCO~ KUPARUK~ 3 [-11~ API e50-029-21932 · ~ TAPE HEADER SERVICE NAME : EDIT DATE : 89/04/ 8 ORIGIN : FLIC TAPE NAME : 73269 CONTINUATION · : 1 PREVIOUS TAPE COMMENT : ARCO~ KUPA~UK~ 3 I-ZZ~ API ~50-029-21932 *~ FILE HEADER ~ FILE NAME : EDIT .00! SERVICE : FLIC VERSION : O01A02 DATE : 89/04/ 8 MAX AEC SIZE : [096 FILE T~PE : LO LAST FILE : SCHLUMBERGER WELL SERVICES COMPANY NAME: ARCO ALASKA~ INC. WELL: 3 I-It FIELD: KUPARUK BOROUGH: NORTH SLOPE STATE: ALASKA API NUMBER: 50-ozg-z1932-O0 LOCATION: 1~7' FSL ~ 48' FEL SECTION: 26 TOWNSHIP: RANGE: 8E PERMANENT DATUM: MSL ELEVATION: 0 [S TAPE VERIFICATION LISTING ~HLUMBERGER ALASKA COMPUTING CENTER 8-APR-1989 16:Zl PAGE: LOG MEASUREO FROM RKB 76. ABOVE PERMANENT DATUM ELEVATIONS KB: 76. DF: 75° GL: 35. DATE LOGGED: TD DRILLER: TD LOGGER: 03-APR-89 6762. 6726. CASING: 9 5/8" @ DRILLER OEPTH DF 3384 AND LOGGER DEPTH OF 3383 BIT SIZE: $ 1/2" ~ 6742. TYPE FLUID IN HOLE: LSNO POLYMER DENSITY: 11.8 LB/G PH: 9.5 'VISCOSITY: 42° S FLUID LOSS: 4.8 C3 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2.72 @ 70. 1'78 3 68. 3ol @ 70. TIME CIRCULATION ENDED: 03:00 03-APR TIME LOGGER ON BOTTOM: 11:20 03-APR MAXIMUM TEMP RECORDED: 141 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUOHOE BAY 'TINKHAM/WARNER FLETCHER/CORBELL/RUNJE TOOL NUMBERS: DIS EC 2140 PGS HB 1026 SGC JC 2626 NLM BC 1329 O]:C DA 2191 CNC A 1449 I~M BO 1347 FIELD REMARKS: I 1/2" STANDOFFS AND ACORN BTM. NOSE USED ON OIL. MATRIX DENSITY --' 2°65 G/C3 ~ FLUID OENSITY = 1o00 G/C3 NEUTRON MATRIX -- SAND ~ HOLE CORRECTION = CALIPER SP' SHIFT ON MAIN PASS AT 5296~'., DATE JO8 STARTEO: 08-APR-89 JOB REFERENCE NO: 73269 LOP/RNA: Jo KOHRING THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS SCHLUMBERGER LOGS INCLUDED WITH THIS FILE' CEDIT.O01): (SEE FILE EDIT.OO2 FOR 1.2= SAMPLED FOC/CNL DATA) IS TAPE VERIFICATION LISTING CHLUMBERSER ALASKA COMPUTING CENTER 8-APR-1989 16:21 DUAL INOUCTION SPHERICALLY FOCUSED67 LOG C.DI:L) FIRST TO LAST READING: ZO' TO 3383' FORMATION DENSITY COMPENSATEO LOG C.FDC) FIRST TO LAST READING: 6694~ TO 6145' COMPENSATEO NEUTRON LOG C,,,CNL) FIRST TO LAST READING: 6678~ TO 6Z&Se GAMMA RAY ZN CASING C.CHL) FIRST TO LAST REAOZNG: 3:418~ TO 996~ PAGE: 3 TABLE TTPE : CONS TUNI VALU DEFI CN ARCO ALASKAt INC., COMPANY NAME FN KUPARUK FIELD NAME IWN 3 1-11 WELL NAME NATI USA NATION STAT ALASKA STATE OR PROVINCE COUN NORTH SLOPE COUNTY FL 147' FSL ~ 48t FEL ,FIELD LOCATION SECT 26 SECTION T ONN 1 3N T OWN SHIP RANG 8E RANGE ENG! TZNKHAM/WARNER ENGINEER~S NAIqE SON 548421 SERVICE ORDER NUMBER APIN 50-029-Z193Z~'00 AP! SERIAL NUPqBER TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL NAME TENS ILO ILM SFLU SP GR TENS DPH! RHOB DRHO FFDC NFDC CALI GR TENS TENSION IL-DEEP RESISTIVITY IL-MEDIUM RESISTIVITY SFL UNAVERAGED SPONTANEOUS POTENTIAL GAMMA RAY TENSION DENSITY POROSITY BULK DENSITY DELTA RHO FAR FDC COUNT RATE NEAR FDC COUNT RATE CALIPER GAIqMA RAY 'TENSION TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 8-APR-1989 1'6::71 PAGE: OEFI NPHI NEUTRON POROSITY TNPH TNRA NPOR R CNT RCFT CNTC CFTC CALI GR TENS GR THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTED NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS CORRECTED NEAR THERMAL COUNTS CORRECTED FAR THERMAL COUNTS CALIPER GAMMA RAY TENSION GAMMA RAY DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ~ TYPE REPR CODE VALUE I 66 0 2 66 0 3 7:3 11 Z 4 66 1 5 66 6 7'3 7 65 8 68 0.5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 0 66 0 ,~ SET TYPE - CHAN ~ NAME SERV UNIT SERVICE AP! API AP! API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM COOE CHEX) DEPT FT 548421 O0 TENS OIL LB 548421 O0 ILO OIL OHMM 548421 O0 ~LM O~L OHMM 54842! O0 SFLU OIL OHMM 54~42! O0 SP OIL MV 548421 O0 GR OIL GAPI 548421 .00 000 O0 0 I I I 4 68 0000000000 000 O0 0 I I ! 4 68 0000000000 000 O0 0 I I I 4 68 0000000000 000 O0 0 1 I I 4 68 O0000OO000 000 O0 0 I I I 4 68 0000000000 OOO O0 0 I 1 1 4 68 0000000000 000 O0 0 1 I 1 4 68 0000000000 TS TAPE VERIPICATION LISTING CHLUIqBERGER ALASKA COMPUTING CENTER 8-APR-1989 16:21 PAGE: NAME SERV UNIT SERVICE API API API IO ORDER # LOG TYPE CLASS TENS FDC LB 548421 O0 000 O0 DPHI FDC PU 548421 O0 000 O0 RHDB FDC G/C3 548421 O0 000 O0 DRHO FDC G/C3 548421 O0 000 O0 FFDC FDC CPS 5484Z1 O0 000 O0 NFDC FDC CPS 548421 O0 000 O0 CALI FDC ZN 548421 O0 000 O0 GR FDC GAPI 54842! O0 000 O0 TENS CNL LB 548421 O0 000 O0 NPHI CNL PU 548421 O0 000 O0 TNPH CNL PU 548421 O0 000 OO TNRA CNL 548421 O0 000 O0 NPOR CNL PU 548421 O0 OOO O0 RCNT CNL CPS 54842! O0 000 O0 RCFT CNL CPS 548421 O0 000 O0 CNTC CNL CPS 548421 O0 ' 000 O0 CFTC CNL CPS 548421 O0 000 O0 CALI CNL IN 548421 O0 000 O0 GR CNL GAPI 548421 O0 000 O0 TENS CSG LB 548421 O0 000 O0 GR CSG GAPI 548421 O0 000 O0 API FILE NUMB NUMB MOD NUMB SAMP ELEM 0 1 1 1 0 1 1 I 0 1 1 1 0 I 1 1 0 1 1 1 0 1 1 1 0 1 1 1 0 I I 1 0 1 1 1 0 1 1. 1 0 1 1 1 0 I I 1 0 I 1 1 0 I I 1 0 I I 1 0 I 1 1 0 I I 1 0 I 1 1 0 I I 1 0 1 1 1 0 1 I 1 SIZE REP COO PROCESS CHEX) 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 DATA DEPT. 6738.500 TENS.OIL SFLU.DIL 3.978 SP.DIL DPHI.FDC 9.232 RHOB.FOC NFDC.FOC 592.000 CALI.FOC NPHI.CNL 34. 874 TNPH.CNL RCNT.CNL 2419. 864 RCFT,CNL CALI.CNL 8.727 GR.CNL DEPT. 6700.000 TENS.OIL SFLU.D[L 4.035 SP.OIL DPHI.FDC 9.144 RHOB.FOC NFDC. FDC 596°000 CALI.FDC NPHI.CNL 34.862 TNPH.CNL RCNT.CNL 2419.864 RCFT.CNL CALIoCNL 8.73& GR.CNL DEPT. 6600.000 TENS.OIL SFLU.DIL 3o927 SP.OIL DPHI.FOC 10.393 RHOB.FDC NFDC.FDC 621.500 CALI.FOC NPHX.CNL 35. 598 TNPH.CNL RCNT.CNL ZO64.TZX RCFT.CNL CALI.CNL 8.766 GR.CNL 3204.000 -43.156 2.498 8.727 35.002 753.110 87.188 4808°000 -46.125 2.499 8.734 34°997 753.110 87.188 4700.000 -46.563 2.479 8.766 35.081 61Z.324 87.188 ILO.OIL GR.DIL DRHO.FOC GR.FDC TNRA.CNL CNTC.CNL TENS.CSG ILO.OIL GR.DIL DRHO.FDC ,GRoFOC TMRA.CNL CNTC.CNL TENS.CSG ILD.DIL GR.OIL ORHO.FOC GR.FDC TNRA.CNL CNTC.CNL TENS.CSG 2.144 87.188 0.039 87.188 3.064 2493.154 -99 9. 250 Z.913 87.188 0.043 87.188 3.064 2493.154 -999.2 50 2.464 87.188 0.056 87.188 3.106 2072.694 -999.Z50 ILM.DIL TENS.FOC FFDC.FDC TENS .CNL NPOR.CNL CFTC,CNL GR.CSG ILM. OIL TENS.FDC FFDC.FOC TENS.CNL NPORoCNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FOC TENS.CNL NPORoCNL CFTC.CNL GR.CSG Zo900 3204.000 448.750 3204.000 35°002 824.938 -999.250 3°064 4808°000 451o250 4808°000 34.997 8Z&.938 -999.250 2.573 4700.000 490.250 4700,000 34.003 684.268 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERSER ALASKA COMPUTING CENTER DEPT. 6500. 000 TENS .OIL SFLU. D/~:1.. 13. 939 SP. OIL DPHI' FDC 17.904 RHOB.FDC NFDC.FDC 606.000 CALI.FDC NPHI.CNL 30.567 TNPH.CNL RCNT.CNL 1310.3Z7 RCFT.CNL CALI.CNL 8.805 GR.CNL DEPT.. 6400.000 TENS.OIL SFLUoOIL 3. 362 SP.OIL DPHZ.FDC 7.972 RHOB.FDC NFQC. FDC 609. 500 CALI.FDC NPHI°CNL 31.719 'TNPH.CNL RCNT.CNL 2098.399 RCFT.CNL C ALI. CNL 9.14! GR. CNL DEPT. 6300.000 TENSoDZL SFLU. DZL 1.676 SP.DZL DPHZ.FDC 16.183 RHOB.FDC NFDC.FOC 633.000 CALI.FDC NPHZ.CNL 48.588 TNPH.CNL RCNT.CNL 1630o090 RCFT.CNL CALZ.CNL 9.242 GR.CNL DEPT. 6100.000 TENS.OIL SFLU.DIL 2.326 SP.DZL DPHI.FDC 17.804 RHOB.FDC N'FOC.FDC 660.000 CALI.FOC NPHI.CNL 48o139 TNPHoCNL RCNT.CNL 1609.985 RCFToCNL CALI.CNL 12.609 GR.CNL DEPTo 61'00.000 TENS.OIL SFLU.DZL 2.959 SP.DIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FOC NPHIoCNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALZ.CNL -999.250 GR.CNL DEPT. 6000.000 TENS.OIL SFLU.DZL 4.460 SP.DZL DPHZ. PDC -999.250 RHOBoFDC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 5900.000 TENS.OIL SFLU.DXL 4.819 SP.DIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL 8-APR-1989'16:Z1 4504.000 ILD.DZL -48.406 GR.DIL 2.355 DRHO.FOC 8.805 GR.FDC 30.805 TNRA.CNL 766.990 CNTCoC'NL 65.438 TENS.CSG 4628.000 ILD.DIL -54.656 GR.DIL 2.518 DRHO;FDC 9.141 GR. oFDC 32.221 TNRA.CNL 692.722 CNTC. CNL 99.563 TENS.CSG 4540. 000 ILD.OZL -48. 375 GR.DZL 2-383 ' DRHO. FDC 9.242 GR.FDC 48.757 TNRA.CNL 432.595 CNTC.CNL 92.438 TEN'$.CSG 4324.000 ILD.DZL -53..688 GR.DIL Z. 356 DRHO'FDC 12. 609 GR. FDC 48.050 TNRA.CNL 399.800 CNTC.CNL 96.438 TENS.CSG 8.034 65.438 0.006 65.438 2.802 2431.311 -999.250 3.123 99.563 0.060 99.563 20906 2203.952 -999.250 1.302 92.438 0.032 92.438 3.855 1735.626 -999.250 1.896 96.438 0.042 96.4'38 3.999 1678.965 -999.250 4584.000 ILD.DIL 2.243 -54'625 GR.DZL 119.188 -999.250 DRHO. FDC -999-250 -999.250 GR.FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999o250 -999-250 TENSoCSG -999o250 &264.000 ILO.OIL -53.844 GR.DIL -999..250 DRHO-FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CSG -60.063 DIL -999.250 DRHO.FDC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL 2.721 177.500 -999.250 -999.250. -999.250 -999.250 -999.250 3.223 91.813 -999.250 -999.250 -999.250 -999.250 ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GRoCSG ILM.DIL TENS.FDC FFDC."FOC TENS.CNL NPOR.CNL CFTC.CNL GR..CSrG ILM.OIL TENS.FDC FFDC. FDC TENS.CNL NPOR.CNL CFTC.CNL GR .CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTCoCNL GR.CSG TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTC-CNL GR.CSG ILM.DIL TENS.FDC FFOC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG TENS.FDC FFOC.FDC TENS.CNL NPOR.CNL CFTCoCNL PAGE: 8.331 587.500 4504.000 31.627 882.247 -999.250 3.119 4628.000 46Z8.000 3Z.989 769°784 -999.250 1.369 4540°000 584.5'00 4540..0:00 50.530' 445'I'9Z -999'250 1.971 640.500 4324'. 000 48.69I 421.865 -999.250 2'.330 -999.2:50 -999.250 -999.2,50 -999'250 -999-250 -999. Z50 Z.SZO -999.250 -999.250 -999.250 -999.250 -999'250 -999.250 3.305 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE V~RIFICATION LISTING ~HLUFqBERGER ALASKA COMPUTING CENTER CALI.CNL -999.250 GR.CNL DEPT. 5800.000 TENS.OIL SFLU.DIL 4.172 SP.DIL DPHI.FDC -999.Z50 RHOB.FOC NFDC.FDC -999.250 CALI.FOC NPNI.CNL -999.250 TNPH.CNL RCNToCNL -999.250 RCFT.,CNL CALI.CN~L -999.230 GR.CNL DEPT. 5700.000 TENS.DIL SFLU.DI'L Z.044 SP.DIL DPHI.FDC -999.2'50 RHOB'FOC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999. 250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 5600.000 TENS.OIL SFLU,.DIL 3.601 SP.DIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPHoCNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 5500.,000 TENS.DIL SFLU.DIL 3.757 SP.DIL DPHI.FDC -999,.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.230 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. Z30 GR.CNL DEPT. 5400.000 TENSoDTL SFLU. OTL 6.504 SP.DIL DPHZ.FDC -999.250 RHOB.FDC NFDC.FDC -999..250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFToCNL C ALI.. CNL -999. Z 50 GR . CNL DEPT. 5300.000 TENS.OIL SFLU.DXL 3.488 SP.DIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPN.CNL RCNT.CNL -999.250 RCFT.CNL CALX.CNL -999.250 GR.CNL DEPT. 5200..000 TENS.OIL SFLU.OIL 3,..601 SP.OIL OPHI.FOC -999. 250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL 8-APR-1989 16:21 -999.250 4204.000 -61.938 - 999.2'50 -999.250 -999.250 -999.250 - 999. 250 ¢03-4.000 -48-438 -999*250 -999.250 -999o230 -999'230 -999.250 4014.000 -64.938 -999. 250 - 999. 250 -999.250 -999.250 -999.230 3894.000 -65.438 -999.250 -999.230 -999..230 -999.230 -999.250 4074°000 -89.625 -999.250 -999.250. .-999.250 -999.250 -999.230 37900000 -64.063 -999.250 -9990250 -999.250 -999.250 -999.250 3744.000 -27.891 -999.250 -999.250 -999.250 TENS.CSG ILO.OIL ' GR.DIL DRHO.FDC *~ GR. FDC TNRA. CNL CNTC.CNL TENSiCSG tLD.DIL '~. G R. D i L DRHO.FOC : G R. rF DC TN:R a. C NL C~TCiCNL TENSICSG ~LO.OIL GR.OIL DRHO. FDC "GR.FDC TNR A. CNL C#T C lC NL TENS.CSG ZLD.O ZL GR.DZL DRHO. FDC ;': GR-FDC TNR A. C N L CNT C. C NL TEN$.CSG ~,LD.OIL GR. DIL DRHO. FDC :GR. FOC T NR A. C NL C #T C. C NL TEN$. C S G ILO.OIL R o O I L oeHo. FDC :GR. FDC TNRAiCNL CNTCoCNL TENSoCSG ILO-OIL GRiDIL ORHOoFDC GR.FDC TNRA.CNL -999.250 3.519 104.12.5 -999.250 -999.250 -999.250 -999.250 -999.250 1.413 96.313 -999.250 -999.250 -999.250 -999.250 -999.250 3.409 94.8"/5 -999°250 -999°250 -999.250 -999. 230 -999.230 3.199 94. 938 -999.250 -999.230 -999.250 -999.230 -999. 250 3.621 73.688 -999.250 -999.250 -999. 250 -99:9.250 -999,250 3.160 1040750 -999° 250 -999.250 -999.250 -999.250 -999.250 3.107 100.938 -999.250 -999.250 -999.230 GR.CSG ILM'DIL TENS.FDC FFDCiPDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILH. OZL TENSoFDC FFDC'FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG TENS.FOC FFDC.FDC TENSgCNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TEN$.FDC FFDC.FDC TENS.CNL NPQR.CNL CFTC..CNL GRoCSG ILR,.DIL TENSoFDC FFDC.FDC TENS.CNL NPOR'.~CNL CFTC°CNL GR.CSG TENS. FDC FFDC.FDC TENS.CNL NPORoCNL CFTC.CNL GR.CSG TENS.FDC FFOC.FDC TENS.CNL NPOR.CNL PAGE: -999.250 3.588 -999.250 -999.250 -999.250 -999.250 -999. IS, -999.250 1.548 -999.250 -999.250 -999.250 -999-250 -999.250 -999.250 3.384 -999.ZS0 -999*250 -999.250 -999'250 -999'250 -999.250 3.124 -999-250 -999.250 -999*250 -999.250 -999.2'30 -999o250 3.800 -999.250 -999.250 -999.250 -999,Z~0 -999,250 -999.250 3.172 -999. 250 -999. 250 -999'230 -999.250 -999.250 -999o230 3.136 -999.230 -999.250 -999.230 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER RCNT.CNL -999.Z50 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPt. 5100.000 TENS.OIL SFLU.DIL 2.777 SP.DIL DPNI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999. 250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 5000.000 TENS.OIL SFLU.DIL 3.384 SP.DIL OPHI..FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CRLI.CNL -999. 250 GR.CNL DEPT. 4900.000 TENS.OIL SFLU.DIL 3.147 SP.DIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999. 250 TNPH.CNL RCNT.CNL -999. 250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 4800.000 TENS.OIL SFLU.DIL 2.353 SP.DIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CAL!.CNL -999.2 50 GR.CNL DEPT. 4700.000 SFLU.D~L 3.997 DPHI.FDC -999.250 NFDC.PDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999.250 TENS.OIL SP.DIL RHOB.FOC CALI .FOC TNPH .CNL RCFT.CNL GR.CNL TENS.OIL SP.OIL RHDB.FDC CALI.FDC TNPH.CNL RCFT .CNL GR .CNL DEPT,,, 4600.000 SFLU.D[L 2.380 DPHI.FDC -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999°250 DEPT. 4500.000 TENS.OIL SFLU.DIL 5.964 SP.DIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FOC 8-APR-1989 16:21 -999.250 'CNTC.CNL -999.250 TENS.CSG 3804.000 ILD.DIL -24.984 GR.DIL -999. Z50 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.25'0 TENS.CSG 3600~000 ILO.OIL -32.031 GR.DIL · -999.250 ORHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.Z50 CNTC.CNL -999.250 TENS.CSG 3634.000 ILO. OIL -25.266 GR.DIL -999o250 DRHO.FDC -999°250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999o250 TENS.CSG 3574.000 ILD.DIL -24.422 GR.DIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999. Z50 TENS.CSG 3454.000 ILO.OIL -42.719 GR.DIL -999.250 DRHO.FDC -999.250 GR.FOC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CSG 3~20.000 ILD. OIL -25.969 GR.DIL -999.250 DRHO.FDC -999.250 GR.FDC -999.250 TNRA.CNL -999.250 CNTC.CNL -999.250 TENS.CSG -999.250 -999.250 2.680 87.563 -999.250 -999.250 -999.250 -999.250 -999.250 2.917 96.375 -999.250 -999.250 -999'250 -999.250 -999.250 2.014 90.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.902 109.625 -999.250 -999.250 -999.250 -999.250 -999.250 3.671 110.125 -999.250 -999.250 -999.250 -999.250 -999.250 Z.211 86. 563 -999o250 -999.250 -999.250 -999.250 -999.250 3464.000 ILD.DIL 2.913 -23.000 GR.DIL 75.188 -999.250 DRHO.FDC -999.250 -999. 250 GR.FOC -999.250 CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC..FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENSoCNL NPOR .CNL CFTC.CNL GR.CSG ILMoDIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.FDC FFOC.FOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL PAGE:' -999.250 -999'250 Z.660 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.903 -999.250 -999.250 -999.250 -999.250, -999.250 -999.250 2.222 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.821 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.533 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 Z.182 -999.250 -999.250 -999.250 -999.250 -999.250 -999°250 3.184 -999.250 -999.250 -999.250 IS TAPE VERIFICATIDN LIS. TING CHLUMBERGER ALASKA COMPUTING CENTER NPHI,.CNL -999.250 TNPH.CNL RCNT.CNL -999.2150 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 14400--000 TENS.OIL SFLU. DIL 2.602 SPoOIL DPHIo'FDC -999.250 RHUB.FOC NFDC.FDC -999.250 CALI.FOC NPNZ.CNL -999.250 TNPH.:CNL RCNT.CNL -999. 250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 4300.000 TENS.OIL SFLU.OZL 2.992 SP.DIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CAL'I.FDC NPNi. CNL -999.250 TNPH.~CNL RCNToCNL -999.250 RCFT.CNL CAL,I.CNL -999.250 GR.CNL DEPT. 4200.000 SFLU. OIL 2.968 DPHI.FDC -999. 250 NFDC..FDC -999. 250 NPHI.CNL -999. 250 RCNT. CN'L -9 99.2 50 CALZ.CNL -999..250 TENS.OIL SP.D.IL RHOB.FOC CALI.FDC TNPH.CNL RCFT 'CNL GR .CNL TENS.D,~L SP.OIL RHOB.FOC CAL! .FOC T'NPHoCNL RCFT-CNL GR.CNL TENS oDIL SP.DIL RHOB, FOC CALI.FDC TNPH.CNL RCFT .CNL GR.CNL TENS.DIL SP.DIL RHOB.FDC CALI.POC TNPHoCNL RCFT.CNL GR .CNL DEPT. 4100.000 SFLU.DIL 3.147 DPHI.FDC -999.250 NFDC.FDC -999.250 NPHI.CNL -999.250 RCNT'CNL -999o250 CALI.CNL -999.250 DEPT. 4000.000 SFLU. OIL 3.630 DPH[.FDC -999.250 NFDC. F:DC -999. 250 NPHI.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999.250 DEPT. 3900.000 SFLU.DIL 3.813 DPHI. FDC -999.250 NFDCoFDC -999.250 NPHZ.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999.250 8-APR.-1989 16:Z1 -999. 250 TNRA.CNL -999.250 CNTC.CNL -999.250. TENS.CSG 3390.000 -22.078 -999.250 -999'250 -999-250 -999.250 -999'250 .[LD.DIL ;GR.DIL DRHO.FDC :'GR.FDC TNRA.CNL C~TC.CNL TENS.CSG ZLD.OIL :!GR. OIL DRMO. FOC 3234.0:00 -24' 516 -999.250 - 999, Z:5'0 - 999. 250 - 999.250 - 999.25 O' T'E N'S - C S:G 3184.000 :~L D' D I L -25' 953 ~GR.DIL ,- 9 9 9.2'5 0 O~H 0. F D C -999'250 !'GR.FDC -999° 250 .CNL -999' 250 .CNL -999.250 .CSG 3204.000 ZLD,DIL - Z 9- 0 6 3 '~G R. O i L -999.250 DR:HO.FDC -999°250 .FDC -999. 250 T~RA.CNL -999. 250 C~!TC.CNL -999.250 TENS'CSG 3004o000 ZLDoDIL -30.016 GR.DZL - 999"250 D, RHO.. FOC -999.250 .~GR. FDC -999'250 oCNL -999~250 NL '~999'~'ZS0 Ti .CSG Z934.000 iLO.OIL -35.250 :'GR.DIL -999'Z50 DRHOoFDC -999. 250 ~::GR. FDC -999.250 TNRA.CNL -999'250 C#TC.CNL -999. ZSO TENS.CSG -999.250 -999.250 -999.250 2.570 88.813 -999.250 -999.250 -999.250 -999.250 -999'250 2.946 98.000 -999. 250 -999..250 -999.250 - 999- Z S 0 -999.250 2.90Z 82.. 063 -999.250 -999.250 -999.250 -999' ZSO -999. 2510 3. 279 95.313 -999.250 -999.250 -999.250 -99'9.250 -999.250 3.185 85.188 -999'~ 250 -999.250 -999.250 -999'250 -999.250 3:.6.91 91.438 -999.250 -999.250 -999.250 -999.250 -999.250 ,NPOR.CNL CFTC, CNL GR.CSG ILM.OIL TENS.FDC FFDCoFDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIiL ,TENS.FDC FFDC.FD:C TENS.CNL ,'NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG iLM.DZL TENS. FDC FFO,C.FOC TENS.CNL NPOR.,CNL CFTC.'CNL GR.CSG ILM.OIL TENS'FDC FFDC-FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ZLM.OIL TENS.FOC FFDC.FOC TEN$.CNL NPOR.CNL CFTC.CNL GR.CSG PAGE: -999.250 -999.250 -999.250 2.515 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 2.860 -999.250 -999.250 -999.250 -999.250 -9199.250 -999.2.50 '2.769 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250. 3.076 -999.250 -999.250 -999'250 -999.250 3.107 -999 ' 25i0 - 999 , ~.5 g -999.250 -999: * Z 50 -999.'250 -:999.250 3. 535 -999. 250 -999.250 -999o250 -999.250 -999.250 -999o250 ::[.S TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER DEPT. 3800.0:00 SFLU.DIL 3,693 DPHZePDC -999.250 NPDC.FDC -999.250 NPHZ.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999.Z'50 8-APR-1989 -16:21 DEPT. 3700.000 SFLUoOZL 4.364 DPHI.FDC -999.250 NFDC.FDC -999.250 NPHZoCNL -999.250 RCNT.CNL -999.Z50 CAL~.CNL -999.250 DEPT. 3600.000 ,F'LU..DIL 3.774 DPHZ.FDC -999.250 NFDC.FDC -999.250 NPHZ.CNL -999.250 RCNT.CNL -999.Z50 CALI.CNL -999°-250 DEPT. 3500.000 SFLUoD[L 3.636 DPH[.PDC -999.250 NFDC.-FDC -999.Z50 NPHZ.CNL -999.250 RCNT.CNL -999.250 CAL~.CNL -999.250 TENS.DZL 288&,000 ILD'DZL 3,777 SP.DIL -33.094 GR'DIL 9&..O00 RH,OB.FDC -999.Z50 DRHO. FDC --999.250 CALI.FDC -999.250 GRi:PDC -999.250 TNPH. CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999.Z50 CNTC.CNL -999.250 GR.CNL -999.Z50 TENS.CSG -999°250 TENS.DIL 2780.000 ILD.D[L 4.214 S P. DIL -33.53'1 GR. D IL 94 o 188 RHOB.FOC '999.Z50 DRHO,-FDC -999.250 CALI.FOC -999. Z50 GRoFDC -999.Z50 T'NPH.CNL -999.250 TNRA'C'NL -999. Z50 RCFToCNL -999.250 CNTC~CNL -999.250 GR.CNL -999-250 TENS.CSG -999.250 TENS.DIL 2674,000 ILDoDZL 3.637 SP.DIL -34.'Z50 GR.DIL 84.8T5 RHOB.FDC -999.250 DRHO'FDC -999.250 CALI.FDC -999.Z50 GR.FDC -999.250 TNPH.CNL -999.Z50 TNR&oCNL --999.250 RCFT.CNL -999. Z50 CNTC°CNL -999-Z50 GR.CNL -99.9.Z50 TENS.CSG -999.2'50 DEPT. 3400.000 SFLU.D[L 2.751 DPHI.FDC -999oZ50 NFDC.FDC -999.Z50 NPHZ..CNL -999.Z50 RCNT. CNL -999.250 CAL~oCNL -999.Z50 TENS.DIL 2624.000 ILO. OIL SP.DIL -36.6Z5 OR'OIL RHOB.FOC -999.250 CALI.FDC -999.250 TNPH.CNL -999.Z50 RCFT.CNL -999.Z50 CNTC.CNL GR.CNL -999.250 TENS, CSG DEPT. 3300.000 SFLUoDZL -999oZ50 DPHZ.FDC -999.250 NFDC.PDC -999'.Z50 NPHZoCNL -999oZ50 RCNT.CNL -999oZ50 CALI.CNL -999. Z50 TENSIDZL SP.DZL RHOB.FDC CALI.PDC TNPH.CNL RCFT.CNL GR.CNL DEPT. 3200.000 SFLU.DIL -999.250 DPHI.FDC -999oZ50 NFDC.FDC -999oZ50 NPH[.CNL -999.250 RCNT.CNL -999.250 CALI.CNL -999.Z50 2614.000 TLD.OTL -38.500 GR.D[L -999°250 ORNO.FOC -999. 250 OR". FOC -999.250 TNRAoCNL -999'Z50 CNTCoCNL -999. Z50 TE#$oCSG 2.922 89. 875 -999.250 --999.250 -999.Z50 Z.600 82.938 -999.250 -999.250 --999°250 -999.250 2514'000 ILN. DIL TENS.. FOC FFDC' FDC TENS.CNL NPOR'CNL C FTC. CNL GR.CSG ILM.OIL TENS.FOC F FDC..FDC T EN'S- CN.L NPOR ' CNL CFTC°CNL GR.CSG ZLlq. OZL TEN$.FDC FFDC.FDC TENS 'CNL NPORoCNL C FT C. CNL GR.CSG ILM.DZL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTCoCNL GRoCSG ILH.DIL TENS.FDC FFDC.FOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG TENS.0IL -999.Z50 ILD.DZL -999. Z50 ZLM.DZL SP.DZL -999.250 -999-Z50 TENS.FDC RHOB.FDC -999.Z50 -999.Z50 FFDC.FDC CAL !. FDC - 999. Z50 TENS o CNL TNPH.CNL -999. ZSO NPOR.CNL RCFT.CNL -999.250 -999.250 CFTC.CNL GR.CNL -999.Z50 TENS.CSG 2500.000 GR.CSG TENS.DIL -999.Z50 ILD.DIL -999.Z50 SP.DZL -999. Z50 6R.DZL -999oZ50 RHOB.FDC -999.Z50 DRRO.FDC -999. Z50 CALZ.FDC -999.Z50 GR. FDC -999.250 TNPH.CNL -999.250 TNRA.CNL -999.250 RCFT.CNL -999oZ50 CNTC.CNL -999.250 GR.CNL -999.Z50 TENS.CSG 2460.000 ILN.DZL TENS.FDC FFDC.FDC TENS CNL NPOR:CNL CFTCoCNL GR.CSG PAGE: 10 3.556 -999.250 -999.Z50 -999.Z50 -999.250 -999.2.50 -999.Z50 3.T67 -999.250 -999.250 -9.99.250 -999. Z50 -999oZ50 -999.250 3.3-10 -999.250 -999.250 -999.,~Z50 -999.250 -999'Z50 -999.Z50 Z.850 -999.Z50 -999.25.0 -999° Z50 -999, 25.0 -999.Z50 -999.Z50 -999.Z50 -999.2.5.0 -999.250 -999. Z'50 8'3 '438 -999°250 -999oZ50 -999oZ50 -999oZ50 -999.Z50 -999°250 -999oZ50 48.375 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 8-APR-1999 16:21 PA6E: 11 DEPT. 3100.000 TENS.DIL SFLUoDIL -999,250 SP.DIL DPHI.oFDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC NPHZ.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 3000.000 TENS.OIL SFLU.OIL -999.250 SP.DIL DPHI.FDC -999.250 RHOB.PDC NFDC.FDC -999.250 CALI'FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 2900.000 TENS.OIL SFLU.DIL -999.250 SP.OIL DPHI.~DC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.Z'50 TNPHoCNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. Z800oO00 TENS.OIL SFLU'DIL -999.250 SP.DIL DPHI.FDC -999.250 RHOB'FOC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALIoCNL -999.250 GR.CNL DEPT. 2700.000 TENS.OIL SFLU.OIL -999.250 SP.DIL DPHIoFDC -999.250 RHOBoFDC NFDC.FDC -999.Z50 CALI.FDC NPHIoCNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALIoCNL -999.250 GR.CNL DEPT. 2600.000 TENS.OIL SFLU.DIL -999.250 SP.OIL DPHZ.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALZ.FDC NPHX.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 2500.000 TENS.OIL SFLU.DIL -999.250 SP.DIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL -999.250 ILD. DIL -999.250 -999.250 'GR.OIL -999.250 -999.250 DRHO-FDC -999.250 -999.250 GR-FDC ,-999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 2380.000 -999°250 ILO.OIL -999.250 -999.250 ~!:GR.DIL -999.250 -999.2'S0 DRHO.FOC -999.2510 -999.250 ::~GR:. FDC -999.250 -99:9. 250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS. CSG ~ 2394.000 -999.Z50 I:LD.DIL -999.250 -999.25'0 GR.DIL -999.250 -999.250 DRHO.FDC -999.250 -999.250 GR.FDC -999.250 -999.250 TNRA.CNL -999'.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG 2344.000 -999.250 ILD.DIL -999.250 -999.Z50 ~'GR.DIL -999.250 -999.250 DRHO.FDC -999.250 -999.250 iGR.FDC -999.250 -999.250 TNRA.CNL -999.250 -999'250 CNTC.CNL -999.250 -999.250 TENS.CSG 2250.000 -999.250 ILO.OIL -999.250 -999.250 ,,'GR.DIL '-999.250 -999.250 DRHO.FOC -999.250 -999.250 ' GR.FDC -999.250 -999.250 TNRA:CNL -999.250 -999.250 C'~C CNL -999'250 -999.250 TENS.CSG 2204o000 -999.250 ILD.DIL -999.250 -999.250 GR.DiL -999.250 -999.250 DRHO'FDC -999.250 - 999. 250 ~:::G R' FDC -999. 250 -999. 250 TNRA.CNL -999.250 -999.250 C~C.CN'L -999.250 -999.250 TENS.CSG 2160o000 -999.250 ILD.DIL -999.250 -999.250 GR.DIL --999.250 -999.250 DRHO.FOC -999.250 -999.250 GR.FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 ILM.OIL TEN"S.FDC FFDC.FOC TENS.CNL NPOR .CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDCoFOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM,.OIL TENS.FDC FFDC.FDC TENS.CNL NP§R.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDC.FDC TENS.CNL NPOR'CNL CFTC'CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.,,CSG ILM. OIL TENS.FOC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILR. DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL -999.250 -999.250 -999.25:0 -999.250 -999.250 -999.250 56.688 -999.250 -999-250 -999.250 -999.250 -999.2'50 -999.250 48'000 -999.250 -999.250 -999.250 -999-250 -999.250 -999'250 44.50,0 -999.2.5:0 -999.250 -999.250 -999.250 -999.250 -99,9.250 43.219 -999-2'50 -999.250 -999.250 -999.250 -999.250 -999.25'0 47.406 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 52.531 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERI'FICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER CALZ.CNL -999. Z50 GR.CNL DEPT. Z400.O00 TENS.DIL SFLU.OIL -999- ZSO SP.OIL DPHI.FDC -999.250 RHOB.FDC NFDCoFDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPHoCNL RCNT.,CNL -999.Z50 RCFT.CNL CALI.CNL -999. 250 GRoCNL DEPT. 2300.000 TENS.OIL SFLU. OIL -999.Z50 SP.OIL DPHI'FDC -999.250 RHOB.FOC NFDC. FDC -999.250 CALI.FDC NPflI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 2ZO0-O00 TENS.OIL SFLU. OIL -999. 250 SP.OIL DPH[.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999. Z50 TNPH.CNL RCNT.CNL -999,,250 RCFToCNL CA'LZ.CNL -999.250 GR.CNL DEPT. 2100. SFLU.DXL -999. DPHI.FDC -999. NFDC. FDC ,-999 NPH[.CNL -999. RCNT.CNL -999. CALI.CNL -999. 8-APR-1989 16:Z1 DEP'T. ZOO0. SFLU.OXL -999. DPHI.FDC -999. NFDC.FDC -999. NPH[.CNL -999. RCNT.CNL -999. CALI.CNL -999. DEPT. 1900. SFLU.DIL -999. DPHI.FDC -999. NFDC.FDC -999. NPHI.CNL -999. RCNT.CNL -999. CALI.CNL -999. DEPT. 1800. SFLU.DIL -999o DPHI.FDC -999. NFDC.PDC -999. NPHI.CNL -999° -999.250 TENS.CSG 2110..000 -999.250 ILD'DIL -999.250 -999.250 GR.DIL -999.250 -999.250 DRHO.FDC -999.250 -999.250 GR.FDC -999.250 -999.250 TNRAoCNL -999.250 -999.250 CNTC.CNL -999.250 -999.250 TENS.CSG '2074.000 -999.250 ILO.OIL -9'99.250 -999. 250 GR.DIL -999. 250 -999.250 DRHO,PDC -999.250 -999. 250 GR.FDC -999.250 -999.250 TNRAoCNL -999.250 -999. 250 CNTC.CNL -999.250 -999.250 TENS.CSG 2000.000 -999.250 ILO.OIL -999.250 -999. 250 GR. OIL -999-250 -999.250 DRHO.FDC -999.250 -999,250 GR'FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 CNTC.CNL -999.250 -999.Z50 TENS.CSG 1935.000 000 TENS.OIL -999.250 ILO.OIL Z 50 S P..OIL -999.250 GR.D IL 250 RHOB. FDC .-999.250 DRHO,FDC 250 CALI.FDC -999.250 GR.FDC 250 TNPH.CNL -999. 250 TNRA.CNL 250 RCFT.CNL -999.250 CNTC.CNL 250 GR.CNL -999.250 TENS.CSG 000 TENS.OIL -999.250 ILO.OIL 250 SP.DIL -999. 250 GR.OIL 250 RHOB.FOC -999-250 ,DRHO. FDC 250 CALI.FDC -999.250 GR.FDC 250 TNPH.CNL. -999.250 TNRA'CNL 250 RCFT.CNL -999. ZSO CNTC.CNL 250 GRoCNL -999.250 TENS.CSG 000 TENS.,DIL -999.Z'50 [LO.OIL 250 SP. OIL -999,. 250 GR . OIL 250 RHOB.FDC -999.250 DRMO.FDC 250 CALI.FDC -999.250 GR.FDC 250 TNPH.CNL -999.ZS0 TNRA.CNL 250 RCFT.CNL -999.250 CNTC.CNL 250 GR.CNL -999.250 TENS.CSG 000 TENS.OIL -999. ZSO ILD.DIL 250 SP.DIL -999.. 250 GR.OIL 250 RHOB.FDC -999.250 DRHO.FDC 250 CaLI.FDC -999.250 GRoFDC 250 TNPH.CNL -999.Z50 TNRA.CNL -999. 250 -999.250 -999.250 -999.250 -999.250 -999.250 1905,000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1860.000 . -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1785.000 -999.250 -999.250 -999.250 -999.250 -999.250 GR.CSG ILM.DIL TENS.FDC FFDC.FOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TE:NS-FOC FFDC.FDC TENS.CNL NP'OR.CNL CFTC.CNL GR.CSG ILM. OIL TENS.FDC FFDC.FDC TENSoCNL NPOR.CNL CFTCoCNL GR.CSG ILM.OIL TENS.FDC FFDC.FDC TENS.CNL NPORoCNL CFTC.CNL GR.CSG ILM.DIL TENS.FOC FFOCoFDC TENS.CNL NPORoCNL CFTC.CNL GRoCSG ILMoDIL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL PAGE: 12 36.594 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 38.813 -999. 250 -999.2;50 -999.250 -999.250 -999.250 -999.250 3Z.3~4 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 33-063 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 33.063 -999.250 -999.250 -999.250 -999.250 -9990250 -999.250 35.719 -999.250 -999.250 -999-250 -999,250 -999o250 -999.250 31.313 -999-250 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.2:50 GR.CNL DEPT. 1700.000 TENS.OIL SFLU. DIL -999.250 SP.OIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC NPH~.CNL -999.2.50 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 1600.000 TENS.OIL SFLU. DTL -999. 250 SP.OIL DPHI.PDC -999.250 RHOB.FOC NFDC. FDC -999. 250 CALI. FDC NPHX.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.2 50 GR.CNL DEPT. 1500.000 TENS.OIL SFLU.DIL -999. 250 SP.OIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNrL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 1400.000 TENS.OIL SFLU.OIL -999.250 SP.OIL OPHIoFDC -999.250 RHOB.FDC NFDC.FDC -99'9.2:50 CALI.FOC NPHI.CNL -999.250 '" TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 1300.000 TENS.OIL SFLU. DZL -999. 250 SP.OIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999. 250 RCFT. CNL CALZ.CNL -999.250 GR.CNL DEPT. 1200.000 TENS.OIL SFLUoDXL -999. 250 SP.OIL DPHI.FDC -999.250 RHOB.FDC NFDC.FDC -999.250 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999. 250 GR.CNL DEPT. 1100.000 TENS.OIL SFLU.DIL -999.2:50 SP.OIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.250 CALI.FDC 8-APR-1989 16:Z1 -999.250 CNTC.CNL -999..250 TENS.CSG -999.250 1765.000 -999.250 ILO.OIL -999.250 -999. 250 GR.OIL -999. 250 -999.250 ORHO.FDC -999.25'0 -999.250 ~GR.FDC -999.250 -999. 250 TNRA. CNL -999. 250 -999. 250 C!~TC.CNL -999.250 -999.250 TENS.CSG 1705.000 -999.250 ILO.OIL -999.250 -999. 250 GR.D!L -999.250 -999.250 DRHO.FDC -999.250 -999.250 -~'i"G R. FDC -999.25'0 -999.250 TNRA.CNL -999.250 . #:1: C. C NL 9.250 -999 250 C -99 -999.250 TENS.CSG 1670.000 -999.250 ILO,OIL -999.250 -999.250 '/IGR-DIL -999.250 -999.250 DRHO,FDC -999.250 -999,.250 GR.FDC -999.250 -999.250 TN:RA.CNL -999.250 -999.250 C~TC.CNL -999.250 -999.250 TENS.CSG 1605.000 -999.250 Z:LD.DZL -999.250 -999°250 GR.DIL -999.250 -999.250 DRHO.FDC -999o250 -999.250 :GR.FDC -999.250 -999.250 T#RA.CNL -999.250 -999.250 C~TC.CNL -999.250 -999.250 TENS.CSG 1565.000 -999.250 ILO.OIL -999.250 -99'9.Z50 GR.DIL -9!99.250 -999o250 DRHO.FDC -999.250 -999.250 'GR.FDC -999.2'50 -999.250 T#RA.CNL -999o250 -999.250 C#TC.CNL -999.250 -999.250 TENS.CSG 1685.000 -999.250 [LD.D!L -999.250 -999.250 ~GR.DZL -999.250 -999.250 DRHO. FDC -999.250 -999.250 GR.FDC -999.250 -999.250 TNRA.CNL -999.250 -999.250 C#TC.CNL -999.250 -999.250 TENS.CSG -999.250 ILO.OIL -9'99.250 -999.250 GR.DIL -999.250 -999o250 ORHO.FOC -999.250 -999.250 GR.FDC -999.250 CFTC.CNL GR.CSG ILM.DIL TENS-FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM.OIL TENS.FDC FFDC,FDC TENSoCNL NPOR-CNL CFTC.CNL GR.CSG ILM.DIL" TENS.FDC FFDCoFDC TENS.CNL NPOR.CNL CFTCoCNL GR.CSG ILM. DIL TENS.FDC FFDC'FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDC,,FDC T E N S, C NL NPOR.. CNL CFTC.CNL GR .CSG ILM. OZL TENS.FDC FFDC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FDC FFDC.FDC TENS.CNL PAGE:: 13 -999.250 33.719 -999-25'0 -999. 250 -999.250 -999.250 -999.250 -999.250 63. 688 -999.250 -999.250 .-999.250 -999.250 -99:9. 250 -999.250 3 5. 750 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 27.266 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 37.096 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 50.688 -999.250 -999°250 -999.250 -999.250 -999.250 -999.250 64.625 -999.250 -999.250 -999.250 -999.250 IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER NPHI.CNL -999. 250 TNPH.CNL RCNT. CNL -999.250 RCFT.CNL CALI.CNL -999.2'50 GR.CNL DEPT. 1000.000 TENS.OIL SFLU. DIL -999.250 SP.OIL DPHI.FDC -999.250 RHOB.FOC NFDC.FDC -999.Z50 CALI.FDC NPHI.CNL -999.250 TNPH.CNL RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL DEPT. 995.500 TENS.DIL SFLU.D[L -999.250 SP.DIL OPHI.FOC -999.250 RHOB°FOC NFDCoFOC -999.250 CALI.FOC NPHI.CNL -999.250 TNPH.CNLr RCNT.CNL -999.250 RCFT.CNL CALI.CNL -999.250 GR.CNL 8-APR-1989 16:21 -999.Z50 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 -999.250 -999.250 -999.Z50 -999. Z50 -999.250 -999.250 -999.250 -999.250 - 999. IS0 -999.250 -999.250 TNRA.CNL CNTCICNL TENS.CSG ILO.OIL GR.DIL DRHO .FDC GR.FOC TNRA.CNL CNTC.CNL TENS.CSG ILO.OIL GR.DIL DRHO,FDC GR.FDC TNRA.CNL CNTC.CNL TENS.CSG -999.250 -999.250 1370.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1305.000 -999.250 -999.250 -999.250 - 999.2:50 -999.250 -999.250 1315.000 NPOR.CNL CFTC.CNL GR.CSG ILM.DIL TENS.FOC FFDC.FOC TENS.CNL NPOR.CNL CFTC.CNL GR.CSG ILM. DIL TENS.FOC FFOC.FDC TENS.CNL NPOR.CNL CFTC.CNL GR .CSG PAGE: 14 -999.250 -999'250 32.625 -999.250 -999.Z50 -999.250 -999.250 -999.250 -999.25,0 35-031 -999.250 -999.250 -999.Z50 -999.Z50 -999.250 -999.250 30.531 END OF DATA ~t FILE TRAILER ~ FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 001A02 DATE : 89/0~/ 8 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : · ~ FILE HEADER '.~ FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001A02 DATe : 89/0~/ 8 MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : THIS DATA HAS NOT BEEN DEPTH SHIFTED - OVERLAYS FIELD PRINTS IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 8-APR-1989 16:21 PAGE: 15 SCHLUMBERGER LOGS INCLUOEO WITH THIS FILE (EDIT.O02): <SEE FILE EDIT.O0! FOR 6" SAMPLED DIL/FDC/CNL/GR DATA> FORMATION DENSITY COMPENSATED LOG~:(.FDH) FIRST TO LAST READING: 6694' TO 6145' COMPENSATEO 'NEUTRON LOG (.CHH) FIRST TO LAST READING: 6678' TO 6145' TABLE TYPE : CONS TUNI VALU DEFI CN ARCO ALASKA~ INC. COMPANY NAME FN KUPARUK FIELD NAME WN 3 I-ll WELL NAME NATI USA NATION STAT ALASKA STATE OR PROVINCE COUN NORTH SCOPE COUNTY FL 147' FSL & 48' FEL FIELD LOCATION SECT 26 SECTION TOWN 13N TOWNSHIP RANG 8E RANGE ENGI TINKHAM~WARNER ENGINEER'S MARE SON 548421 SERVICE ORDER NUMBER APIN 50-029-21932-00 API SERIAL NUMBER TABLE TYPE : CURV DEFI DEPT DEPTH CHANNEL NAME TENS DPHI RHOB DRHO FFDC NFDC CALI GR TENS NPHI TNPM TNRA NPOR RCNT RCFT TENSION DENSITY POROSITY BULK DENSITY DELTA RHO FAR FDC COUNT RATE NEAR FDC COUNT RATE CALIPER GAMMA RAY TENSION NEUTRON POROSITY THERMAL NEUTRON POROSITY CALIBRATED THERMAL NEUTRON RATIO NEUTRON POROSITY OUTPUT FROM AN APPLICATION PROGRAM RAW CORRECTEO NEAR THERMAL COUNTS RAW CORRECTED FAR THERMAL COUNTS IS TAPE VERIFICATION LISTING CHLUMBERGER ALASKA COMPUTING CENTER 8--APR-1989 16:Z1 PAGE: 16 OEFI CNTC CORRECTED NEAR THERMAL COUNTS CFTC CORRECTED FAR THERMAL COUNTS CALl CALIPER GR GAMMA RAY DATA FORMAT SPECIFICATION RECORO *~ SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 Z 66 0 3 73 80 4 66 1 5 66 6 73 7 65 8 68 0,.099 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - tHAN ** NAME SERV UNIT SERVICE AP1 API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER J LOG TYPE CLASS MOD NUMB SAMP ELE# CODE CHEX) DEPT FT 548421 O0 TENS FDH LB 5484'21 O0 DPHI FDH PU 548421 O0 RHOB FDH G/C3 548423. 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