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Home My WebLink About186-188Originated: Schlumberger PTS - PRINTCENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Del ivered to: �.�f� AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 186188 TRANSMITTAL DATE TRANSMITTAL# �,.. EUNAME API It IfColor FIELD NAME DESCRIPTION DESCRIPTIONDATA DATELOGGED Prints CD's 1A-25 30-11 3K-23 50-029-22116.00 50-029-21676-00 50-029-22771-00 ENL -00028 EBNL-00029 EBNL-00030 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL PPROF LDL LDL FINAL FIELD FINAL FIELD FINAL FIELD 21 -Jun -19 22 -Jun -19 23 -Jun -19 1 1 1 2V-02 1Y-1450.029-20910-00 1H-109 1H-113 1H-117 3H -14B 50-029-21037-00 50-029-23595-00 50-029.23588-00 50-029-23602.00 50-103-20092-02 EBNL-00034 EBNL-00035 EBNL-00036 EBNL-00037 EBNL-00038 EOSH-00062 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL IPROF (PROF IPROF IPROF [PROF LDL FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 27 -Jun -19 28 -Jun -19 29 -Jun -79 30 -Jun -19 1 -Jul -19 3 -Jul -19 1 1 1 1 1 1 2G -14A 18-06 1B-09 3G-03 1R -22A 50.029-21161-01 50-029-20603-00 50-029.20655-00 50.103-20245.00 50-029-22206-Ot EOSH-00064 EOSH-00065 EOSH-00066 EDSH-00067 EOSH-00048 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WLLDL LDL PPROF IPROF PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 5 -Jul -19 6 -Jul -19 7 -Jul -19 8 -Jul -19 8 -Jul -19 1 1 1 1 1 JUL 12 2P19 14 �.. /� l A Transmittal Receipt signature confirms that a package (box, D! / (/ /jam envelope, etc.) has been received and the contents of the X V package have been verified to match the media noted above. " Name Signature Date specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this e return via courier or sign/scan and email a copy Schlumberger and CPAI. point. a PTSPrintCenter@slb com Tom.Osterkam@conoconhoom SLB Audirnr- i—. Schlumberger -Private THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Ron Phillips Sr. Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-11 Permit to Drill Number: 186-188 Sundry Number: 319-258 Dear Mr. Phillips: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. o og cc. a las ko.gov Enclosed is the approved application for the 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 farther time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner ncl DATED this ZZ day of May, 2019. RBDMS1-"'MAY 2 3 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 141AY 17 -1019 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A w\f-%P`°PN 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑Q 6p ab., Wi4dwinEl Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing E Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory E Development 0. Stratigraphic ❑ Service ❑ 186-188 3. Address: 6. API Number: P.O. Box 100360, Anchorage, AK 99510 50-029-21676-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 30-11 , Will planned perforations require a spacing exception? Yes ❑ No ❑Q 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25512, ALK 2553 1 Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD, (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): - , &6634' 7001' 6401' 1,940 none 7001',7003' Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 16" 115' 115' Surface 3748' 9.625" 3808' 3730' Intermediate Production 7180' 7" 7240' 6607' Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 6928'-6942',8948'-6964',8970'-7000' 6338'-6359,6354'-6369',6374'-6400' 2.875" L-80 6845' Packers and SSSV Type: Packer (Baker FHL) Packers and SSSV MD (ft) and TVD (ft): FHL Packer (6,676'16,122') Packer (Camco HRP -1 -SP) HRP -1 -SP Packer (6,814'/ 6,240') 12. Attachments: Proposal Summary Wellbore schematic Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑� Exploratory E Stratigraphic ❑ Development ❑Q Service ❑ 14. Estimated Dale for 15. Well Status after proposed work: Commencing Operations: 5/31/2019 OIL ❑Z WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Ron Phillips Contact Name: Ron Phillips Authorized Title: Sr. Wells Engineer Contact Email: Ron.L.Phillios(dtCOP.com Contact Phone: 265-6312 Authorized Signature: y Dale: 5/16/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: i1 I� 15 r ( Plug Integrity F-1BOPTest � Mechanical Integrity Test El Location Clearance Other: g0%� �-'- 'f o Z 50 O s' 4 fthnv/R✓ �� rVt✓ytf� f>St � Zv�bU�52-' Post Initial Injection MIT Req'd? Yes C]No 18DMQ MAY Spacing Exception Required? pD - 4 6 T 2 31019 Yes ElNo Subsequent Form Required: APPROVED BY eby ' COMMISSIONER THE COMMISSION Date: 5 / 1 ApprovV7-,-- Jr,1 a& 7''I-1 5,12-111" ORIGINAL /�^q— S66 —/ / mit Fotma d4' / Q" Form 10-403 Revised 412017 Approved application is-va0d'for 12 months from the date of approval. T#/�Altachments in Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 16 May 2019 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3Q -I1 (PTD #186-188). Kuparuk well 3Q-11 was originally drilled in 1986 and completed in 1987 as an `A' sand producer in Kuparuk. In 1990 the A and C sand was re -perforated and hydraulically fractured to improve production. In 2006 multiple tubing leaks warranted a RWO in September 2007. A tubing leak was identified in April 2019 and a workover was recommended to repair and upsize the tubing from 2-7/8" to 3-1/2" prior to a CTD sidetrack. ✓ The proposed workover scope for 3Q-1 I will include pulling the 2-7/8" completion with a stacker packer and a second packer and then installing a new 3-1/2" completion to prepare for CTD. If you have any questions or require any further information, please contact me at 265-6312. Sincerely, P,4 Ron Phillips Senior Wells Engineer CPAI Drilling and Wells 3Q-11 Rig Workover CTD Setup (PTD #: 186-188) Current Operations: This well is currently shut-in and awaiting a RWO. Scope of Work: Pull the existing 2-7/8" completion, and install a new 3-1/2" single packer completion. ✓ General Well info: Well Type: MPSP: Static BHP: Wellhead type/pressure rating: BOP configuration: MIT results: Production Engineer: Workover Engineer: Producer 1,940 psi using 0.1 psi/ft gradient 2,577 psi / 6,369' TVD (7.8 ppg EM W) measured on 04/16/19 Cameron Gen IV, 5M psi top flange Annular / Pipe Rams / Blind Rams / Pipe Rams CM1T-TxIA PASSED — 05/11/2019 MIT -OA PASSED — 05/12/2019 IC POT &PPPOT PASSED — 05/12/2019 TBG POT &PPPOT PASSED — 05/12/2019 Devin Kozak Ron Phillips (263-6312/ Ron.L.Phillips@ConocoPhillips.com) Pre -Rig Work 1. MIT testing. SBHP test. TBG and CSG PO tests. 2. String shot and chem cut first joint above packer. 3. FT LDS, grease tree valves and set BPV. Workover Procedure 1. MIRU. Pull BPV. Circulate workover fluid. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE and pressure test rams to 2,500 psi and annular to 2,500 psi. 3. Pull blanking plug & BPV. Screw in landing joint, BOLDS's, and pull tbg hgr to the rig floor. 4. POOH laying down 2-7/8" tubing. 5. RIH on DP and fish tubing stub and seals. 6. RIH on DP and fish Baker FHL packer. 7. RIH on DP and fish tubing stub and seals. 8. RIH on DP and fish Carrico HRP -I -SP packer. 9. Perform a production casing clean out run to perforations. 10. RIH with 3-1/2" single packer completion. 11. RU E -Line and correlate packer depth to ensure set depth is accurate. RD E -Line. 12. Move packer depth if needed. Drop a B&R. Pressure up tubing to set packer. 13. Shear out of PBR. Space out and MU tubing hanger. Circulate corrosion inhibited fluid in the IA. Land the tubing hanger, RILDS. 14. PT the tubing. Hold pressure on tubing and pressure test IA and chart. Bleed tubing pressure quickly to shear the SOV. 15. Pull the landing joint, install BPV. 16. ND BOPE. NU tree. Pull BPV and install tree test plug. Test tree and pull test plug. 17. Freeze protect well with diesel. Set BPV. 18. RDMO. Post -Rig Work 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline. Pull SOV, ball & rod and run GLD. 4. Handoff to operations to put back on production. 3Q-11 Proposed RWO Schematic 116" 62# H-40 1 shoe (a) 115' MD r-5/8" 36# J-55 shoe 3808' MD Back Up Proposed KOP @ 6920' MD C4 -sand perfs 6928' - 6942' MD A -sand perfs 6946' - 6964' MD , 6970'- 7000' MD 7" 26# J-55 shoe @ 7240' MD 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrels @ TBD PBR xxxx' MD (3" ID) FHL Packer @ XXXX' MD (4.0" ID) 3-1/2" X -Nipple @ TBD (2.813" ID) Northern Solutions WEDGE (KOP @ 6920' and 6940') Northern Solutions Wedge * 3-1/2" 9.3# L-80 Base Pipe * 5.905" OD (12.9' long) * —23.14' Total Length * 0.625" Bore thru Lipper Tray * 1.125" Bore thru Lower Section * HES 2.81"X Nipple below KUP PROD WELLNAME 3Q-11 C^noc o(r�rh E'er 1, �" Wall Attributes �N`O" ''I'II� ._Name W¢porcAWUVfl Wa NeSka.lnc KGPgRGK RIVER UNIT 50029216]60 NIPPLE WO'. WELLBORE 3Q-11 aa-+1.snrzpre,po9.2oud Last Tag Vv 1xnmovc(ads) Avided- based Mid 1 End pale wNlOve LaslMWBv Last Tag: SLM 6955.0 82112011 30-11 ninam HAeoER ma"_- Last Rev Reason Arhediion End pale W¢Ilbon tad Made, Rev Reason Puled OV 85eI DV 5/82019 30-11 Izedrddadq Casing Strings Casing Description jobbed Ii Top lnka)4ed pep_1111(el Sed Depth BvD)- WULen il_.Ande Top Tnreed CONDUCTOR 16 1BOfi 40.0 115.0 115.0 6250 H-40 Casing Deicripryon Kid Ip lint Top 1.)Sed hepar Me) sed Oeph mpl_. wutmg...Orwe Top TMatl 10 9518 8.76 37.0 3,808.0 3]30.5 36.00 J-55 BTC Calnp paaerlpd- OD lin) Ip pn1 Top lMte) SN pepM nlKBI SN DepM mD)... WOLen p... --a Top TMw] TSURFACE PRODUCTION 7 628 35.5 ],239.] 68063 2600 J-55 BTC Tubing Strings Tuae. oe:c,ipnon some de-mOn) rap)tike) se, Depth ha Deep BEER ..1 Grade Tapeonoead. CON.L.Too 40.o.nao JW TUBING 2]/8 244 20.6 6,778.8 6,209.9 6.50 L-80 EUE6rDMOD Completion Details ,P(,D1 mpm¢I _aminal NIABLE )e2lp M TOP ME) Irel 19 gem 0¢e Cam to jub 20.6 20.6 004 HANGER TU B ING HANGER 2.441 5249 5249 064 NIPPLE XLANDING Nipple 2.313 6,661.6 61098 31.58 PBR Baker PER 8032 2.9M 6,675.6 6.1217 31.52 PACKER Baker Pecker FHL 47B2-7' 264 2.992 OAS LIFT; g,510.4 6,7282 6,1666 31 23NIPPLE XN Nipple L-80812.313 2.2% 6.]7]2 6,208.5 30.92 OVERSHOT Baker POOR BOY OVERSHOT 4.75"X2.875" 2,990 sDRFACE; noa,m>a Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Had (WO) Tag Nal Top M E) DISK) V) pn Com Ban Cape In (in) 6,7238 6.162.8 31.25 Catcher Catcher on top MN audit 50'x .9 G172019 DOM ons un: ae.za 1.813" G FM) 6,]28.0 6,166.4 31.M XXN Plug Bet 3.31' XXN plug 4l"DAL 411&2019 O.OW ],001.0 6,401.1 30.52 FISH JUNK BRIO Ein CSG 5'oud of TBG Tailo mrsc. rynk- 925tl992 peri Charge, teflon ring - III iidentifiable. BREWED 9/25192 .sEL'at2ae ],003.0 6402.8 0.53 FISH CATCHER SUB 2.27"X24"C H U IN 42W006 RATHOLE 4122/2006 Perforations & Slots Cape EASUFT:6.1447 TOpnVD) kdknHVDI (motrM Topuffli BMIMte) take) (Mta) L'sess Z.ne Date I ryge Cem 61 ,9420 6.3382 6,350.3 C4,A-3,30-11 42411990 6.0 APERF Ope9-0h; 1 "Sv,p Gun 6,9480 6.964.0 6,353] 6,3692 A-2,30-11 42411990 6.0 APERF 6Nil ph, 1rE"Strip Gun ,9]0.0 7,000.0 I 63]44 I 64002 q-1,30-11 3lL1987 40 /PERF It tai Passing; 2 H8 "EJ os LIFT; aem.e Mandrel Inserts go oYo Top(MfB) Tep mq MIS valve raeh Pages, Tiro Run me. Madel Op(a) sery ryce Type (In) Usti) Run pate Com 1 25108 2.5107 CAMCO KBMG 1 GAS LIFT GLV BK -5 0.156 1,290T 1 521109 PER; eed s 2 BACKER Sides- 3,84].3 3.7636 CAMCO SEMI GAS LIFT GLV BK -5 0.156 1,289.0 1 2 0 3 5,13.8 4.823.0 CASCO KBM - 1 GAS LIFT GLV BK -5 BASS 1,3 4. 1 2 4 6,144,7 5,6744 CAMCO KBMG- 1 GAS LIFT GLV BK -5 :Lim 1,317.0 1 512009 2 c xnm:e,7ae 5 7.8 6,0639 CASCO KBMG- 1 GASLfii DV BTM 0.000 0.0 51812019 2 Notes: General & Safety NIPPLE; B,Ti9.2 End Date I Agrest n .NPlg5T2aa 411 NOTE D NIPPLE HAS BEEN MILLED, 50GGEST NOT USING IT 422-06 D 009 NOTE: VIEW SCHEMATIC eadiska Sc6ema0CB.0 OVERSHOT', 9,]11.2 APERF;59al.peIL APERF, 6996,e9,%e.0� IPERF:6.db-TD]0.0---- FISH;T,O]10 F19N', 7.0030 PRODUCTION: 35. ILTM7 ~ ~ . • ConocoPh i I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Ju1y 18, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage AK 99501 ~r (~r ' r~ra`~~i~~~u~~`c ~ ~ ~~j~ 'n` ~l1Li`; .wa'~~+ 4~ ~ Dear Mr. Maunder: • ~ '" ~^~ ~ ` ,~v ~ ~ ` , ~~ ~ Enclosed please find a spreadsheet with a list of wells from the Kupanak field (KRi~. 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 annulax space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the lreatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 26~', 2009. The corrosion inhibitor/sealant was pumped June 30~' & July 16~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. ~ Please ca11 MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. 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 7/18/09 3H, 31 ~ 3Q PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft ~ al 31-07 500292154900 1860390 3' NA 3' NA 8.92 7/16/2009 3H-04 501032007600 1870760 30" NA 30" NA 13.6 7/16/2009 3H-08 501032008000 1870800 17" NA 17" NA 3.4 7/16/2009 3H-11 501032009100 1871240 27'.' NA 27" NA 6.37 7/16/2009 3H-19 501032009000 1871330 17" NA 17" NA 5.95 7/16/2009 3H-21 501032009400 1880080 8" NA 8" NA 1.27 7/16/2009 3H-23A 501032020401 1961860 6" NA 6" NP, 1.27 ~ 7/16/2009 3H-24 50103202350U 1960150 6" NA 6" NA 1.27 7/16/2009 3H-31 501032020500 1940190 13" NA 13" NA ~ 2.97 7/16/2009 3H-33 501032057800 2081130 19" NA 19" NA 5.52 7/16/2009 3Q-03 500292222100 1911260 SF NA 5" NA 0.9 6/30/2009 3Q-06 500292168300 1861950 43' 6.30 26" 6/26/2009 6.8 6/30/2009 3Q-08A 500292168101 1971930 SF NA 6" NA 1 6/30/2009 3Q-09 500292167400 1861860 SF NA 6" NA 1 6/30/2009 3Q-10 500292167500 1861870 15' 2.50 18" 6l26/2009 6.8 6/30/2009 3Q-11 500292167600 1861880 37' 4.30 23" 6/26/2009 7 6/30/2009 3Q-14 500292166500 1861770 46' 5.10 23" 6/26/2009 7 6/30/2009 3Q-22 500292262500 1951860 SF NA 19" 6/26/2009 6 6/30/2009 ~ ~ ~ ~ ~OnoCOPh~ll~p5 January 29, 2008 T. Maunder State of Alaska Alaska Oii & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 • J. Eggemeyer Engineering Leader Drilling & Welis P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6049 3 ~~ ~:~ ~~` ~ ~~,~ ~ ~r ~ a ' t~C~f 1A' ~ ,~ t~~i~ ,~ ~ ~ ~v~r~a ~,~c~~i~~iA~ ;~~,1~,~~~ ~'~ ~ t~~~ r~~~ ~n~~~ . ~~~-~,~~ Subject: Additional Well Summaries 3~~ ~ 1 Dear Mr. Maunder: ~ ~ ~ ~~~~~ ~~ ~~~ ConocoPhillips Alaska, Inc. submits the attached well summaries for wells 3Q-11, 1 J-137, 1 C-104, 1 E-29, 1 J-176, 1 J-176L1, 1 J-107 and 1 J-107L1 you reque~ s~ed'.'- These summaries will replace the shorter summaries already submitted with the completion reports for these wells. If you have any questions regarding this matter, please contact me at 265-6049. Sincerely, ~ ~ . Eggemeyer Engineering Team Leader CPAI Drilling JE/skad ~ ~~~,.~= AU G ~ ~ ~~G~ k~' ~,~N/ ~ J i 1 Page 1 of 1 ~ ~ Maunder, Thomas E (~OA) From: Eggemeyer, Jerome C. [Jerome.C.Eggemeyer@conocaphiliips.ec>m] Sent: Wednesday, December 12, 2007 9:46 AM To: Maunder, Thomas E (a0A} Subject: RE: ~etaifed Reports Requests the first package is leaving this morning, we will get these items together aiso. jce From: Maunder, Thomas E (DOA} [mailto:tom.maunder@alaska.gov] Sent: Wednesday, December 12, 20Q7 9.3Q AM To: Eggemeyer, Jerome C. Su6ject: Detailed Reparts Requests Jerome, Further to our discussions, would you pfease provide the detailed aperations reparts for the foltowing wel! (s)/aperations. .~~J,-_137 206- Warkover begun 10t15l07 -~, 3Q-11 (186-188} Workover begun 09!(37l07, nan-rig work summary provideti is sufficient. Thanks in advance. Caft or message with any questions. Tam Maunder, PE AOGCC 12/12/2007 ~ ~ RECEf~/ED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION OCT ~ 7 ZOO~ 1. Operations Performed: Abandon ^ Repaif Well ^~ ~ Plug Perforations ~ Stimul8te ~ Other n rage Alter Casing ^ Pull Tubing ~ . Pertorate New Pooi ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Weli ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ~~ Exploratory ^ 186-188 /~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-21676-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 60' / 3Q-11 ~ 8. Property Designation: 10. Field/Pool(s): ADL 25512, ALK 2553 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7272' feet true vertical 6634' ' feet Plugs (measured) Effective Depth measured 6968' feet Junk (measured) 7001', 7003' true vertical 6373' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUR. CASING 3748' 9-5/8" 3808' 3730' PROD. CASING 7180' 7" 7240' 6607' Perforation depth: Measured depth: 6928'-6942', 6946'-6964', 6970'-7000' true vertical depth: 6338'-6350', 6354'-6369', 6374'-6400' Tubing (size, grade, and measured depth) 2_7/g~~, L-80, 6845' MD . Packers & SSSV (type & measured depth) pkr- Otis FHL, Camco HRP-1-SP pkr- 6678', 6814' Camco x nipple @ 525' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packe~ ~ Title Wells Group Engineer ~~f rb ~~ ~ ' L~`" `-- Signature -';G Phone:265-6845 Date %" Pre red b haro Allsu -Drake 263-4612 ~ ........ ..._ . .~,. ./~.~. ~~ ~G.~~ Form 10-404 Revised 04/2006 Q R i G I N A L -~~~~ uF~n" ~' 10Q~ Submit Ori i~~l/~~~ .~ REPORT OF SUNDRY WELL OPERATION~~aska Oi1 & Gas Cons. C • 3Q-11 Well Events • DATE Summary 6/29/07 TAGGED AT 7017' RKB, EST 17' RATHOLE. MEASURED BHP @ 6965' RKB: 3952 psi. IN PROGRESS. 6/30/07 ATTEMPTED LOCK OUT SSSV, NO SUCCESS. ATTEMPTED FUNCTION CHECK SSSV, NO SUCCESS. SSSV APPARENTLY STUCK OPEN, POSSIBLY DUE TO SCALE, POSSIBLY SCLEROTIC AFTER 21 YEARS. DRIFTED TO 6832' RKB WITH 11' x 2-1/8" STEM. 7/5/07 PRE RWO POT & PPPOT-T & IC PASSED, FUNCTION TESTED LDS (ALL MOVED FREELY), MITOA PASSED 7/8/07 STRING SHOT TUBING WITH SINGLE STRAND FROM 6760-6772'. SET BAKER 1-11/16" IBP MID-ELEMENT AT 6826' BETWEEN THE CAMCO 'HRP- 1-SP' PACKER AND THE D-NIP. LOGS CORRELATED TO TUBING TALLY. LRS RETURNED FOLLOWING MORNING AND CMIT PASSED. 7/11/07 CMIT Tx IA - PASSED (PRE-RWO). 7/21/07 TESTED IBP 2500 PSI FOR 30 MIN, G004. DUMP BAILED 5' CaC03 ON IBP. TAGGED TOP OF CaC03 PLUG @ 6790' SLM. COMPLETE. 7/26/07 2-1/8" CHEMICAL CUT AT 6770' (FIRST FULL JOINT ABOVE OEJ). CIRCULATED WELL (230 BBL) TO 9.6-LB SODIUM CHLORIDE BRINE. 9/7/07 Continue to RD and move rig from 1A to 3Q. Rig left 1A @ 23:00 hrs. 9/8/07 MIRU 9/9/07 Pooh w/original 2 7/8" completion recovered all 31 ss bands. P/u and Rih w/ New 2 7/8 Prod Completion 9/10/07 Finish Completion and move rig to 1 E-29 Rig released @ 22:00 hrs 9/15/07 PULLED BALL & ROD AND RHC PLUG FROM 6728' RKB. PULLED SOV @ 6607' RKB AND SET DV. MIT'D CSG 2500 PSI, GOOD. PULLED DV AND SET OV @ 5123' RKB. PULLED DV AND SET GLV @ 2510' RKB. BAILED FILL @ 6803' RKB. IN PROGRESS. 9/16/07 BAILED FILL FROM 6803' TO 6830' RKB. TAGGED IBP WITH 1-3/4" LIB @ 6830' RKB. IN PROGRESS. 9/17/07 BAILED FILL OFF IBP @ 6830' RKB & PULLED SAME. COMLETE. 9/20/07 GAUGED TBG TO 2.13' ; TAGGED @ 6968' SLM. NO SAMPLE. MEASURED BHP @ 6936' RKB: 3874 psi. COMPLETE. Cc~nc~ca-Phillips Time Log Summary ~,~ We!lurew N/eb Reporting I Well Name: 3Q-11 Job Type: RECOMPLETION ~9/07/2007 16:30 00:00 7.50 MOVE MOB P Finish rigging down off 1A and move ri to 3Q. 09/08/2007 00:00 03:15 3.25 MOVE P Arrive on location @ 03:15. Begin s ottin cam and ri . 03:15 16:00 12.75 WELC NUND P Rig accepted @ 12:00 hrs. Hold pre-WO meeting w/ crew. Pull BPV, ND tree and NU BOPE. MIRU tiger tank, hard line. Had to wait for tiger tank due to truck availability. Prepare to contact AOGCC for BOP test. 16:00 00:00 8.00 WELC BOPE P NU BOP. Perform BOP test to 250/3500. State witness waived by Chuck Sheavy @ 16:55 on 9/8/07 per hone call. 09/09/2007 00:00 02:30 2.50 WELCT BOPE P Finish BOP Test & Blow down lines. 02:30 0630 4.00 RPCOti CIRC P R/U & Pull BPV. Unland tbg hanger @ 35k and pull to 80k & part tbg @ cut @ 6770' w/ string wt of 45k. Circ 10 bbls. to Tiger Tank. and continue to circ 2 hole vol of 400 bbls to pits w/ 9.6 brine. 06:30 16:30 10.00 RPCO PULD P Pull hanger to floor. 52K up WT 43K DWN WT. Rig up HES for control line disposal. Beging pulling tubing OOH. Collect 31 SS Bands. Continue to POOH la in sonw sidewa s. 16:30 00:00 7.50 RPCOti RCST P P/U and M/U New 2 7/8 L-80 6.5# Prod BHA and Rih inserting GLM in Calc lacin s 09/10/2007 00:00 08:00 8.00 RPCOti RCST P Continue to Rih w/ new 2 7/8 Completion inserting GLM @ desired de ths. 08:00 13:00 5.00 RPCO HOSO P Tag tubing chemical cut. Shear tattle tail pins space out PBOS 1' As per proceedure. Up WT 54K. DWN WT = 44K. Blook Hook WT = 10K. Drop Ball & rod 1 3/4" Fish neck 6'8" OAL. Set Baker FHL PKR 2,600 PSI. Shear out PBR @ 74K. Bleed off tubing pressure. Space out for pup joint installation. Land hanger. SET BPV. Prep for NDNU. 13:00 13:30 0.50 RPCOh SFTY P Pre-job safety meet due to change of sco~e. . . WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Howard Okland 333 West 7th Avenue Suite 1 00 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 attention of : ProActive Diagnostic Services. Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage. AK 99518 Fax: (907) 245-8951 1) 1 BL / EDE Disk 2) 3) 4) 5) 6) 7) 3Q -11 13 - Oct - 06 Caliper Report (; 't"l'.l Mþ.lr'¡'! ê\'o?n" >cnfj¡t,;[ì) ~iS Signed: (~~~ Date : OCT 2 4 r<' Print Name: éjJ1 (,~t\ ..L{( f)ì r;.L 'A1L+',v¡ PRoAcTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL: ?DSANCHORAGE{Wr.¡lEMORYLOG.(::Oi\ij I~ 115(, - i'"6?r" WEBSITE: 'J'PJI.J1N.MEi'i10RYLOG.COiVl D:\OO _ PDSA!,C-2006\Z _ W ordlDistribution\TransmittaC Sheets\Transmit_ Original.doc 1:1. 1"[ q;). I I I I I I I I I I I I I I I I I I I . . Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. October 13, 2006 8059 1 2.875" 6.5 lb. L-80 EUE 8RD AB Mod Tubing Well: Field: state: API No.: Top Log IntvI1.: Bot. Log I ntvl1. : 3Q-11 Kuparuk Alaska 50-029-21676-00 Surface 6,846 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into the end of the tubing tail @ 6,845' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 2.875" tubing appears to range from good to poor condition. A possible hole is recorded in joint 195 (6,236'). A 33% wall penetration is recorded in joints 173 (5,548') and 207 (6,643'). Wall penetrations from 20% to 29% are recorded intermittently throughout the remainder of the tubing. The damage appears in the form of isolated pitting with a few areas of general corrosion. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate buckled tubing from below GLM station 3 (-5,100') to the bottom of the 2.875" tubing. This log was run with a dual too/ string comprised of a 24-arm caliper and magnetic thickness tool. Unfortunately, the data from the magnetic thickness too/ is not interpretable. MAXIMUM RECORDED WALL PENETRATIONS: Possible Hole Isolated Pitting Isolated Pitting Isolated Pitting Corrosion 6,236 Ft. (MD) 5,548 Ft. (MD) 6,643 Ft. (MD) 6,107 Ft. (MD) 4,757 Ft. (MD) Jt. Jt. Jt. Jt. Jt. 195 @ 173 @ 207 @ 191 @ 149 @ ( 71%) ( 33%) ( 33%) ( 29%) ( 23%) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 13%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. RECEIVEr OCT 2 4 2ûOfi ....()it & Gas CoM, Go.mn)I$~¡(;i Afd¡orage I Field Engineer: R. A. Richey Analyst: M. Lawrence Witness: C. Fitzpatrick J 1f(µ - J "61> :t:t" /41t1d I Correlation of Recorded Damage to Borehole Profile I Pipe 1 2.875 in (49.4' - 6844.3') Well: Field: Company: Country: Survey Date: 3Q-11 Kuparuk ConocoPhiÐips Alaska, Ine. USA October 13, 2006 I I I Approx. Tool Deviation Approx. Borehole Profile I 75 49 I 25 792 I 50 1585 I GlM 1 2400 I 100 3196 0 '- :E () ..Q .,.; E I..L... ::::; C Z .J:: ... 125 3989 11. GlM 2 .£: () 0 150 4787 GlM 3 GlM 4 175 5589 GlM 5 GlM 6 200 6395 GlM 7 I I I I I 211.7 o 6844 100 50 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Su rvey = 211.7 I I I I I Well: Field: Company: Country: 3Q-11 Kuparuk ConocoPhillips Alaska, Ine. USA I Tubing: Nom.GD 2.875 ins Weight 6.5 f Grade & Thread LoBO WE 8rd I Penetration and Metal loss ('Yo wail) I metal loss body I 150 100 I 50 ~ o to 1% 10 to 20 to 40 to over 20% 40% 85% 85% 1 to 10% I o o pene. loss I I Damage Configuration ( body) 60 I 40 I 20 o I isolated general line ring hole / pass pitting corroSIon corrosìon corrosion ¡ble hole I o I I PDS Report Overview Body Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Nom.ID 2.441 ins October 13,2006 MFC UW 24 No. 211387 1.69 24 M. Lawrence Nom. Upset 2.875 ins Upper len. 1.2 ins lower len. 1.2 ins Damage Profile ('Yo wall) penetration body o 1 GlM 1 GlM 2 GlM 3 GlM4 GlM 5 GlM6 GlM 7 metal loss body 50 100 Bottom of Survey 211.7 Analysis Overview page 2 I I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: Nominal ID.: 2.875 in 6.5 ppf [-80 EUE 8rd 0.217 in 0.217 in 2.441 in Well: Eield: Company: Country: Survey Date: 3Q-11 Kuparuk ConocoPhillips Alaska, Inc. USA October 13, 2006 I Joint J t. Depth Pen Pen. F\.TJ Mc' I;] I Min. Damag e Profile No. (Et) Body 1.0. Comments (% wall) ) (Ins.) (Ins.) 0 50 100 1 49 n 0.Q1 3 (j 2.41 2 62 0.02 II I 2.41 3 93 0.03 12 ;> 2.43 4 125 0.03 I Ii 2.41 5 157 ( 0.03 1 n 2.41 6 189 ( 0.Q1 n 3 2.42 I 7 220 l 0.04 I j 2.41 Shallow oitbm?:. 8 252 0 0.03 14 2.41 9 284 Ii 0.Q1 4 2.41 10 315 n 0.03 12 2.40 11 347 n 0.02 13 2.41 12 379 (1 0.Q1 6 2.41 13 411 0 0.02 10 3 2.42 14 442 0 0.02 11 2 2.41 15 474 0 0.02 13 2.41 16 506 I 0.Q1 6 2.41 17 539 0.02 ml 2.40 18 570 1 0.03 2.41 19 601 1 0.02 10 2.40 20 633 ( 0.03 (3 4 2.41 21 665 Ii 0.02 Iii I 2.42 22 698 0 0.02 9 6 2.41 23 729 0 0.02 11 7 2.39 24 760 0 0.03 16 11 2.40 Shallow oitting. [t Deposits. 1, 25 792 Ii 0.03 12 6 2.40 26 824 0 0.02 ß 2 2.40 27 855 0 0.Q1 ( 11 2.41 ~ 28 888 l 0.04 20 ß 2.39 Isolated pitting. Lt Deoosits. 29 9'19 0 0.02 ( 2.41 30 951 0 0.03 15 2.38 Shallow oitting. 31 982 (I 0.02 9 2.41 32 1014 0 0.Q1 6 2.40 33 1046 0 0.02 11 2 2.40 34 1077 0 0.02 3 2.40 35 1109 0 0.02 0 3 2.40 36 1141 0 0.02 ¡ 2.40 37 1173 0 0.02 I 2.40 38 1205 0 0.02 1 2.38 39 1237 n 0.02 1 2.39 40 1268 0 0.02 n 2.40 ¡tit 41 1300 1)0', 0.03 1 2.39 Pitting in upset ¡tit 42 1332 () 0.02 ) I 2.39 I!£I 43 1364 0 0.03 1 2.39 44 1395 0 0.03 I 2.40 ~ 45 1427 0 0.03 I 2.40 Shallow pitting. 46 1459 0 0.03 L 2.39 47 1491 0 0.03 13 2.39 48 1522 U 0.02 II 4 2.40 49 1554 0 0.02 11 3 2.40 II 50 1585 0 0.04 17 )) 2.40 Shallow oitbng. I I I I I I I I I I I I Body Metal Loss Body Page 1 I I I PDS REPORT INT TABULATION SHEET I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 2.875 in 6.5 ppf L-80 EUE 8rd 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-11 Kuparuk ConocoPhillips Alaska, Ine. USA October 13, 2006 I I Joint JL Depth F\ Pen. F'e \'1etal Min. Damag e Profile No. (Ft.) '1 Body 1.0. Comments (% wall) (Ins) (Ins.) (Ins.) 0 50 100 51 I 1617 0 0.03 12 (, 2.38 52 I 1649 () 0.02 11 2 2.38 53 1681 0 0.03 12 :> 2.39 54 1713 I n 0.04 I :¡ 2.38 Shallow aitlin\!:. 55 1744 II 0.03 1 lli38 Shallow oitlim:¡;. Lt. Deposits. 55.1 1776 () 0.ü1 .38 PUP 55.2 1786 0 0 i o 2.31 SSSV 56 1798 0 0.04 I J 2.37 Shallow nitlinQ. 57 1829 ( 0.03 15 3 2.38 Shallow aitlim;¡. 58 1861 I 0.02 I '1 2.39 59 1893 0.03 12 4 2.39 60 hO 0.05 2 ¡ -I 2.39 Isolated Dittinl!:. Lt. DeDosits. 61 1 n 0.02 1 2.38 62 1988 0 0.03 ¡ 2.38 63 2020 () 0.03 2.38 64 I 2052 0 0.04 2.40 Shallow nitling. It. Deaosits. 65 2083 00(, 0.03 P 2.38 Pittìm! in uo<;et. 66 2115 0 0.03 2.38 Shallow oitlinQ. 67 2147 0 0.02 10 4 2.39 68 2178 0 0.04 17 2.38 Shallow corrosion. 69 2210 I) 0.02 10 2.38 70 2242 0 0.03 14 2.39 71 2273 0 0.02 11 2.39 72 2305 0.05 0.03 14 3 2.38 Pittim2 in uoset. 73 2337 I 0.03 15 5 2.38 Shallow corrosion. 74 2369 I 0.05 2 11 2.40 Corrosion. 75 2400 I 0.02 t 1 4 2.38 76 2432 0.02 tn I 2.40 77 2464 0.02 W :> 2.39 78 2493 n 0.03 15 (, 2.38 Shallow aitlinQ. Lt. DeDosits. 78.1 2524 n 0 n n N/A GlM 1 (No Deviation) 79 2531 n 0.04 17 7 2.39 Shallow DitlinQ. 80 2562 n 0.03 "¡ , 2.39 Shallow corrosion. 81 2594 0.02 1 2.38 =It 82 2626 0.04 1 I 2.38 Shallow Ditling. 83 2657 I 0.04 1 2.36 Shallow pitting. U. Deposits. 84 2689 0.03 I 2.40 85 2721 0 0.02 11 4 2.39 86 2752 IJ 0.03 is 6 2.40 Shallow aitlim;¡. It. Deoosits. 87 2784 I) 0.04 1n 9 2.40 Shallow oitting. 88 2816 n 0.03 3 2.39 89 2848 ¡!iF 0.03 4 2.37 Pitting in uoset. 90 2879 II 0.02 I 2.38 91 2911 II 0.04 11 2.38 Shallow corrosion. 92 2942 II 0.02 1 2 2.41 93 2974 IJ 0.03 ¡ 7 2.39 94 3005 n 0.03 I , 2.40 95 3037 n 0.03 1 2.41 96 3069 n 0.02 1 2.39 97 3101 0 0.03 1 2.38 I I I I I I II I I I I Penetration Body Metal loss Body Page 2 I I I PDS REPORT JOINT TABU ONSH I I Pipe: Body Wall: Upset Wall: Nominal ID.: 2.875 in 6.5 ppf l-80 EUE 8rd 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-ll Kuparuk ConocoPhiDips Alaska, Ine. USA October 13, 2006 I I Joint J L Depth Per Pen. Perr P¡leldl Min. Damage Profile No. (Ft.) (::::r;, Body 1.0. Comments (%wall) (Ins.) (ins.) 0 50 100 98 3133 0 0.03 13 7 2.38 99 3165 0 0.D3 tl4 4 2.38 Shallow oit1imL 100 3196 (J 0.03 5 6 2.38 Shallow oitûm<:. 101 3229 \) 0.0313 6 2.38 102 3260 0 0.02 1 2.39 103 3292 0 0.03 Ie I 2.38 Shallow nitûnQ. 104 3323 0 0.D3 1 2.38 Shallow nitûm!:. 105 3355 ) 0.04 í 2.38 Shallow corrosion. 106 3387 0 0.02 11 2.39 sits. 107 3419 ) 0.D3 12 2.38 It. Deoosits. 108 3450 ( 0.D3 12 7 2.39 109 3481 ( 0.D3 12 6 2.39 I 110 3513 0 0.04 113 6 2.38 Shallow corrosion. 111 3545 0.05 0.D3 I IJ 2.37 Lt. Deoosits. PittinQ in unset. 112 3576 0 0.04 F r 2.38 Shallow oitûnQ. 113 3608 \) 0.D3 ¡ I CI 2.39 114 3640 \) 0.04 I 2.39 Shallow corrosion. 115 3672 \) 0.02 II 2.38 116 3704 0 0.02 11 2 2.39 117 3735 \) 0.03 13 ::; 2.39 118 3767 \) 0.02 11 2.38 119 3798 \) 0.03 17 HJ 2.38 120 3830 \) 002~ 2.39 121 3862 \) 0.02 5 2.39 122 3894 ( 0.03 ! 2.39 123 3924 0 0.021Ö 2 2.38 124 3957 \) 0.D3 m 7.40 125 3989 \) 0.03 2.40 Shallow oitûnQ. 126 4020 0.D3 2.38 Shallow oitûnll. 127 4052 I 0.D3 12 7 2.40 128 4085 I 0.03 15 2 2.39 Shallow oitûmL 129 4116 0.02 10 3 2.40 130 4149 0 0.D3 \6 () 2.37 Shallow oitûm<:. 130.1 4180 \) 0 0 (1 N/A GlM 2 (latch @ 3:30) 131 4187 \) 0.04 1 (', 2.36 Shallow corrosion. 132 4218 \) 0.D3 I ;; 2.38 It. Deoosits. 133 4250 0 0.03 1 I 2.39 134 4281 0 0.04 H ß 2.38 Line shallow corrosion. U. Deoosits. 135 4313 0 0.D3 1 6 2.38 136 4344 &6 ß 2.38 Shallow oitûm<:. 137 4376 \) 0.D3 I 2.39 138 4407 0 0.021 2.40 139 4440 \) 0.03 I 2.38 140 4471 \) 0.04 21 2.38 Isolated oittim<:. 141 4503 0 0.D3 I 2.38 Shallow oitûm1:. 142 4534 \) 0.03 13 2.37 143 4566 \) 0.03 1 I 2.38 144 4598 \) 0.D3 í 4 2.38 Lt. Deoosits. !II 145 4629 0 0.03 1 6 2.38 r 146 4661 0 0.03 1 7 2.38 . I I I I I I I I I I I I Penetration Body Metal loss Body Page 3 I I I PDS REPORT JOINT TABULATION SH I I Pipe: Body Wall: Upset Wall: Nominal '-D.: 2.875 in 6.5 ppf L-80 EUE 8rd 0.217 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-ll Kuparuk ConomPhillips Alaska, Inc. USA October 13, 2006 I I Joint Jr. Depth Pe Pen. Pen. (/Ie ta I Min. Damage Profile No. (Ft.) 'I Body I.D. Comments (%w all) (Ins.) (Ins.) 0 50 100 147 4693 n 0.02 10 h 2.39 148 4724 0 0.04 II 7 2.38 Shallow mrrosion. 149 4755 iJ 0.05 2 'j 2.36 Corrosion. Lt. Demsits. 150 4787 n 0.D3 1 (, 2.39 Shallow nitting. 151 4820 0.04 :; 6 2.39 Isolated nitting. 152 4851 0.02 1 2.38 153 4883 t 0.03 1 2.37 154 4915 t 0.02 H 2.39 155 4946 ( 0.D3 ¡ 2.39 156 4977 0 0.D3 I 2.39 157 5010 () 0.02 11 4 2.38 158 5042 U 0.02 ¡ 'S 2.37 159 5074 n 0.D3 1 " 2.37 159.1 5105 iJ 0 () N/A GlM 3 (latch @ 130ì 160 5112 U 0.03 4 7 2.37 Bucklina. 161 5142 U 0.04 ') 2.38 Shallow corrosion. Lt. De oosits. 111 162 5175 0 0.D3 15 H 2.36 Shallow mrrosion. Lt. Demsits. " 163 5206 0.02 II 1 2.38 164 5238 0.02 11 2 2.39 Buckling. 165 5268 I 0.03 14 4 2.39 166 5298 1 0.02 11 1 2.36 Buckling. 167 5328 U 0.02 1 I 2.38 168 5360 0 0.02 1 4 2.38 Buckling. 169 5392 0 0.D3 12 ') 2.39 ~ 5424 () 0.02 > 2.40 Buckling. ~ 171 5456 0 0.05 2.38 Isolated nittinQ 172 5488 0 0.03 2.38 BucklimL 172.1 5519 0 0 I N/A GlM 4 (latch @ 8:30) 173 5526 0 0.ü7 2.37 Isolated nittim!. 174 5558 0 0.D3 15 h 2.39 Shallow oittim!. 175 5589 0 0.D3 12 2 2.35 Bucklina. 176 5621 0 0.01 7 I 2.38 Buckling. 177 5652 () 0.02 2 2.38 Buckling. 178 5684 () 0.03 6 2.37 Buckling. 179 5716 0 0.03 ) 2.38 Buckling. 180 5748 () 0.02 I 2.39 Buckling. 181 5779 U 0.04 ) 2.37 Isolated r)ittÍl12. 182 5811 0 0.D3 12 )' 2.39 Buckling. 183 5843 0 0.02 ) 2.35 Buckling. 184- 5875 n 0.02 2 2.38 BucklinQ. 185 5907 I) 0.01 2 2.38 Buckling. 185.1 5938 0 0 t 0 N/A GlM 5 (latch @ 3:30) 186 5945 0 0.04 19 ) 2.36 Shallow nittina. 187 5977 ( 0.D3 15 S 2.37 Shallow nitling. Buckling. 188 6008 0 0.D3 2.38 Shallow nitling. 189 6040 o on 0.05 2 2.40 Isolated nitting. 190 6072 0 0.04 1 2.38 Shallow nitlin;;!. 191 6104 0 0.06 2.36 Isolated oittim!. 192 6136 IJ06 0.03 I 2.38 Pitting in unset. Bucklin\:!. 193 6167 0 0.04 17 1 2.38 Shallow nitling. I I I I I I I I I I I I Penetration Body Metal Loss Body Page 4 I I I I PDS REPORT JOINT TABU ON SH I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 2.875 in 6.5 ppf 1.-80 fUE 8rd 0.21 7 in 0.217 in 2.441 in Well: Field: Company: Country: Survey Date: 3Q-11 Kuparuk ConocoPhillips Alaska, Ine. USA October 13, 2006 I Joint )t. Depth P"n. Pen. Pen. 1\1\('1al Min. Damag e Profile No. (Ft.) Body (¡SS 1.0. Comments (% wall) (Ins.) (Ins.) 0 50 100 194 6198 0 0.04 HI 4 2.38 Shallow pitting. - 195 6230 0 0.15 71 4 2.37 Isol<1ted pitting, 196 6263 0 0.03 12 ! 2.37 Lt. Deoosits. Bucklin\!. 197 6293 0 0.ü2 10 j 2.35 BucklinlZ. 197.1 6326 0 0 C 0 N/A GLM 6 (Latch @ 7:30\ 198 6332 () 0.04 1 2 2.37 Shallow pittin\!. 199 6364 0 0.02 ¿¡ 2 2.39 Buckling. 200 6395 () 0.03 1 e; ¡¡ 2.38 Shallow pitting. 201 6426 0 0.02 11 4 2.38 Buckling. I 202 6459 0 0.04 10 4 2.38 Shallow pitting. 203 6490 0 0.02 1 (; 2.37 Lt. Deposits. Bucklin\!. 204 6522 () 0.04 1 5 2.37 Shallow oittim<. Lt. Deoosits. 205 6554 ( 0.04 2 7 2.36 Isolated pitting, Bucklinº. 206 6585 () 0.04 1 II 2.38 Shallow corrosion. Bucklim::1. 207 6617 () 0.07 =if ¡ 2.35 Isolated pitting, Bucklim!. 208 6649 () 0.02 ¡, 2.38 Buckling. 209 6681 () 0.ü2 11 2 2.38 Bucklin\!. 210 6712 () 0.03 1.5 6 2.34 Shallow pittim<. Bucklim<. 210.1 6743 () 0 () C N/A GLM 7 (Latch @ 8:00\ 211 6752 () 0.03 14 17 2.39 Shallow pitting. 211.1 6784 () 0.01 4 2.41 PUP Buckling. 211.2 6793 () 0 () 2.31 PBR 211.3 6813 () 0 () 2.35 PACKER 211.4 6820 I 0.01 4 I 2.40 PUP 211.5 6832 1 0 0 () 2.25 o NIPPLE 211.6 6834 C 0.01 4 1 2.38 PUP 211.7 6844 ( 0 0 () N/A HI. I I I I I I I I Body Metal Loss Body I I I I I Page 5 I I - ----- Well: Field: Company: Country: Tubin : ...... .. .... .. ...... .. - .. P S Report Cross S ons 3Q-11 Kuparuk ConocoPhillips Alaska, Inc. USA 2.875 ins 6.5 f L·80 EUE 8rd October 13, 2006 MFC UW 24 No. 211387 1,69 24 M. Lawrence Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 195 at depth 6236.303 ft Tool speed = 43 t'.JominaIID = 2.441 ,Nominal OD = 2,875 Remaining wall area = 97 % Tool deviation = 36 0 Finger 1 Penetration = 0.153 ins Possible Hole 0.15 ins = 71% Wall Penetration HIGH SIDE UP Cross Sections page 1 - - ---- Well: Field: Company: Count¡y: Tubin : ------- ---- - - PDS Report Cross Sections 3Q-11 Kuparuk ConocoPhillips Alaska, Ine. USA 2.875 ins 6.5 f L-80 EUE 8rd October 13, 2006 MFC UW 24,'\10,211387 1.69 24 M. Lawrence Survey Date: Tool Type: Tool Size: No, of Fingers: Anal st: Cross Section for Joint 207 at depth 6642.923 ft Tool speed = 43 Nominal 10 = 20441 ,\lominal 00 = 2.875 Remaining wall area = 99 % Tool deviation = 32 0 Finger 18 Penetration = 0,071 ins Isolated Pitting 0.07 ins = 33% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ------ Well: Field: Company: Country: Tubin : ------- - - -- - - PDS Report Cross Sections 3Q-ll Kuparuk ConocoPhillips Alaska, Inc. USA 2.875 ins 6.5 f L-80 EUE 8rd October 13, 2006 MFC UW 24 l'iO. 211387 1.69 24 M. Lawrence Survey Date: Tool Type: Tool Size: No. of Fingers: Anal st: Cross Section for Joint 173 at depth 5548.113 ft Tool speed = 43 ,'-!ominaIID = 2.441 Nominal 00 = 2.875 Remaining wall area = 97 % Tool deviation = 38 0 Finger 5 Penetration 0.071 ins Isolated Pitting 0.07 ins = 33% Wall Penetration HIGH SIDE = UP Cross Sections page 3 I KRU 3Q-11 I 30..11 API: 500292167600 Well Type: PROD Angle (j'ì) TS: 31 dea íaJ 6923 SSSV Type: TRDP Orig 12/22/1986 Angle @ TO: 31 deg @ 7272 sssv Completion: (1789-1790, Annular Fluid: LastW/O: Rev Reason: TAG FILL 00:2.875) Reference Log: Ref Log Date: Last Update: 8fl12006 Last Too: 6958 TD: 7272 ftKB ~ate: 7/28/2006 Anale: 36 deg (j'ì) 4800 Gas Lilt I ndrel/Dummy escri!>tion Size Too Bottom TVO Wt Grade Thread Valve 1 CONDUCTOR 16.000 0 115 115 62.50 H-40 (2529-2530, SUR. CASING 9.625 0 3808 3730 36.00 J-55 00:4.750) PROD. CASING 7.000 0 7240 6607 26.00 J-55 Gas Lilt liD'''''''' I ndrel/Dummy Size I Too I Bottom I TVO I Wt I Grade I Thread Valve 2 2.875 I 0 I 6845 I 6267 I 6.50 I L-80 I EUE 8RD AB MOD (4181-4182, 00:4.750) Interval TVO lone Status Ft SPF Date TYDe Comment Gas Lift 6928 - 6942 6338 - 6350 C-4,A-3 14 6 4/24/1990 APERF o deg. ph; 2 118" Strip Gun I ndrel/Dummy 6946 - 6964 6354 - 6369 A-2 18 6 4/24/1990 APERF o dea. Dh; 2 1/8" Strip Gun Valve 3 6970 - 7000 6374 - 6400 A-1 30 4 3fl11987 IPERF o deg. phasing; 2 118" EJ (5105-5106, 00:4.750) St MD TVD Man Man Type V Mfr V Type VOD latch Port IRO Date VIII Gas Lift Mfr Run Cmnt I ndrel/Dummy 1 2529 2529 Merla TMPD DMY 1.0 BK 0.000 0 5/23/2006 Valve 4 2 4181 4045 Merla TMPD DMY 1.0 BK 0.000 0 5/2312006 (5523-5524, 3 5105 4808 Merla TMPD DMY 1.0 BK 0.000 0 5/23/2006 00:4.750) 4 5523 5153 Merla TMPD DMY 1.0 BK 0.000 0 5/23/2006 5 5941 5504 Merla TMPD DMY 1.0 BK-2 0.000 0 1/20/1987 Gas Lift ~828 ",Merla TMPD DMY 1.0 BK-2 0.000 0 8/6/1993 I ndrel/Dummy Valve 5 7 6182 Otis 27/8X1.5 DMY 1.5 RM 0.000 0 1/28/1998 (5941-5942, lCIuhi.etc.l- 00:4.750) Depth TVD TYDe Descriotion ID 1789 1789 SSSV Baker 'FVL' 2.310 Gas Lift 6797 6226 PBR Cameo 'OEJ' 2.312 I ndrellOummy 6814 6240 PKR Cameo 'HRP-1-SP' 2.347 Valve 6 (6328-6329, 6832 6256 NIP Cameo 'D' NIDrne NO GO 2.250 00:4.750) 6844 6266 SOS Cameo 2.441 6845 6267 TTL 2.441 Gas Lift Fish>..F ISH I ndrêI/Dummy DeDth Oescriotion Comment Valve 7 (6746·6747, 6850 JUNK BRIDGE in CSG 5' out of TBG Tail of misc. junk - perf charge, teflon 00:5.460) ring - most identifiable. See WSR 9/25192 6992 CATCHER SUB 2.27" X 24" CATCHER SUB IN RA THOLE 4/22/2006 PBR fiT (6797-6798, Date Note 00:2.875) ~ 4/29/2006 D NIPPLE HAS BEEN MILLED, SUGGEST NOT USING IT 4-22-06 5125/2006 T ubina Leak verified íaJ 5554' 7/18/2006 ADDITIONAL TUBING LEAK FOUND BETWEEN 6228' & 6240' RKB PKR (6814-6815, OD:6.151) NIP (6832-6833, 00:2.875) TUBING (0-€845, OD:2.875, 10:2.441 ) JUNK (685G-6855, 00:6.000) Perf - - f---.-- (6928-6942) -- -- --- f---.-- Perf = l= (6946-6964) ----- - f---.-- -- !-- -- - - -. - --. -- --- Perf - ---- (697G- 7000) -- ---- I I I I I I I I I I I I I I I I I . RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS . OCT 1 {) 2006 Alaska Oil & Gas Cons. Commission 1\ n,..hA"'~' 1. Operations Performed: Abandon D Repair Well 0 Plug Perforations D Stimulate D Other D -a' t Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConccoPhillips Alaska, Inc. Development 0- Exploratory D 186-1881 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21676-00 . 7. KB Elevation (ft): 9. Well Name and Number: RKB 60' 3Q-11 . 8. Property Designation: þ/O-'l'J,-O{¡, 10. Field/Pool(s): r Kuparuk River Unit ¡fDL. z5>I'Z Kuparuk River Field 1 Kuparuk Oil Pool 11. Present Well Condition Summary: T ctal Depth measured 7272' feet true vertical 6634' , feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' SUR. CASING 3748' 9-5/8" 3808' PROD. CASING 7180' 7" 7240' \.f~/;· "'¡".¡~. ., .-'. '.' Perforation depth: Measured depth: Three intervals from 6928-7000 MD true vertical depth: Three intervals from 6338-6400 TVD Tubing (size, grade, and measured depth) 2-7/8", L-80, 6845' MD. Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 6814' . Baker FVL SSSV= 1789' 12. Stimulation or cement squeeze summary: Intervals treated (measured) RBDMS 8Ft OCT 3 1 2006 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation N/A Subsequent to operation N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAGD GINJD WINJD WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Marie McConnell / Perry Klein :~~n::;u:ame #~~C#/~/# Title Problem Well Supervisor Phone (907) 659-7224 Date 10/12/2006 . Form 10-404 Revised 04/2004 ORIGINAL 1. ß ¡O·23·C(. ~:?(.:~,¿;~ ~ . 3Q-11 DESCRIPTION OF WORK COMPLETED SUMMARY . , Date Event Summary Report of failed attempts to repair tbg leaks with patches I 5/13/2006FAILED RE-TIFL POST GLV C/O. I 5/25/2006PERFORM LEAK DETECTION & MUL TIFINGER CALIPER. TBG LEAK FOUND AT 5554'. I" 6/13/2006ISET TTS RETRIEVABLE 2-718" TUBING PATCH FROM 5544.5 FT TO 5568 FT I 6/14/2006MITIA FAILED , 7/16/2006IpULL 2 7/8" TIS UPPER PKR AND SPACER PIPE I 7/17/2006PULL TTS PKR FROM 5569' RKB. I 8/14/2006 RAN LEAK DETECT LOG. FOUND ADDITIONAL LEAK AT 6240' BELOW KNOWN LEAK AT ". 5552'. 8/18/2006SET RETRIEVABLE 2 7/8" TIS PATCH OVER LEAK AT 6240'. TOP ELEMENT SET AT 8/19/2006 SET RETRIEVABLE 27/8" TIS PATCH OVER LEAK AT 5552'. TOP ELEMENT SET AT 5546.5' AND BOTTOM ELEMENT AT 5570'. MIN PATCH ID = 1.375". MIT IA ESTABLISHED LEAK OF APPROXIMATELY 0.2 BPM AT 2500 PSI. 8/29/2006 PERFORMED LEAK DETECT WI PONY TAIL. APPEAR TO FIND LEAKS IN TBG. @ 5711' , RKB AND 5696' RKB (BETWEEN TBG. PATCHES ). 9/14/2006PULLED 2-718" TTS PATCHES @ 5546' & 6223' RKB. 08/22/06 Schlumberger RECE\VED .<. " . . ". "', "1,=--,,'.; . ßC.Þ1t~í··h:u ,D.,UG 2 3 Z006 NO. 3936 c~ ~~: Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 " commission .~cKa 01\ 8. Gas \,.;on5. Ancf1Croge I ~fo -/~'75 Field: Kuparuk Well Job # Log Description BL Color CD Date 2E-05 11249943 SBHP SURVEY 08/08/06 1 1J-109 11235392 CBUUSIT 08/07/06 1 3Q-11 11213793 LDL 08/14/06 1 2T-28 11235394 INJECTION PROFILE 08/16/06 1 1 H-17 11213794 PROD PROFILE W/DEFT 08/15/06 1 1 L-22 11235395 INJECTION PROFILE 08/17/06 1 1J-166 40013010 MD VISION RESISTIVITY 01/19/06 1 1 1J-166 40013010 TVD VISION RESISTIVITY 01/19/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . ì1AY 2 4 Z006 ~!)jf & = CCffiII'48i:a . \g / \ qfb Alaska Oil & Gas Cons Comm \~ Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 RECEIVED 05/18/06 Scblumbel'gel' NO. 3808 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: ) ;) Field: Kuparuk Well Job # CD Log Description Date BL Color 1 G-01 (REDO) 11213744 INJECTION PROFILE i"'ád -ì3ò 05/03/06 1 1 Q-26 11258706 PRODUCTION LOG W/DEFT ¡c1:,\ - /~-;) 05/06/06 1 1 A-03 11258708 PRODUCTION LOG W/DEFT I "ð" ¡ - 0 ~11' 05/07/06 1 1Y-15A 11216294 PRODUCTION LOG W/DEFT I C¡ ?r _ 1«(,., 05/08/06 1 1A-02 11258709 SBHP SURVEY t' '! c.. I 'if t - ('~ l 05/09/06 1 1 R-13 11258711 INJECTION PROFILE (' :l "- \ 'Î'<'-' - ,Çr-> 05/10/06 1 2M-34 11216296 INJECTION PROFILE 1Jì:- ~ I Q (;~ - {,~ 05/11/06 1 2F-03 11216298 SBHP SURVEY , \'~ (ò \.:"..~ - ¡..;..-"1- 05/14/06 1 2F-14 11216299 SBHP SURVEY tJ'r-f' If\-",·· ~ 05/14/06 1 1 A-06 11258712 INJECTION PROFILE ~) '"'\: Q. I.s,. ¡ - I} (,. 05/14/06 1 3Q-11 11216301 LDL , "G' (,- /'5r5r 05/16/06 1 1J-184 11216297 USIT r) ""¡ (' ;::¡ ,"t· n¿¡¿( 05/12/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. [1_.lÁ- ~/9~!ot; s e e MICROFILMED 9/28/00 DO NOT PLACE' ANY NEW MATERIAL UNDER THIS PAGE ARCO Alaska, Inc. Post Office Bo× i003.80 Anchorage, Alaska 99510-=0360 Telephonic 907 276 1215 May 11, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. W E L L ACTION 3Q-11 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. R. Brandstetter L. L. Perini KeEl .4-9 ATe 112O ATe 113O w/o attachments RECEIVE ! .Oil.& Gas Cons, C0mmissio~ ARCO Alaska, h~c, is a Subsidiary of t'~t!sniic~ ~ h?;~i ,. :: ::::, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~ '~. REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 99510 5. Type of Well: Development X Exploratory __ Stratigraphic __ Service __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 4. Location of well at surface 2271' FNL, 2085' FEL, Sec. 17, T13N, R9E, UM Other 6. Datum elevation (DF or KB) 60' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3Q-11 At top of productive interval 1426' FSL, 1898' FWL, At effective depth 1335' FSL, 1829' FWL, At total depth 1288' FSL, 1792' FWL, Sec. 17, T13N, R9E, Sec. 17, T13N, R9E, Sec. 17, T13N, R9E, 12. Present well condition summary Total Depth: measured true vertical 7265' 6628' UM UM UM feet feet 9. Permit number/approval number 90-220 '~'O~ ~'~' 10. APl number 50-029-21676 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 3771 ' 7204' measured 6928'-6942', 6338'-6350', Tubing (size, grade, and measured depth) 7148' 6527' Size 16" 9 -5/8" i, feet Junk (measured) None feet Cemented Measured depth 1875 # Poleset I 1 5' 900 Sx AS IV, 3 8 0 8' 275 Sx Class "G" & 30 Sx dry cmt on top 175 Sx AS I & 7239' 6606' 300 Sx Class "G" 6946'-6964', 6970'-7000' True vertical depth 115' 3731 ' 6354'-6369', 6374'-6400' 2 7/8", 6.5# L-80 AB mod. tubing with tail set @ 6845' MD Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr. @ 6814' MD; Baker FVL SSSV @ 1789' MD 13. Stimulation or cement squeeze summary hydraulically refractured the A sand Intervals treated (measured) 6928'-6942', 6946'-6964', 6970'-7000' Treatment description including volumes used and final pressure pumped 105,000 lbs. of 16/20 mesh proppant and 1521 bbls. of gelled water 14. Reoresentative Daily Averaoe Production or Iniection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Pressure Tubing Prior to well operation 9 3 2 3 3 8 6 6 I I 3 0 Subsequent to operation I 9 5 8 7 0 8 3 3 8 2 0 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas~ Suspended ~ 17. I hereby Certify that the foregoing is true and correct to the best of my knowledge. Service 147 164 S,~ned"~~ ~-~'~ Form 10-404 Rev 06/15/88 Title Senior Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, In,~ ~' · v' ~ WELL SERVICE REPORT Su. bsidiary of Atlantic Richfield Comp~ cONTRACTOR--~ ~ - [~PERATION AT REPORT TIME . I~~(~ ( :~~~ _ . . ~~~ , f- / knot~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate Plugging Perforate X , Repair well Pull tubing Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory __ Stratigraphic m Service __ Location of well at surface 2271' FNL, 2085' FEL, At top of productive interval 1426' FSL, 1898' FWL, At effective depth 1335' FSL, 1829' FWL, At total depth 1288' FSL, 1792' FWL, Sec. 17, T13N, R9E, UM Sec. 17, T13N, R9E, UM Sec. 17, T13N, R9E, UM Sec. 17, T13N, R9E, UM 121 Present well condition summary Total Depth: measured true vertical 7265' feet 6628' feet 6. Datum elevation (DF or KB) 60' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3Q-11 feet 9. Permit number/anoroval number 90-194 10. APl number 50-029-21676 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured true vertical Length 80' 3771 ' 7204' measured 6928'-6942', 6338'-6350', Tubing (size, grade, and measured depth) 7148' 6527' Size 16" 9-5/8" i! feet Junk (measured) None feet Cemented Measured depth 1875 # Poleset 1 1 5' I 1 5' 900 Sx AS IV, 3808' 3731' 275 Sx Class "G" & 30 Sx dry cmt on top 175 Sx AS I & 7239' 6606' 300 Sx Class "G" 697O'-7OOO' 6374'-6400' 6946'-6964', 6354'-6369', True vertical depth 2 7/8", 6.5# L-80 AB mod. tubing with tail set @ 6845' MD Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr. @ 6814' MD; Baker FVL SSSV @ 1789' MD 13. Stimulation or cement squeeze summary add perforations in the A sand Intervals treated (measured) 6928'-6942', 6946'-6964' Treatment description including volumes used and final pressure Perforated at 6 spf with 0° phasing 14. Reoresentative Daily Averaoe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Pressure Tubing Prior to well operation 1 0 7 0 3 8 2 1 2 1 1 3 0 Subsequent to operation 1 1 8 4 4 31 0 1 1 3 0 15. Attachments ~16. Status of well classification as: I Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service 151 246 Form 10-404 Rev 06/15/88 Title Senior Operations Engineer Date SUBMIT IN DUPLICATE ARCO Alaska, ir S?,bsidiary of Atlantic Richfield Comp WE~'L ~ ~-// WELL SERVICE REPORT CONTRACTOR REMARKS- tPBDT - lFIELD - DISTRICT- STATE IOPERATION AT REPORT TIME IDAY~ lDATE '-/- z,-t- ~' o F-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK W. ath.rR.pOrt ..[Temp. 'F Chill Factor. Fl[Visibility mile. Iwind vel' ~77 ARCO Alaska, Ir Post Offic ax 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 9, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. W~ll Action Anticipated Start Date 2U-15 Stimulate April, 1990 3F-11 Stimulate April, 1990 3Q-11 Stimulate April, 1990 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer cc: J. Gruber ATO 1478 J. R. Brandstetter ATO 1120 L. Perini ATO 1130 KOE1.4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Al{3[~; t;()():; (; STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well_ Change approved program_ Pull tubing _ 2. Name of Operator 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ ARCO Alaska. Inc. 3. Address P. O, Box 100360, Anchorage, AK 99510 Re-enter suspended well _ Time extension _ Stimulate ;~ Variance Perforate_ Other _ 60' RKB f e e t · Unit or Property name IKuparuk River Unit 8. Well number 3Q-11 9. Permit number 86-188 10. APl number 50-029-21676 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Location of well at surface 2271' FNL, 2085' FEL, At top of productive interval 1426' FSL, 1898' FWL, At effective depth 1335' FSL, 1829' FWL, At total depth 1288' FSL, 1792' FWL, Sec. 17, T13N, R9E, UM Sec. 17, T13N, R9E, UM Sec. 17, T13N, Sec. 17, T13N, R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured true vertical 7265' feet 6628' feet Plugs (measured) None Operation Shutdown_ Plugging _ Effective depth: measured 71 4 8' true vertical 6527' Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 7 71 ' 9 - 5 / 8" Intermediate Production 7 2 0 4' 7" Liner Perforation depth: measured 6970'-7000' 4 SPF feet Junk (measured) None feet Cemented Measured depth True vertical depth 1875# Poleset 115' 115' 900 Sx AS IV & 3808' 3731' 275 Sx Class "G" & 30 Sx dry cmt on top 300 Sx Class "G" 7 2 3 9' 6 6 0 6' 175 Sx AS I 0 degree phasing 13. true vertical 6374' 6400' ~t-'; .I. o . Tubing (size, grade, and measured depth 2 7/8", 6.5# L-80 AB mod. tubing set at 6845 .... ..,~,,,~::ii?]~.¢.asO0ns. O0m~i'&s~l~i~ Packers and SSSV (type and measured depth) ~ ' .~p,(;!~0r~tl~) Camco HRP-1-SP pkr. ~ 6814', Baker FVL SSSV ~ 1789' Attachments Description summary of proposal _ Detailed operation program X BOP sketch Hydraulically refracture the A sand. 15. Status of well classification as: Gas __ Suspended _ 14. Estimated date for commencing operation Aoril 1990 Oil _~_ 16. If' proposal was verbally approved Name of approver Date approved 17. I herffi~y cert. ify _that the foregoing is true and corrept to the best of my knowledge. Signed'~~ ~) ,, Title Sr. Operations Engr. FOR COMMISSION USE ONLY Service Conditions of approval' Notify Commission so representative may witness Date IApproval No. Plug integrity __ BOP Test Mechanical Integrity Test_ Approved by the order of the Commission Location clearance ~ I ~¢:~,,'J" ,-~' ,z. c.) --Subsequent form require 10- ~'-'~ -,,oVe(~ Oo[:;)"J / ORIGINAL LONNIE C. SIVI!TH ~ner Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Application for Sundry Approval Kuparuk Well 3Q-11 April 2, 1990 1. The estimated bottom hole pressure is 2800 psig at -6200' ss based on data taken on March 4, 1990. 2. No workover fluids will be required for refracturing the well. Kuparuk Well 3Q-11 Refracture Treatment STAGE CLEAN VOLUME PROPPANT DIRTY VOLUME CUMULATIVE STAGE HITS (BBL) (POUNDS) (BBL) DIRTY VOL (BBL) PERFS @ (BBL) BREAKDOWN (GW) 100 0 100 100 43 PAD (GW) 900 0 900 1000 143 SLURRY (GW) 2 PPG 64.3 5404 70 1070 1043 4 PPG 68.0 11425 80 1150 1113 6 PPG 71.2 17936 90 1240 1193 7 PPG 63.2 18568 100 1340 1283 8 PPG 73.9 24840 100 1440 1383 10 PPG 41.6 17490 60 1500 1483 12 PPG 13.1 6593 20 1520 1543 FLUSH (SD) 41 0 41 1561 - TOTAL 1436 102256 1561 TOTAL GW 1395 TOTAL SD 41 VOLUME TO PERFS (BBLS) = 42.8 GW-- GELLED WATER SD -- SLICK DIESEL PROPPANT = 16/20 MESH (CARBO-LITE OR LWP) PUMP RATE = 20 BPM (drop rate to 16 BPM if necessary) ESTIMATED TREATING PRESSURE = 4000 psi BREAKDOWN = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKE PAD = GW + 40 LB/1000 GAL SILICA FLOUR + BREAKER SLURRY = GW + BREAKER (NO SILICA FLOUR) FLUSH = SLICK DIESEL ARCO Alaska, Inc. Pos! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 2, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in triplicate are multiple Applications for Sundry Approvals on the following Kuparuk wells. Well Action Anticipaled Start Date 3H-04 Stimulate April, 1990 3K-08 Perforate April, 1990' 3Q-11 Perforate April, 1990 KRU State #1 Stimulate April, 1990 If you .have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer APR - 5 1990 0il & Gas ConS. Com~ss~°'~ CC: J. Gruber ATe 1478 J. R. Brandstetter ATe 1120 L. Perini ATe 1130 KeEl .4-9 w/o attachments ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. :Type of Request: Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension Stimulate _ Change approved program -Pull tubing _ Variance _ '~erforate ×. Other _ 2. Name of Operator -' ' ' 5. TyPe of Well' 6. Datum elevation (DF or KB) Development ~ ARCO Alaska, Inc. Exploratory _ 60' RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. BOX 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 2271' FNL, 2085' FEL, Sec. 17, T13N, R9E, UM 3Q-11 ... At top of productive interval 9. Permit number 1426' FSL, 1898' FWL, Sec. 17, T13N, R9E, UM 86-185.. At effective depth 10. APl number 1335' FSL, 1829' FWL, Sec. 17, T13N, R9E, UM .50-029-21676 At total depth 11. Field/Pool Kuparuk River Field 1288' FSL, 1792' FWL, Sec. 17, T13N, R9E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7265' feet Plugs (measured) None true vertical 6628' feet Effective depth: measured 71 48' feet Junk (measured) None true vertical 6527' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 1875# Poleset 1 1 5' 1 1 5' Surface 3771' 9-5/8" 900 Sx AS IV & 3808' 3731' Intermediate 275 Sx Class "G" & 30 Sx dry cmt on top Production 7204' 7" 300 Sx Class "G" 7239' 6606' Liner 175 Sx AS I Perforation depth: measured 6970'-7000' 4SPF 0 degree phasing true vertical APR - 5:1990 6374'-6400' - Tubing (size, grade, and measured depth ~,. . , . aska 0il & Gas Cons, 2 7/8", 6.5# L-80 AB mod. tubing set at 6845' Packers and SSSV (type and measured depth) Camco HRP-I-SP pkr. @ 6814', Baker. FVL SSSV @ 1789' 13. Attachments Description summary of proposal _ Detailed operation program ~. BOP sketch Add perforations to the A sand. 14. Estimated date for commencing operation 15. Status of well classification as' April 1990 Oil ~ Gas __ Suspended _ 16. If proposal was' verbally..appr0ved Name of approverD~te a'pproved Service 17.' I hereb~ certif, y,.~)~, tha~lthe foregoing is~ ~' true and correct to the best of my knowledge. ~"~/~/~ Signed · Title Sr. Operations Engr. Date FOR COMMISSION USE ONLY con'ditions of approval:' Notify Commission' so representative may wi'tness IApproval No. Plug integrity _ BOP Test _ Location clearance __ //o/~ I ?~' Mechanical Integrity Test _ Subsequent form require 10- ORIGINAL SIGNED Approved by the order of the Commission BY LONNIE C, SMITH Commissioner Date y~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Application for Sundry Approval Kuparuk Well 3Q-11 April 2, 1990 1. The estimated bottom hole pressure is 2800 psig at-6200' ss based on data taken on March 4, 1990. 2. No workover fluids will be required for perforating. 3. There will be a lubricator with a 5000 psig rated BOP used during the perforating work. RECEIVED AP R - 5 !990 0il & Gas Cons. CO~~t$s'to~ Anchorage Kuparuk Well 3Q-11 Perforating Procedure (4/2/90) Charge Code: 230DS36QL 1. MIRU slickline unit. 2. RIH and tag fill. 3. RDMO slickline unit. 4. If tag is at or above 6990' MD-RKB, a CTU cleanout should be performed prior to perforating the well. 5. Obtain two 12 hour tests prior to perforating the well. 6. MIRU perforating unit and pressure test equipment. 7. Shut-in well. 8. RIH with 2-1/8" through tubing perforating gun below tubing tail. The following charges are acceptable for perforating Well 3Q-11' Vendor Charge Charge 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 9. Open well and tie in to the following logs: DIL/SFL dated December 20, 1986 CBL dated January 9, 1987 Short Joints: 6809'-6848' MD-RKB (from CBL) 10. Once the tools have been tied in, perforate the following intervals at 6 spf (0° phasing) with the well flowing: 6928'-6942' MD-RKB (A3 interval) 6946'-6964' MD-RKB (A2 interval) 11. Shut-in the well and POOH with perforating guns. 12. RDMO perforating unit. 13. Return well to production. 14. Obtain two 12 hour tests as soon after perforating as possible, in order to help quantify the benefits of perforating Well 3Q-11. RECEIVED A?P~ '- 5 !990 0il & Gas Cons. Co[ii$$$10-t~ 3. SO00 PSi 4 l/E," L~TOR 4. SO00 PSi 4 1/8" FLOW TUBe p.M:~-orr 2 RECEIVED ~Pi-~ f5 . ~ STATEOF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C,~vIMISSION ./d~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~ OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, inc. 86-188 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21676 4. Location of well at surface 9. Unit or Lease Name 2271' FNL, 2085' FEL, Sec.17, T13N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1426' FSL, 1898' FWL, Sec.17, T13N, R9E, UM 3Q-11 , At Total Depth 11. Field and Pool 1288' FSL, 1792' FWL, Sec.17, T13N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 60'I ADL 25512 ALK 2553 l:~. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. '15. Water Depth, ifoffshore 116. No. of Completions 1 2/16/86 1 2/20/86 05/14/87*I IN/A feet MS L 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7265'MD, 6628'TVD 7148'MD, 6527'TVD YES~] NO[] 1789' feetMDJ 1600' (approx.) , 22. Type Electric or Other Logs Run D IL/GR/SP/SFL, FDC/CNL/Cal, CBL, Gyro, CCT./Temlz3./t~z~essuzre/S~)±z~ner 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE! WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 ;u rf 80 ' 24" 1875# Pol eset 9-5/8" 36.0# J-55 ;urf 3808' 12-1/4" 900-sx AS IV¢ 275 sx Ciass G & 30 sx dry cement on tcp 7" 26.0# J-55 Surf 7239' 8-1/2" 300 sx Class G & 175 s> AS I · 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) ,, 2-7/8" 6845 ' 6814 ' 6970'-7000'MD w/4 spf 6367'-6400 'TVD 26. ACI D, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL uSED See attached addeldum~ dated 5/16/87 for fracture ¢ ata 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (co[r) Press. 24-HOUR RATE ~ 2'8. CORE DATA BriefNonedeScription of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit cornish,sE E t V E D Alaska 0il & Gas Cons. O0,nmissifln Anchora~ie * NOTE: Drilled RR 12/22/86. Tubing run 1/20/87. Perforated we]] 3/7/87. Form 10-407 WC265 :DAN I Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29.)' ..... .-.-. 30. ~ , GEOLOGIC MARK~R5 FORMATION TESTS .. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Top Kuparuk C 6923' 6334' N/A Base Kuparuk C 6932' 6341' Top Kuparuk A 6932' 6341 ' Base Kuparuk A 7034' 6429' 31. LIST OF ATTACHMENTS Addendums (dated 2/17/87 & 5/16/87) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~;~~./ ~'~i)L/~)d..)~,. Title Associate Engineer' Date (£'~? -C~'~/ INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' ClaSsification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 1/06/87 1/09/87 1/21/87 3Q-11 Rn CBL & gyro. Re-rn CBL to 7132' WLM TD. Rn GR/JB f/PBTD to surf. Arctic Pak well w/175 sx AS I & 60 bbls Arctic Pak. "Drilling supervisor · Da~e ADDENDUM WELL: 3/07/87 5/14/87 3Q-11 RU Schl, rn CCL/Temp/Press/Spinner/perf gun, perf 6970'-7000' @ 4 SPF. Att to rn spinner; did not wrk properly. SI f/PBU. POOH. Frac Kuparuk "A" sand perfs 6970' - 7000' in 11 stages per procedures dated 5/~7/87 as follows: Stage 1: Pad "B", 180 bbls gel diesel Pad @ 20 BPM, 4000 - 4010 psi Stage 2: 5 bbls gel diesel 100 mesh 1 ppg @ 20 BPM, 4010 - 4020 psi Stage 3: Pad "C", 420 bbls gel diesel pad @ 20 BPM, 4020 - 3880 psi Stage 4: 20 bbls gel diesel 20/40, 2#, 20 BPM, 3880 - 3850 psi Stage 5: 40 bbls gel diesel 20/40, 4#, 20 BPM, 3850 - 3860 psi Stage 6: 40 bbls gel diesel 20/40, 6#, 20 BPM, 3860 - 3870 psi Stage 7: 41 bbls gel diesel 20/40, 7#, 20 BPM, 3870 - 3820 psi Stage 8: 20 bbls gel diesel 20/40, 8#, 20 BPM, 3820 - 3850 psi Stage 9: 19 bbls gel diesel 20/40, 9#, 20 BPM, 3850 - 3920 psi Stage 10:12 bbls gel diesel 20/40, 10#, 20 BPM, 3920 - 3810 psi Stage 11:43 bbls flush @ 20 BPM, 3810 - 4530 psi Fluid to Recover: Sand in Zone: Sand in Csg: Ave Pressure: 840 bbls 200# 100 mesh & 35,000 20/40 300# 20/40 3850 psi Release well to Production. Dri~hg Super~i~or ate January 23, 1987 Mr. Randy Ruedrich ARCO Alaska, Inc. P.O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-70005 Well: 3Q-11 Field: Kuparuk North Slope, Alaska Survey Date: January 7, 1987 Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures N L Sperry. Sun/N L Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ..~ ~ _to_ ~ SPERRY-~IN-WELL :::URVEYING i-:OMPANY' . .......... i ........................ _F'~GE.., '" '- '- ........ ............ .:v:-:--'-? .' ' :.. ' ............... ARCO ALA~;KA, INC,;'"~'o', ".'~oo ' ' ' "' ' ' ' ..... ~' ..... : .OF' .,~URVEY ,JANUARY .~7.-,. 19.87 · - . ' : '. - -:.~ ~.. ....... . ' - ...:--.. ..---- '...:--DATE ~. c. - . . - , ..- . - .:i-.-::.%.?~!;:~- . __ ........ , ., ,--- _-", , ~ ' ' '~LJ~_ ' "'" ' ':: ' ' :' '~':'':''' ' ' ":~ ~_:-.~__~ ......... i,.__~i - '.'", '~'~~ - · '. '~.'¢O~P.U.T~TIO~.'D.~.~, .... -.' .:. ~:..' ~:~.':~.~;?~8.:' ~.-YRO,~COP~c. SURV£~,?:.-,..::-:: . . KIJF'~RLfl-.-~ ~ ,..I~NUARV ]1.2, 1987 ,..lOB.. NUMBER ~L.A,:3K~ ......... .a .......................... - ........................................................... .' ...................................................................................... -..=...-.. = .................................................. -~'~' · - . KELLY~ BIJSHINC. i ELEV. = &O. O0 F'I'. VERT I CAL SECT ION CAL.C.:~ONO -~,~. .... . ..,~!..~ ~.... ~,.~.~:~:...~ -.-. -', ....... ...~"""" · .,~.n,..,~ -._.......,.~ - T-RUE MEA.:,LIRED VERTICAl... VERT'ICgL INCLINATION ............................................................... 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"- .2 :L; ; '~ .. ... ., ..... . ,, .. .... ., .... · ...... 7 · t4 .-,. . ,, :t. :i:::. ":i.C; E :l 4. . 1 ,::,'"" i'". ~ i i,--. m r-'i'l .:,FEF:RY-.z,I:JN WELL :--;I_IRVEYI-NCi C:OMPANY -"~= .... 0:~'. ..... ~ ......................... - AN~-.~"6~iE ALASKA:'?. F'~GE .. ARCO ALASKA, INC. ~: D,~ ~ '. .... DATE OF SURVEY JANUARY 07, -_,- . o ~ ~'. -' ~ COMPUTATION DATE' _ ~L~_-.!..1..' ........................ ~_~. m'::.. ~:::' :;:~. ~' '~................ '',B.~SS GYROSCOF'IC SLIRVE. Y.'. ';...,'~? KLIPARLil< ,3:, ~ .... _~:~. ............. ITt:! ._IANUARY 12, 1 :~87 JOB NUMBER Ai<--BO---7C~O05' ALASKA . '" '. ~ ....:~ ...... i ...... ~ .... "' i .: ........... i' .:i'". '" :' ' . .... - .... KEI.LY BLI.'.--.;I-I-:I"I',I£.~ ELE,, = Ac. 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F'AGE 4 .. :=':' ' "''' "'" ' ": - ' 'DATE..-.OF SURVEY dANUARY 07~ . . : : ' . . . : :.' . .: . . .. , ~ . -:s-:~. ,JANUARY 12, 1~87 JOB NUHB~R ~K--BO-7000~ ~. ............................................................................. -kEEL'~'m ~U~;H~Nc~ EEEV.'""J ........... g6' r~n "FT', ........................ .................... .. . ....................... ~ ............................. . . : OPERA TOR- MC.:GU I R E INTI~~~T....E:'D Vi~LUES FOIR.;.EVEN'.':t-O00'' .FEET OF" MEgSURED"DERTH. ..... :.~..~ .; .... . · ~ ~-.;','.'-'i:~?"' .t,'~,"' . .' - ,' ............ . .................. ',.._, ...... : ..... -,/.::' .. ?~,~:'-:,".~ 4'.v7.~c.'~.. -- - _ .............. TRl_e..r" SUB-SEA. TOTAL . . MEASURED VERT I CAI_ "VERT'i'i~!AL' . REC:TANGULAR ' COORB INATES 'MD-TVD VERT I CAL. FJEPTH [,F:.F"f'H ...... ~'~'~'~ .... N~R'TI'j/'E-iOLiTH EAST/WEST '[:i IF:'F'AREN ...E" ' ' ' r' ..... f'.':ORRECT.. . I OIq. ............................ ..: 0 0 .' O0 .-60. 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(') ('u", ' . . .................................................................................................... O. ................................................... ' ................... ; ................................ :,: .................................. " ..................................................... 2,,.,= ..................... "" "' "' ~ 560 ~ P~-,('~ ~ O0 1 ~ ' c ._,OJ,O0 6.42 N ~0.'~4 E 0 ''"' ..... ..... (.),:, 0 C)(") 1660 ' ..: ' t"660.00' . 1600 .' O0 ' .6:';::~::4:=~:'.. 'N':';~::: · ....... 11' ,:8:~.:'::'::'E:.:"-:'::: .:::?"~:':"' "~ Y;::<O':;?.O~ O, O0 ............ ::,...:?r..: 176.0:. 176.0',.00 -..I"700,:.00' : . . . ...... .~.~.. .............. . ~=. :--.: . . . ..... ' . ~ :~. '" '.~" · .... ~".'..- .... ....... ......... :-'~ ............. 7",: ~~ ~ . ..~ ... . ...~ ... .... . :... :..,.?.. . ....... . .... ..:. .~ ...:.~:...~':~.~:.~.:~:;~:.' . . .. . . . ..¢_ ~., ~ ' ..,.. . .: .,.. ... :....:. ..:. . .,.. , .. .... ...... ':~;~~?..,,~,~ .**,,~,~ · : . . . .~' . ~_ ............ . :~..... ::..: . ... ::~::~:~,.;~¢~..... . ... . . .... . ~ ~.. ~.~ . . ~ · .. : .,, . . . :., .. .:. . ~:~..i~i~:~i~:~'.~.::.~:~::: . . ........................ ~.-~ .... ~ ................. ~ ........ .. -~~-.: ................ - "'%~ ~e "' .................. ................................................ : ....... : .......... ' . ~ ' ~ .. . ...... ...... . ....... .. ..... ...................... : ............................. . . · ' -~. ~ ............: ............... : ....... : ........................................... :~..'..: ........ ...' .......................... S ..... -,.... ....... :~ ....... : ....... : .,... .................... - , · :.- .. .'~ · , ' ?~ · ..::..'~:..... ....... . .-. · : _. .:. EF;RY ,.._N WELL. SURVEYING COMPANY PAGE 6 -. ARCO ALASKA, INC :' ': DATE OF SURVEY JANLIARy 07, i9.87 ii. - - . , - ~ ' ., . ,:: -. . -.... , . . . . . . . . .. .. I-:::UPARUK . ' .JANUARY 12, 196:7 .... '_.lOB NUMBER'AI'::.'-BO-70005 · . .... OPER~TOR,'~COU~R£ .................................................... INT..-~D VALI~E:$ POR EVEN, 1O0 FEET .OF E:UB.~.EA DEPTH ....:,....}~. TRLIE SUB-SEA TOTAl. . ...'.... -:'... .............. MEA.:, _ R~[.~ VERT I CAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD VERTI C:Ai... K~E'PTH I'vE' F"'TH KIEPTH I~'OR]f H/' i~:C'jU]"Ft EAST/WE.:-.T D I FF. EREN ...E C:OF;:F::E C:T I ~"',l",.i . ...... .,:. 0 ,, ;";":' · ......* ,~" ~ .. ., ... ......... -. ...... .... .. ...................... ........ =~0 W .... ' . ,,.,, . - . .~..,~_ . . .~.,... .. .. . .. .:..~i, ~ '::,'~, .... . . :. ,.. . · .~. - SPERRy-SUN ~E~..,E~L SL!RVEYING'-COMPANY ,..: - J:'AGE 7' :ARco,. ALASKA, INC.. -: ..... ' . . -. -. ,--..-:-.:~ - .' - ..~ - .... ' .,, ,- ..... -.: .:;.,?, :,:,:~:.-:-.--, ~::-:-.:-..-?:.: ~>/~, E OF .... ' ' '" " ' ' ":" ' ':'::' :':" ':' ' """' :"";'? -:~::~:-'"/::': '%':' ~"?'~"' "~'~"~ '"' SURVEY ALASKA "-' · . " ' ' ' ' ~ELLY-..Bt3SH I NG EI..EV ..............................- .."~'~ ........ :-- ~"-. · - "'>~- .................. ', · ~-"'~~A~ ~.~t'R- M~:G~.i IRE ~.' ........ - · ' .... ~ :.-' "~~: :"~ ' : ': : ~":-- :.-'- ~. :' '7 -','' ~ '.:..-: · ' . .,' i ~: ."..- . .:~.'-' ,'Y '~:~:": :'?.,. ~' ."u~.~-,i ~::.~ i-' x'.' - . ': ~ · ,' -. .' . .~.~~:':?,~,?¢~:;~%?.: - ... :, . ,. ... : .::...:.:,.. .~,:....:. : . . - . . .:::...'..:, TRUE ...... ~,!.~g.~ ................. TOTAL .............................. MEASURED ' VERT~.CA.L ..... ~,~.~.~g...' ....... EgCX~NOUkAF.. c¢OBpZN.~g~'~ ........ .......................... ~;LY'VD:'".',,....~ .......... ...... V~F':T~'-'.-.,-',L': - "' - i:": C ON .DEPTH DEPTH DEPTH NORI'H/SOLITH ~ EAS"r/WEST DIFFEREN_E ORRE:C"I" I ................................. . ~ ........ ~.~.~.~.. __;.-:;... ,,.-- . -- ..... ~ ........................ ; ...................... · .:,,:~ 4.:,.:~ 7 ,:, O. 00 ..:3'70 O 00 -Z 6 Z · 'l 3 ::; .:~...4..~. 2'9 .:,,=, .:, 0 00 '-' '=' ' ' · :,oOU. 00' .. ,3 i 1.82 '"'S ..oc,. i'l N ........................................... - _ . 4080 3'760,. 0() 3'~90. O0 36, t. i :lS .- 322.25. W 419:3 4060, 00. 4000., 0.0" ~ i ri'::; 53 .S ' :3.8;2'~ 0'~:" W_ .,. 431 '7 4160'. O0 4 t00. QO -' 4:60, '25 S 401., ¢~5 W ,. 1'-' 49 LB. :l 6 J, '8 ,, 4 4 :|.o 4:260, ()0' 44.: ..... ................................................. .......... ...... . ................... ' ' ' . '. ~2" ' ~ ' ' "~ ' :' · ' ' ' "" · ,, '. '.' =================================================== ' ' ' oF ERR~ -._-,_ N 'WELL NG o ..IR VEY I COMPANY PAGF .......... : .... : ...... · ANCHOR~ 'AL--A~K~. ' ........ ~":-.. :' "." ':"::" -~ ................. . ARcO '~LA.SKA, INC, ' -' BATE OF .SLIRVEY-,JANUARY . .. : . ....... 3~4-11 ' ':.~ - .,.;(~;~;/-;~.~.~-~;,....'- .'-. :.~'. '.':'. TA'TION-OA~' .. :~f~:;.' .. ." ....-,_ ............... ... · :...~ :. :..,. .... . . KLIPAR.~IK ........................... ~ .................. ~!ANU.~.12, ~987 . JoB NUMBER AK-BO-70005 . ALASK~ .;: ......... ' "'."R~LLY ~'USH~ NG E. LEV,' ~"' ~&i)' O0 'FY'~ ................. . ~ ........ :'-- ...................... . . OPERATOR-.McGUIRE ................................................ ~ ...... · ~.~~L...--:':r - "' ..~. ....... ... .. . . . ... ~.?-~ ,..-..... .... .. . . .... j.:;. ~T]~-~:---~;:~. . IN~O. VA[UE.S :F~..EVEN' ~ O0.-.::.F~ET.' OF -SI~B~S~A.~: o~PTH' . . · " ' ' ' "" ' ....... '~ ] e?- ' ' . . . . . ~' ..., . -~ .. - ........................... z ..... ., ' ':. ~ ............................. '... >':::2. . ~ ..... · .....· . :.:.~,:...:~..:m..,,P~:~.;.. -.._.'.". '.';' ' '._~ ;':' - SUB'SEA TOTAL '" 9~'~'i'i~.~IL .... REi~:'T'AI~jt~'UL. AR Cl30RD i Ng TRUE .MEASUREI] VERT'I CAL ....... M'B- TV~J .... VER~' I C;£:, i .... ' ...... "l ~ '~ ' L EF l' H D'~PTH. DEPTH NORTH/SOOTH EAST/WEST D I FFERENCE C:ORRE C::T.. i ON . 4;127 0660. O0 5600 00.' 1.ja¢~ ~o S- 1'0~6 6.8-.W 467 9'1 1'~.j '--'":' ./:,247 5760 O0 5700.0'0 .1~01."36 S. 1077 28 W. 487 51 19,60 .............. ".~ .: .................................... :__.'_ .................. ; ............................ · .................................... ." .............................. · 6 ::'-: /-, ,/-, .~,'---'"-._ o o A~, 00 ~'-'"~'" 00 1 '-":'-' ~.:,' ¢3 '" q · --= ....... 1' 117', ._ 6 W ~OA., '-'" ..... · z,.J.,:., .:z, .. _ ;:, (.). [ '.,.'-> · ' ¢ --:, ' o zI. _ _..9,z, W ,.'=;'0 p'; ~ .'.::. J :.'3 ,, 72 .4:,4:35 .596F: 00 5900. O0 i 4 .~.4 ,_, S 1'1 :-~/-, e,-, . ............ . .' . ...... ' '" k"i'"-'. 0';/' '¢' ''=' ~';' "-" . .. 66 C):.3 606 C) C)0 /.;; ~.-)0 F), 00 1, 4 ..... :: . S 11 .= .,,. 7 ~ W .. 4._',. 54. .L :3 .o 'I. /. -'. :.~,... . .......... .~;.:;:.:.:.--~-~ .................................. ~,~. , ,, =,7 .:c)"?;, ................... ~ );,o' :.oh ............... ~;i 662..6c): .................... T§~16'2"~9 ~ 1~: ..... :-:. ~.,7 W ..,.::,o. ;==*.., ~: ........... ~:~' /-"-"'""~ 6260 O0 6200, O0 '= -" ' ( ,' ~"~' '-" '~" / m 6 .*,.:, 3 6,:,60, O0 6300, O0 1 ,='. c',= .' ~=, 1'"306 04 · W . ,.:, ~ ~., 75 16, 2 J. ............. .... 00' .................. './.;,'~i~i ............................... ~T;~ !2~ .................... ' - ,-' ' ?- n/..,,:.~ .... ~S if,-'.;o'' .......... i~i~ i~iT-~ ~';~' ':s ...... i"~-_;:'4-~' ;'i~'i'"':iLF ......... 6u:; , ,=~'--'""-,=, :l ~:'.-, , ~. ".'.'..., ....... ~'!,. ~" ~"~ i~ .--i' ~"i 7 !,_,':-" /'_, 6,:=i/,A ....... ,. 00 /_-,~.,¢..)0 ,00 16,-, .'; , 16 . S 1 ..:, Y,::, , 1'5 W 6,2/_-,, ~. '":' _1. 1 7'T, APi j:,62.7 ,, 74. /"--, ,.P;' 6 ''=,, 7;I. ' '*~ ~' ' '~''' ' ........................... 637 'mX- ..... ........ 17.:: 1 ~ C..l .=, 14.02., 76 W ....... 'l. · . THE r.i:At_C:U[_A'r' iON PR'OCEDURE'~;' USE ...A LI.NEAR:' :INTERPOI....AT ]:ON 'BETWEEN' THE: NEAREST-20 FOOT MD (FROM RADIUS.."OF i_':'URVA'FURE):.P.O'I..NT~. "' 42 ZZ."i .' ." i : :'-'7;;;Li;:';:... L': .: . ..................~ :'~;~;";:... ....... -~ ............ ~... ...... . .~' -.... ---. .. ~ ............ ..... ~?.,?':.~:'"~.~':':.: ......... ..,.~:.~ .. ..... .. ' %?% ................................... . ........................................................ % .' .. SPERRY-SUN NELL :--;URVEYING COMPANY .... [::~AGE '=~ ' '"' '--" -.' '" ~' .ANCHORAGE' AI=ASKA ARCO.. . . - /'. i~LASi<A,. INC. .~..:~.,...:.~:~;..,-,:..-.....,L' - ".C:"= 0~' ..: '~'.~.... ?" -..-..<~}"-?:i'~:':¥' .:DATE: OF SLIRVEY' dANUARY 07, .I ~87..._ .............. ~ ~, ,. ' , -.~-'~z'.¢.~.~'--.~'~.~..~...~.- , - :;-.. n:~..:,¥ ,:..:,., .-. . ;:.~:- '., .. · , ,., KLIF, ARLIK ....................................................... ~!~...N..'!.=.!~R...Y......!...~,, ..... 1~.~!.7 ........ - ...... . ..... 'j-: ................... :..:!.O.B.......N.U..MBE'.R AK.'-BO-TC'()!')..~ ....................................... ; ........ ALA'.3K~ . . ~ KELLY BUSH I NO ELEV. = ~0. (')(') "FT. ............... ~ ............ · ........................................................................... · OPERATC~R-MCGU .... . ;.' .:: I.NT.~..VALuES .FOR' SPECIAL SURYE¥?,-PO..:~..:N',~.~i.?:/ '. · ~-~%-'.~. :'..'~x.] .-? ¢.~A,."..:: · ~ '} - ~:- : · " ' : ..': ~'f '.. . .-- . ~-. ;:.]'..'~.. ,.;.~,?,? }-:. - . .. . _ ...................................... . . , .:,.:-~.~:L. .................... ~ ...... -~. ............. :-,~::'. ti -. . :. ~.:¥~'"'.~'~ ~ ' "- ' ~ '"' ' " 'rRUE SUB-SEA TOTAl. · ............. MEASURED VF..F,''r IriAL' ":Ol~i~'~:j:"i~i'i~'L .... 'REi_=iTANGULAR .... CooRD INP~]'ES ............ r.,'EF:TH.'...' .... . ........ ?...,E.F, TH" i/'.'.../i',i'i"~.,.-~'~!~)~;Th- .................. 'i~'~r~f'i~/L-~i'6i.):rH' ............ [~'~Si'f'/U~.!'i~if 6:,?23 6333.53 6:-.?32 ' 63Z~ 1 '. 27 ............................. · --~.~. A'-.?:=,'2 6341, ,,: / 7034 /=,42".'..~. 12 7 .1. () 0. /- - '-'~-" A 9 ~' 4 C5..I ,,, _ , 714i:3 6527. 16' 7...265 ,/_-,627.74 6273.53 628.1.27 1582.74 .S TOP R:Up~RUK C BASE KUPARLIi< C: :,.,::,:, 1 .,._ 7 1 ._ ,.~, S 1 9; '-'"~' .=l :;.. I_"., .... · . .:,.:, W TOP .I<UF'AF~IJI< A 6,:, W BASE' ~:~LIF'ARI_tK A ./.-.,.:, ~:,'-' ' '-~. 1 '":' 16.'.27 ~ 64 S .1. ._, ':'.._,'':' A,, "=' .~:. . i, .. ............... · . · e,.J4, .... 1 :.::51.=,.x, '-' I ' ,!,4'.-.'~ '"':~ ' ~:: ' ":' '":' '::' ' - ,:,; l . ,.-...... gl .:.,L RVEY DEPTH · ..~ .~:.o ...~ .................................................... ~ ........................ 6467, 16 1673, 7...2 S 1366.21. N PLUG '.BACK TD · :' ' .:, 14 3...-, 7.6 N TOTAL. DEF ] Fi ][ R I L..L. ER 6567,.74 17,: J:, 01 '" ¢ '-' ' - '" I "' ' ~. .... ¢~..-//. ........ . ........ . .............. . .... : .................................. · .... · .............. . ................. ... ' ' .......... ~'~.'""'"~ ...... ~'" .' ................................... i ..... :':: ................. . ....... ..................................................... ........ ' . ' ...... · '~'~]' .... .~ ........ ='"~' ....... .' ......................... =": ...... :7"--= ...................... ~'~ ...... ~"~ .......... :'::i?~i!:%"":'.:.;":5::?'="':'" .................................. : .......... · ,. . . ,. ...:- .... . .... .... ,, ... ~.~ ~._ - . ..' · .,:......,,~.~,.~,.~!~ii!!: . ..... · ............. ~.~!...'.~'..__.' ....... ...... ' ' :. --'. _.~--2 ' . ........ i ......... '-?.:/!?::':i:!%:?&~?.i~:::~..~:':?'L'..:... ........ ._.'. ......... .... . · x~,.?,?~..,:...~;~.: . - StoAT i'~R~'~"~.! c",-~SU~,id'~'~.',:.i''''' ' .. ' '-" ................ . DERIVEr,' USING' DIL DEp!~. ~...._Sp[.~y..~y~....~5.0Rg[9' .r,n%~- ............ '":' "":" THICKNESS- V~RT'I CAI. ...... --MARKER .......... TVD ~':'~ ' · .} .-.~..~.~:~..'27~?.-~ . ,:;;;;:~ . ....................................... - 'm,,, ......... , v' ", ................ . TOP KUPARUK C "67~ .............. 633:3. ~'* i .-..q' · .,~. .=.~7..:,. 59 ": ..... BASE KUF" 'q'''~'IJK' C: ' ............................................................................................................................... A s~:~2 6341 ~OP- KUPhROK~ g ................................. ~g~' .......... 6~41 ..27 628~-~;2-~~ .................... r ........................ BASE KI. IF ARUK g 7034- 6429.12 606 ~. 12 PLUG BACK I'D 7148 6527.' TOTAL. DEPTH. . '"~LR-i'L E~-~-" ................. 7~' t= ..... ~; '~,':L,~-¢7¢-4'/-" ............ · . . . ..~. '~'. .... ~ - --:': ..... .,~ .......... ,-.~.:- ........................... "g,,;, ...... ........................................... ....................................... ~-~J .............................. i ......................................................................................... . .......................... ~j ...................................... r ....................... . " "'~1 ................. =': ....... 7..;"'.'. ............... ;'; ......... .:,."-:: .................................................. 1) FR[M LINEAR EXTRAPL~LATIO~.=":~'~£'~ii~F'~i~;~.§i~:i'~}~A:¥'~I~}'"'""':i'"'"'7' ......... '"" ....... ~'""-?' .... ~" ....... '-": 2) COI'4PUTER PROGRAM oPER. R...Y ...... " - SUN THR .. B. DATA C'ALCLILA'f I L'tN AND I NTERPOLAT1 ON :.!'.BY':: RAD I.U$ 'OF . C:L!RVATLIRE -' DATE 'OF SURVEY ..IANLIARY ()7., :1. ':-;' ;.."~: };' .. qK -8~ 7~UE NORTH -~s~o. oo -.~obo. oo -sob. oo .? --500~,00 --1000.00 ---1500.00 L-2000. O0 'RECEIVED F'EB 2 5 1987 AlaS~ Oil & G~s Cons. ~.~--"~" O. CO 500. O0 3000, CO . . . ~. b C,:'3. C ':tSCd 6_. qS~.~., !iNC. .JRNUfie'~ C7 ~9~- 4500. CC -. 6-000. CC 75C,3. 23 .~ 662i. i,I I , ! 503. CO / 8300. O0 REC.'E VED FEB 2'5 !.987 AlaSka Oil & Gas Cons. Aritho, -. STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ,SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate [] Plugging ,9 Perforate [] Pull tubing Alter Casing .rq, Other ~ COHPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 60' 3. Address 6. Unit or Property name P.O. Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 2271' FNL, 2085' FEL, Sec.17, T13N, R9E, UM At top of productive interval 1426' FSL, 1898' FWL, Sec. 17, T13N, R9E, UM At effective depth 1335' FSL, 1829' FWL, Sec.17, T13N, RgE, UN At total depth 1288' FSL, 1792' FWL, Sec.17, T13N, RgE, UM 7. Well number 3Q-11 8. Approval number 7-62 . 9. APl number 50-- 029-21676 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical Effective depth: meas u red true vertical 7265'MD 6628'TVD 7148 ' MD 6527 ' TVD Casing Length Size ., Conductor 80 ' 16" Surface 3771 ' 9-5/8" Producti on 7204 ' 7" Perforation depth: measured true vertical None None feet feet feet feet Plugs (measured) Junk (measured) None None Cemented 1875# Poleset Measured depth ll5'MD True Vertical depth 115'TVD 900 sx AS IV & 3808'MD 3731'TVD 275 sx Class G & 30 sx Dry cmt on top 300 sx Class G 7239'MD 6606'TVD 175 sx AS I Tubino (size, grade and measured depth) 2-7/8", L-80, tbg w/tail @ 6845' Packers and SSSV (type and measured depth) HRP-1-SP pkr @ 6814' & FVL SSSV @ 1789' 4' . 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Wel 1 Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run J~ GYRO 15. I hereby certify that the foregoing is true and correct to the best of my knowledge (DAN I ) SW02/003 Form 10-404 Rev. 12-1-85 Submit in Duplicate ARCO O:1 and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filial Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be subnlltted a!86~wheft operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "FInsl Report" form may be used for reporting the entire operation if space is available.: ; ' District Alaska Field Kuparuk River Auth, or W.O. no. AFE AK1657 Nordic #1 Operator ARCO Alaska, Inc. Spudded or W.O. begun Complete 1/20/87 County or Parish Lease or Unit ITte Date and depth as of 8:00 a.m. North Slope Borough 1/21/87 ADL 25512 Completion API 50-029-21654 IA.R.Co. W.I. 56.24% IDate 1/19/87 Complete record for each day reported Accounting cost center code State I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 1630 hrs. Alaska IWell no. 3Q-11 7" @ 7239' 7148' PBTD, MU tbg hgr 10.0 ppg brine Accept rig @ 1630 hrs, 1/19/87. ND tree, NU & tst BOPE to 3000 psi. RIH w/211 jts, 2-7/8", 6.5#, L-80 EUE 8RD AB-Mod tbg ~ w/SSSV @ 1789', HRP-1-SP pkr @ 6814', TT @ 6845'. 7" @ 72~' 7148' PBTD, RR 6.8 ppg diesel Set pkr @ 6814'. Tst tbg to 2500 psi, pkr to 2500 psi & SSSV @ 1000 psi. ND BOPE, NU & tst tree to 250/5000 psi. Displ well w/diesel. RR @ 1200 hrs, 1/20/87. Old TD New TD Released rig Date 1200 hrs. Classifications (oil, gas, etc.) Oil PB Depth 1/20/87 Kindofrig Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data 7148' PBTD Rotary Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day ~mp size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The ab.~-'f~ correct Signat% / Da~/ Title sF~; f~;~e~lruer~e~ra~i~nnu~, sedi~tir~nbU~i0°,n' ~ ' Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. j Pag] no. DlvllJon of AtlsntleRIchfleldCompa~y ARCO Alaska, In ..... '~ Pos! Office b~... 100360 Anchorage, Alaska 99510-0360 Telephone 907 2']6 1215 Date: February 9, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the fo/lowing items. and return, one SiEned copy of this transmittal. · 3Q-13 1-9-87 6162-8074 3Q-14 1-9-87 6416-8392 3Q-11 1-9-87 5158-7127 3Q-9 1-8-87 7113-7760 3Q-12 1-9-87 5127-7284 3Q-lO 1-8-87 5418-8240 Transmittal # 5909 Please acknowledge receipt Receipt Acknowledged: BPAE Chevron (+ sepia) Unocal (+ sepia) NSK L. Johns ton I,V[I)./ ].31.987 Mobil (+ sepia) SAPc (+ sepia) Drilling , :~.~, .,.~.~.~?.= ARCO Alaska, /nc. Is a Subsidiary of AllanticRIchfleldCompan¥ STATE OF ALASKA ALASK,~ OIL AND GAS CONSERVATION COMM,~$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ~ Operation Shutdown ~ · Re-enter suspended well iTM' Alter casing [] Time extension ~ Change approved program ~ Plugging [] Stimulate [] Pull tubing ~ Amend order '~ Perforate ~ Other 2. Na~-~c%f Ooerator Aqaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4, Location of well at surface 2271 ' FNL, 2086' FEL, Sec. At top of productive interval 1345' FSL, 1868' FWL, Sec. At effective depth 1346' FSL, 1783' FWL, Sec. At total depth 1297' FSL, 1744' FWL, Sec. 17, T13N, R9E, UM 17, T13N, R9E, UM (approx.) 17, T13N, R9E, UM (approx.) 17, T13N, R9E, UM (approx.) 11. Present well condition summary Total depth: measured true vertical 7265 ' MD feet Plugs (measured) 661 8 ' TVD feet 5. Datum elevation (DF or KB) RKB 60 fe~ 6. Unit or Property name Kuparuk River Unit 7. Well number 30-11 8. Permit number 86-188 9. APl number 50t 029-21676 10. Pool Kdparuk Oil Pool None Effective depth: measured true vertical 7148 'MD feet Junk (measured) None 6519 ' TVD feet Casing Length Size Conductor 80 ' 1 6" Surface 3771' 9-5/8" P roducti on 7204 ' 7" Cemented Measured depth Conductor report 115'MD not received 900 sx AS IV & 275 sx Class G 3808'MD 30 sx Dry cmt on top 300 sx Class G 7239'MD Rue Verticaldepth 115'TVD 3729 'TVD 6596'TVD Perforation depth: measured No n e true vertical None Tubing (size, grade and measured depth) Packers and SSSV (type and measured depth) None None 12.Attachments WELL HISTORY Description summary of proposal Detailed operations program _ BOP sketch - 13. Estimated date for commencing operation January, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby c~tify that the foregoing is true and correct to the best of my knowledge Signed ,~~ ~, ~(/~/~/3~ .; ' ./.~,.~ ~.~_~,. Title Ass°ci ate Engineer Commission Use Only 5A/195 Conditions of approval Notify commission so representative may witness I Approval No. ~ Plug integrity ~- BOP Test ~_ Location clearancel Date Approved by Form 10-403 Rev 12-1-85 · Commissioner by order of the commission Date/~,~ ~?~ ,~ Submit in triplicato Well History'-- after a well la spudded or workover operations are started. giving inclusive dates only. parish or borough North Slope Borough '~ield . Lease or Unit Kuparuk River I ADL 25512 Auth. or W.O. no. ITitle AFE AK1657 Drill Istate Alaska IWell no. 3q-ll Doyom 9 AP1 50-029-21654 Operator IARCO W.I. ARCO Alaska, Inc. I Spudded 12/16/86 1500 hrs. . , 56.24% for each day reported 'PU new-bit & RIH. WT 4, PH 10.0, WL 14.8, Sol 3 /8" csg w/900 sx AS IV lead, 335 bbls @ 11.8 PPS. Tail w/275 sx Class G, w/21 SI & 21 9-46, 56 bbl @ 15.8 ppg. Pump plug w/2000 psi. CIP @ 0900 hfs, 12/18/86. ND diverter, NU stack. Test BOPE. RIR. Drlg FC + 10' new hole. to 12.5 ppg EMW. Drlg 3835 - 4725'. Plugged Jet. bearing section and bit. 16"@ 115' (2551') POOR & PU Dynadrill PV 22, YP 24, PR 9.0, WL 14.2, Sol 10 Ri. @ .1130, 12/16/86, N~' B~.~ mix mud,~. ~: ~.~, ~v 2~, ~ 2~, ~a 8.5, ~, s.s. sot~;: ... , : _' .~1~i::~, :6 , S59:3g, 1486:94 ~, -8.33 Va, .7 , ~60.8~, 2490.87 T~, -9.33 rS, , 85~.8~ 3105.67 ~,' 42.65 rS, 38.g~B~¢~'.;--:Ig.~4~:;.: . s4~.1~, ~84.14 ~', 10~,05 va, 5~, 3454.73 ~, 181,12 VS~' 132.028, ' ~618.19 T~, 275.64 rS,. ~01.82S, 3679.69 ~, 314.94 V8,'231.558, ., Perfom LOT .... . . ~6 Date Title 1 I Drilling Supervisor operation if space is available. Accounting District Alaska Field Kuparuk River Auth. or W.O. no. AFE AK1657 County or Parish North Slope Borough Lease or Unit State Title Alaska I Well no. ADL 25512 3Q-ll Drill Doyon 9 Operator Spudded or W.O. begun Spudded Date and depth as of 8:00 a.m. AP1 50-029-21654 IA.R.Co. W.I. ARCO Alaska, Inc. 56.24% IDate 12/16/86 Complete record for each day reposed 12/20/86 thru 12/22/86 Iota number of wells (active or inactive) on this~ Dst center prior to plugging and I bandonment of this well our I Prlor status tf a W.O. I 1500 hrs. 7" @ 7239' 7265' (2540') RR WT 9.9+, PV 16, YP 12, PH 9.0, WL 5.2, Sol 12 MU BHA, orient RIH drlg. 4725' - 4909'. POH LD motor sections (2). PU motor sections RIH. Drlg f/4909'-7265'. Circ& POH for 8-1/2" logs. LD MWD & turbine. RU SOS & run open hole logs. RD SOS i RIH. RIH w/wipe trip. Circ & cond. Spot 10% diesel pill. POHLDDP. RU & RIH w/7" csg. Cmt 7" csgw/100 sx (38 bbl), 50/50 @ 11.7 ppg, tailed w/200 @ 15.8 ppg. ND BOPE - set slips - NUwellhead & @ 0600, 12/22/86. 3924', 32.9°, S40.6W, 3826.11TVD, 408.89VS, 303.14S, 275.70W 4267', 32.5 4613', 35.6 5119', 35.0 5558', 33.4 5873', 32.8 6316', 33° 5873', 32.8 6316', 33.0 7160', 31,0°, S40.0W, 4114.75TVD, 594.10VS, 444.76S, 395.56W S43.2W, 4401.39TVD, 787.51VS, 589.29S, 524.15W S40.0W, 4814.36TVD, 1079.45VS, 807.92S, 718.25W S39.2W, 5177.43TVD, 1326.16VS, 998.04S, 875.53W S39.2W, 5441.31TVD, 1498.17VS, 1131.34S, 984.25W S38.8W, 5813.27TVD, 1738.79VS, 1318.35S, 1135.68W S39.2W, 5441.31TVD, 1498.17VS, 1131.34S, 984.25W $38,8W, 5813.27TVD, 1738.79VS, 1318.35S, 1135'.68W S38.5W, 6528.98TVD, 2186.01VS, 1667.62S, 1415.00W I PB Depth Kind of rig 12/22/86 IType completion (single, dual, etc.) S ingle Official reservoir name(s) Kuparuk Sands Old TD Reiea~led rig 0600 hrs. Classifications (o11, ga~. etc.) Oil PrOducing method Flowing POtential test data New TD Date ,, Nell no, Date Reservoir Producing IntervalOil or gas Test time Production OII 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 For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Date ]Title I Drilling Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 20, 1987 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 i Anchorage, AK 99510-0360 Transmittal #5891 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH Finals: (1 blueline unless otherwise specified) 3Q-12 2" & 5" FDC Raw 12-14-86 5900-7458 & 5" DIL 12-14-86 1000-7484 Cyberlook 12-14-86 6800-7400 3Q-11 2" & 5" FDC Raw 12-20-86 3810-7238 2" & 5" FDC Porosity 12-20-86 3810-7238 ~ ~ 2" & 5" DIL 12-20-86 3810-7264 ~ Cyberlook 12-20-86 6750-7200 3Q-10 2" & 5" FDC Raw 12-27-86 4650-8356 ~/__ 2" & 5" FDC Porosity 12-27-86 4650-8356 2,' & 5" DIL 12-27-86 4371-8382 ~berlook 12-27-86 7800-8300 25" Density High Resolution Passes 12-27-86 6678-8223 Receipt Acknowledged: DISTRIBUTION: NSK Drilling · , ska 0ilD&a~l~0Cr;;;· Commission L. Jdhnston (vendor pkg) Vault (f ilm)4. ARCO Alaska, Inc, Is a Subsidiary of' AllanlicRIchfieldCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA' INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE January 2, 1987 TRANSMITTAL # 5867 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tape + Listing,: 3Q-11 12-20-86 #72132 3Q-lO 12-27-86 #72139 Receipt Acknowledged: DISTRIBUTION: Wetherell ARCO Alaska. Inc. is a Subsidiary of AtlanticRic~tfieldCompany December 5, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box !00360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: Kuparuk River Unit 3Q- 11 ARCO Alaska, Inc. Permit No. 86-188 Sur. Loc. 2271'F~L, 2086'FEL, Sec. 17, T13M, R9E, UM. Btmhole Loc. 1206'FSL, 1757'FWL, Sec. 17, T13N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe'of the conductor pipe. Ve~ truly ~urs, Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF /"HE CO~ISSIOM dlf Enclosure cc: Department of Fish & Game, I'{abitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery STATE OF ALASKA ALASKA ...,L AND GAS CONSERVATION C,,_,vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Typeofwork Drill ~ Redrill ~1 lb. Type of welI. Exploratory [] StratigraphicTest [] DevelopmentOil/~' Re-Entry [] Deepen Service [] Developement Gas [] Single Zone~ Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool &RC0 Alaska, Inc. RKB 60', PAD 23' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oi 1 Pool P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25512 ALK 2553 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2271 'FNL, 2086'FEL, Sec.17, T13N, R9E, UN Kuparuk River Unit Statewide At top of productive interval 8. Well nu .tuber Number 1345'FSL, 1868'FWL, Sec.17, T13N, R9E, UM 3Q-11 #8088-26-27 At total depth 9. Approximate spud date Amount 206'FSL, 1757'FWL, Sec.17, T13N, R9E, UM 12/23/86 $500,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth(MD and TVD) property line 3Q-1 2 7265 'MD 2086' @ Surface feet 25' @ surface feet 2560 16579,TVD) feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth2664 feet Maximum hole angle 35 0 Maximum surface 2223 psig At total depth (TVD) 31 60 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) _ . 12-1/4"9-5/8" 136.0# J-55 BTC 37R9' 35' 35' ~,R?/~' ~,7c,/~' IORO .~x A.% III HF-ERW 275 sx Class G blend 8-1/2" 7" i26.0# J-55 BTC 7231' 34' 34' 7265' 6579' 200 sx Class G(minimum HF-ERW TOC 5(10' abov," top of Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ~:,~ ,~7 i~, Conductor " -~ J~,?',~ ~,~ Surface £'" '""~ (') Intermediate ~ Production Al3?; Oil ~ Liner a~ , ',. Perforation depth: measured true vertical 20. AttachmentSfluid Filing Timfee__e~v Property plat[] []RefractionBOP Sketch ~ Diverter Sketch ,~ Drilling program,,~ Drilling program .~L s depth plot analysis [] Seabed report [] 20 AAC 25.050 requirements 21. I hereby cert,[,f~at the foregoing is true and correct to the best of my knowledge ?// //~,%.~.~,.,,,c,~.. ~, Z~.~/ Regional Drilling Engineer Signed Title Date / ~, c, / - ,,-~. Commission UseOnly (RHE) PD/019 I APl number I Approval date See cover letter Permit Number ¢~'¢ '*f' %' ~' 50-- ~'L~ '~" ~']'7I for other requirements ~ ..... -- ~ 12/05/86 Conditions of approval Samples required [] Yes [] No Mud Icg required M Yes ~' No Hydrogen sulfide measures [] Yes [] No Directional survey required ~' Yes [] No Required worki~...~rq¢~~M~ 5M; [] 1OM; [] 15M Other: __~/~,~~ ----,, by order of Approved by ~,~ ' . _?/ , tk "' Commissioner the commission Date Form 10-401 Rev. 12A-85 ' / Subrr~t triplicate I I~ ' ' ' ! : ~ ii . . , : L : ~A . i ; . $~.~ 4--. I ~ ~_._~...., ..... 4;-~ ~: ~ ~ ~d-eI~ ' i ~" ~--~-*~ ...... "*"-+'-'~ ...... ~--kl'--~ ....... i---I-.~-'~ ............ ~-~ .... t'-'+ ........ ~ , · , . + ~ ~ ~ ~ I , : ....... ,. .... : ..... ~.., : ........ ~ : '. ~ ' ~ ~ ! ' ~~. :~: , ,':. ::, :/::: iit ~!~'~'''~ :~;: ;:::~":: ":' . ;. · . :~~ ~ ~:~"~: , . ..... ~i~ '; ....... , , , ...... ' ~ .... i~ ~ ii~ ' ~ ,:~ '~ ' ., i. ': ' ~..L.I._L-L.~ . . . 7 6 DIAGRAM #1 ,13-5/8" ,5003 PSI RSRRA BOP STAQ< I. 16" - 2000 PS! TAI~<CO STARTING HEAD 2. I1" - 3000 PSI CASING HEAD 5. I1' - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIP~ 5. 13-5/8' - 5000 PSI DRILLING SPOCL W/CHCKE KILL LI~ES 6. 13-5/8' - 5000 PSI DOUBLE ~ W/PIPE P~ ON TOP, ?. 13-5/8' - 5000 PSI AI~ ACCUVllLATOR C,APACITY TEST I. CHECK AbD FILL AC~TOR RE~OIR TO P~ LEVEL WITH HYI~IC FLUID. 2. AS~ THAT AC~TOR P~ IS 3~300 PSI WITH 5. OBSERVE TI~E, THEN CLOSE AlL UI~TS SIMLITN~OUSLY ALL UNITS ARE CLOSED WITH CHARGING PU~P OFF. 4. RECORD ON NADC REPOirTo THE AO35~rABLE LO~ER LIMIT IS 45 SE~ CLC~ING TIldE ~ I~00 PSI REMAINING 4 13-5/8" BOP STACK TEST !. FILL BC~ STACI( AI~ ~ MANIFOLD WITH ARCTIC DIESEL. 2. OEO( THAT ALL LO(]( EX]AN ~ IN V~].LI-EAD ARE FULLY RETRACTED. SEAT TEST PLUG IN ~ELLHEAD WITH RUNNING Jl' AD~) RUN IN L~ SOREY~. LIhE VALVES ADJA~ TO B~P ~TAC~. ALL OTHER 4. PRESSJRE UP TO 2.50 PSI ~ HOLD FOR I0 MIN. IN- CREAS~ PRES,SURE TO ~ PSI MN) HOLD FOR I0 MIN. BLEED PRE&SURE TO 0 PSI. LI~E VALVES. CLCEE TOP PIPE RAM~ ADI) HOR VALVES ON KILL AFl) ~ 6. TEST TO 2.50 PSI ~ 5000 PSI AS IN STEP 4. ?. C~NTI~ TESTING ALL VALVES, LI~r~s, AN) CliO(ES WITH A 2.50 PSI LC~ ~ 5000 PSI HIGH. TEST AS IN sTEP 4. ~ NOT ~~ T~T ANY THAT I0. CLOSE BLI~E) RAMS ~ TEST TO 2,50 PSI AhD 5000 PSI. II. OPEN BLIFt) RAMS A~D RETRIEVE TEST PLUG. MAKE SURE MANIFOLD A~D LIhES ARE FULL OF NO~F+'REEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAI~i)PIPE VALVES. KELLY, KELLY COC~S, DRILL PIPE SAFETY VALVE, A~D INSIC~ BOP TO 250 PSI 3000 PSI. 13. RECORD TEST I~FCI~VATION ON BLONoLrr PREVENTER TEST FORM, SIONo A~D SE~D TO DRILLING SUPERVISOR. 14. PERF~ CC~E BOPE TEST AFTER NIPPLING UP A~D WEEKLY THEREAFTER FUNCTIONALLY OPERATE BOPE DAILY. 510084001 REV. 2 MAY 15,, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate AP1 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degas~er - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. 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. LWK5/ih KUPARUK RI VER UNIT 20". DIVERTER SCHEMATIC ,j L DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD ,5. FMC DIVERTER ASSEM§LY WITH TWO 2-1 / 16" 2000 PSI BALL VALVES 4. 20" 2000 PSI DRILLING SPOOL W/10" OUTLETS 5. 10" HCR BALL VALVES W/lO" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED, OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN ~E,~ii~!:,i"::: :.,.::~...~ ~. UNDER ANY CIRCUMST^NCES JG 11-3-86 6 DIAGRAM #1 13-5/8" ,5(X~ psi RSRRA BOP STACK ~" I. 16" - 2000 PSI TAPCO STARTING HEAD 2. il" - 3000 PSI CASING HEAD II" - 3000 PSI X 15-5/8" - 5000 PSI SPACER SPOOL 4. 15-5/8" - 5000 PSI PIPE RAMS 5. 15-5/8" - 5000 PSI DRILLING SPOOL W/O-tOKE ~ KILL LI~ES G. 15-5/8" - 5000 PSI DOUBLE RA~ W/PIPE RA~S ON TOO, BLIhD RA~ ON BOTTC~. 7. 15-5/B" - 5000 PSI A~ ACCLM, JLATOR CAPACITY TEST i. CHECK AbD FILL A(X~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSUI~ THAT ACCL~TOR PRE,S~ I8 306)0 PSI WITH 1500 PSI D(~TREA~ OF THE REGULATOR. 3. OBSERVE TINE, THEN CLOSE ALL UNITS SImULTAnEOUSLY A~E) RECORD THE TINE A~E) PRESSURE REIVt~INING AFTER ALL UNITS ARE CLOSED WITH CHARGING PLOP OFF. 4. RECORD ON NADC REPORT, THE ACCEPTABLE LO/~.R LIWIT IS 45 SE~ CLOSING TINE A~E) 1200 PSI RSVI~INING PRESSURE. 5 4 2 I 13-5/8" BOP STACK TEST i. FILL BOO STACK AhD Q-N]<E MANIFOLD WITH ARCTIC DIESEl.. 2. CHECK THAT ALL LOCK D(~ SCRE~ IN ~Ei. LI~ ARE FULLY RETRACTED. SEAT TEST PLUG IN ~Ei. LHEAD WITH RUINING JT AI~ RUN IN LO(]~ SCREWS. CLOSE A~ PREVENTER A~D ~AL KILL AhD CHOKE LIhE VALVES ADJACENT TO BOO STACK, ALL OTHER VALVES AND CHOKES SHC~ BE 4. PRESSURE UP TO 250 PSI A~ HOLD FOR I0 MIN. IN- CREASE PRESSURE TO 3000 PSI Ahl) HOLD FOR I0 MIN. BLEED PRESSURE TO 0 PSI. 5. OOEN AI~ PREVENTER AhD ~AL KILL AhD CHOKE LIHE VALVES. CLOSE TOO PIPE RA~ AhD HCR VALVES ON KILL AND CHOKE LIhES. 6.TEST TO 250 PSI AhD 3000 PSI AS IN STEP 4. ?. CONTINUE TESTING ALL VALVES, LIhES, AbE) CHOKES WITH A 250 PSI LO~ AhD 3000 PSI HIGH. TEST AS IN STEP 4. O0 NOT PRESSURE TFRT ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. ODI.Y FI~TION lEST CHOKES THAT DO NU! FULLY CLOSE. 8. OOEN TOO PIPE RA~S AhD CLOSE BOTTCM PIPE RA~S. TEST BOTT(]Vl PIPE RA~S TO 250 PSI AI~E) 3000 PSI. 9. OOEN BOTTC~ PIPE RA~S, BACK OUT RUbbING JT AhD PULL OUT OF HOLE. ~0. CLOSE BLIhD RA~ AhD TEST TO 250 PSI A~D 3000 PSI. II. OOEN BLIND RA~S AND RETRIEVE TEST PLUG. MAKE SURE MANIFOLD AhD LI~ES ARE FULL OF NON-FREEZING FLUID. SET ALL VALVES IN DRILLING POSITION. 12. TEST STAll]PIPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, AND INSIDE BOO TO 250 PSI Ahl) 3000 PSI. ~3. RECORD TEST IhFC~ATION ON BLOWOUT PREVENTER TEST FOR~, SIGN, AND SEhD TO DRILLING SUPERVISOR. 14. PERFORM COV~LETE BOOE TEST AFTER NIPPLING UP AhD ~EEKLY THEREAFTER FUNCTIONALLY OOERATE BOPE DAILY. 510084001 REV. 2 MAY 15,, 1985 Density DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up to TD 10.3 PV 15-30 5-15 9-13 YP 20-40 8-12 8-12 Viscosity 50-100 35-40 35-45 Initial Gel 5-15 2-4 3-5 10 Minute Gel 15-30 4-8 5-12 Filtrate API 20 10-20 pH 9-10 9.5-10.5 9.5-10.5 % Solids 10± 4-7 9-12 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. 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. LWK5 / ih GENERAL DRILLING PROCEDUam KUPARUK RIVER FIELD DEVELOPMENT WELLS 1. Move in rig. 2. Install Tankco diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8." casing. 5. Install and test blow out preventer. Test casing to 2000 psig. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide i00' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement 7" casing. Pressure test to 3500 psig. I1. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. Run cased hole logs. 15. Move in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plug back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. 19. Change over to diesel. 20. Flow well to tanks. Shut in. 21. Secure well and release rig. 22. Fracture stimulate. SHALE SHAKERS- DEGASSER PIUD CLEANER .~. STIR ~..~ STIR _~ STIR CENTRIFU(IE TYPICAL MUD .SYSTEI"I SCHEMATIC LWK4 / ih ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 19, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - 3Q Pad (Wells 1-16) Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/dmr GRU1/44 Enclosure If ARCO Alaska, Inc, is a Subsidiary of AllanticRichlieldCompany 17 VICINITY ~ S~ld,.E ~ I" · 2 MII.[~ ALL WELLS LOCATED IN SEC. 17, TI3N, RgE, UMIAT MERIDIAN. lw,"l '¥' 'ASPs",,'X' I 16,025,875.23 515, 959.92 2 J6~025 ,867. 50 515, 984.20 4~ J6,025,861.28 516,008.42 J6,025,855.29 516,0~ J6,025,849.~6 516,056.99 }6,0~,843.~7 516,081.28 7 ~6,025,8~7.~ 51~,105.64 8 }6,025, 851.43 516,1~.72 I0 ~6,025, ~7.25 51~,226.~ II ~6,025, 801. ~1 51~,251.42 12 }6,025, 7~.~ 516,275.~ 13 /6,o25, 789.31 H 16,025, 783.4T 15 16,025, T77.44 516,~.Z0 16 16)025, 7Tl.~ 51~,~.31 / ! LA, TITUDE 70° 2 8' 54.758" 70° 28'54.701" ?0° 28' 54.639" 7(3° 28' 54. 70° 28' 54.52 i" ?0° 28' 54.462" ?0o 2e'54.40~" 7'0° 28' 54. 70e 28'54. IS5" ?o° 28' 54. to~" ?o° 28' 54.o44" 70° 28' 53.9~?" ?0e 2B' 53.925" ?~ 2.' 55. 8~7" ?0o 28' 55.80~" ?0~ 28' 5~. ?49" NOTES: I. AU.. COOnQmATE$ Anf: A.S.R, ZONE 2.~L. DESTA~C~ ~0WN M( TRUE. 3.E~~S ~ ~P. LS.L. 4.~F. FIELD 6.~RIZONTAL ~'TIO~ ~O ~KS PER LHD LONGITdDE i 149052, I0.5 I 149o S~' 09.798'' 149° 52'09 14F 52'08.376" ~4~° 52'07.658" ~4~ 52'0e.944" 14~ 52'0e.220" 14~' aa' 05. ~o" 14~52'03.370" I~ ~'~ .665" 14~ 52'01.942" I~ ~'~. 520" 14~ 51' ~. 814 '14~ 51' 58. Dlst. F.N.L. !, 2199' 2205' 2211' 2217' 2223' 2229' 22:~' 2241' 2299' 2271' 2277' 2213' 22e~ 22~ 2501' 2377' 2352' 252e' 2304' 2255' 2231' 2207' 21:54' 2110' 2085' 20~.' 2037' ams' " I"1 ' I · ~,,~ 17.1 17.1 17. I 17.2 17.2 17.$ 17.3 17.4 17.5 17. S 17.5 17.5 IT.5 21,1 21,1 21.1 21,1 21,9 21.9 21.6 21.9 I HEREBY CERTIFY THAT I AM PRO~RLY REGISTERED AND LICENSED TO PRAC- TICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY SUPERVISION~ AND THAT ALL DIMENSK)NS AND OTHER DETAILS ARE CORRECT AS OF 11/2/86. D.S. 3Q WELL CONDUCTOR ASBUILT DATEr I I/IO/N III , J c,,,K , ,NIK,, 6. 317-d$ , , ~{ECK LIST FOR NEW W~.T, PERMITS ITEM APPROVE DATE (1) Fee_~f~ ..... / ~ ~ ~.:~ ~ 1. / (" 8) (9 thru 13). .... (14 t~ 22) '(23 thru--78~ (6) (TI'HER /~,~, (29 thru 3'1) (6) Add: ,/~7/.~///, ~.~.~ Company : ............ Lease & Well No ~.~: ~ ~.:~.~ . Is the permit fee attached ........................................... ~'~ , ~ 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... e 10. 11. 12. 13. Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ~ e e · · e e . · · · e · e e e · e · · e · · I · · · · · · · · · · · · · · ~,~ rF' Does the well have a unique name and number ......................... ~,- 14. 15. 16. 17. 18. 19. 20. 21. 22. Is conductor string provided ......................................... ~ Will surface casing protect fresh water zones ....................... Z~ Is enough cement used to circulate on conductor and surface ......... . .,f~. 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 abandor~t procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ ~ 23. 24. 25. 26. 27. 28. For 29. 30. 31. Is a diverter system required schematig'and ................... iig '&2'g &i &g : Is the drilling fluid program adequate__ Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~ ~D C~D psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. ~ - exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented-- 32. Additional requirements ............................................. Geology: Engineering: .......... JAL rev: 07/18/86 ~.n!! POOL INITIAL CLASS STATUS UNIT NO. ON/OFF SHORE Additional Remarlcs: ,-3q-lt A,-- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. LIS TAPE VERIFICATION LISTING YP OlO.H02 VERIFICATION LISTING PAGE :~ REEL HEADER ~ ERVICE NAME :EDIT ,ATE :86/12/28 ~RIGIN : iEEL NAME :149474 :ONTINUATION'# :01 'REVIOUS REEL : iOMMENTS :LIBRARY TAPE TAPE HEADER ~ ;ERVICE NAME :EDIT tATE :86/12128 IRIGIN :0000 ~APE NAME :2132 ~ONTINUATION # :01 ~REVIOUS TAPE : ;OMMENTS :LIBRARY TAPE ~ILE HEADER ~ NAME :EDIT .001 RVICE NAME : RSION # : : iXIMUM ~EN?TH : 1024 TYP ~REVIOUS FILE : INFORMATION RECORDS ~NEM CONTENTS : ARCO ALASKA, INC. : KUPARUK RANG: 9E ~OWN: 13 N SE C T: ! 7 ~OUN: NORTH SLOPE SjAT: ~ ALASKA CTRY: USA MNEM CONTENTS UNIT TYPE CATE SIZE CODE 000 000 01'8 065 000~ 000 006 0'65 00'0 000 008 065 000 000 002 065 000 000 004 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE PRES: E 000 000 001 065 ~* COMMENTS V,P OlO.H02 VERIFICATION LISTING PAGE 2 SCHLUMBERGER ALASKA COMPUTING CENTER QMPANY = ARCO ALASKA INC ~,ELL : 3Q-11 :'IELD = KUPARUK = NORTH SLOPE BOROUGH : ALASKA NUMBER AT ACC: 72132 #1~ DATE LOGGED: 20-DEC-86 IP: L. B. CUDNEY ~SING [PE FLUID NSITY SCOSITY = 9.625" @ 3808' - BIT SIZE =. 8.5" TO. 7265' = LSND POLYMER = 9.9 LB/G RM = 4.220 ~ 64.0 DF : 39.0 S RMF = 4.500 @ 64.0 DF = 9.5 RMC = 2.660 @ 64.0 DF = 4.6 C3 RM AT .BHT = 1.958 @ 146. DF UID LOSS iTRIX SANDSTONE THIS DATA 'HAS fl,'OT BEEN DEPTH SHIFTED - OVER,LAYS~:~.~FIELD PRINTS .VP OlO.H02 VERIFICATION LISTING PAGE 3 SCHLUMBERGER LOGS INCLUDED WITH THIS MAGNETIC TAPE: DUALINDUCTION SPHERICALLY FOCUSED LOG (DIL) DATA AVAILABLE: 7286' TD 3790' FORMATION DENSITY COMPENSATED LOG (FDN) COMPENSATED NEE~TRON LOG (FDN) DATA AVAILABLE: 7286' TO 3790' GAMMA RAY IN CASING (GR.CNL) DATA AVAILABLE: 3875' TD 1000' ~, DATA FORMAT RECORD ~ ENTRY BLACKS . TYPE SIZE REPR CODE ENTRY · 2 I 66 0 4' I 66 l ~" 8 4 73 6 0 , ,' 9 4 65 .lIN '~"" 16 1 66 1 :~ 0 1 66 0 UM SPECIFICATION BLOCKS iEM SERVICE SERVICE UNIT API AP1 API AP1 FILE SiZE SPL REPR ID ORDER ~ LOG TYPE CLASS MaD NO. CODE PT FT O0 000 O0 0 0 4 LU OIL OHMM O0 220 O1 0 0 4 D DIL OHMM O0 120 46 0 0 4 M DIL OHMM O0 120 44 0 0 4 OIL MV O0 010 O1 0 0 4 PROCESS (OCTAL) 1 58 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 1 68 00000000000000 VP OlO.H02 VERIEICATION LISTING PAGE 4 R R ALI HOB ~RHO .AT iRA IPHI [~NL DIL GAPI O0 310 O1 0 FDN GAPI O0 310 01 0 FDN IN O0 280 O1 0 FDN G/C3 O0 350 02 0 FDN G/C3 O0 356 01 0 FDN O0 420 O1 0 FDN O0 000 O0 0 FDN PU O0 890 O0 0 FDN PU O0 890 O0 0 FDN CPS O0 330 31 0 FDN CPS O0 330 30 0 CNL GAPI O0 310 O1 0 DATA 7286-.5000 SFLU -3l. 5000 GR 2.6074 DRHO 23.2910 DPHI -999.2500 7200.0000 SFLU -33.5000 GR 2.4746 DRHO 34.0820 DPHI -999.2500 7100.0000 SFLU -30.5000 GR 2,4141 DRHO 40.0391 DPHI -999.2500 7000.0000 SFLU -14.0000 GR 2.3,848 DRHO 32.0801 DPHI -999.2500 6900.0000 SFLU -19.0000 GR 2.5313 DRHO 32,0313 DPHI -999.2500 6800.0000 SFLU -23.0000 GR 2.4043 DRHO 43.7500 DPHI -999.2500 6700.0000 SFLU 12.9922 GR 2.3744 69.8750 -0.0488 2.5902 2.9574 101.0625 0.10'84 10.6387 2.5756 102.6250 0.0469 14.3078 15.1844 77.6250 O.O1T1 16.0832 2.9134 126.0625 0.0439 7.2062 3.4396 91.8750 0.0933 14.8996 4.4765 105.8125 ILO GR NRAT NCNL ILD GR 'NRA T NCNL ILD GR NRAT NCNL ILO GR NRAT NCNL ILD GR NR AT NCNL ILD GR NRAT NCNL ILD GR 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 4 1 2. o 9 8 3 69. 8750 2.3086 1950. 0000 3.01 101.06 3.0,4 2054.000 2.3743 102.6250 3.3477 1909.0000 14.8875 77.625.0 2.9121 2360.0000 3.0623 126.0625 2.9531 2620.0000 1.6417 91.8750 3.5547 1783.0000 2.2706 105.8125 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000000000000 68 00000'000000000 68 00000000000000 68 00000000000000 ILM 2.4699 CALl 8.6953 RNRA 3.7500 FCNL 520.0000 ILM 3.0419 CALI 9.0547 RNRA 3.2988 FCNL 622.5000 !LM 2.4015 CALI 8.7422 RNRA 3.7422 FCNL 510.0000 ILM 12.9874 CALl 8.9297 RNRA 3.3262 FCNL 709.5000 ILM 3.1002 CALI 9.4375 RNRA 3.4336 FCNL 763.0000 ILM 1.7418 CALI 8.7891 RNRA 4.1836 FCNL 426.0000 ILM 2.4171 CALI 8.9922 ,VP OiO.HOZ VERIFICATION LISTING PAGE 5 ~HOB 2.4102 DRHO IPHI 42.9199 DPHI ;R -999.2500 )EPT 6600.0000~ SFLU P -38.0625 GR HOB -999.2500 DRHO IPHI -999.2500 DPHI ~ -999.ZS00 )EPT 6500.0000 SFLU ~P -66.0625 GR ~HOB -999.2500 DRHO ~PHI -999.2500 DPHI -999.2500 71:!;TPT 64000000SFLU -61~5000 GR RHOB -999.2500 DRHO ~//HI -999:.2500 DPHI ~ -999.2500 PT 6300.0000 SFLU -59.562'5 GR 0 B 99=9 0 D RM 0 ~HI -9! 0 DPHI -999.2500 'PT 6200.0000 SFLU -43.53, I3 GR tOB -999.2500 DRHO ~HI '-999.2500 DPHI -999.2500 PT 6100.0000 SFLU -37.5313 GR )B 2.4355 DR. HO I 35.4492 DPHI -999.25010 '~PT 6000.0000 SFLU -43.5313 GR 08 2.4336 DRHO I 35.0098 DPHI GR -999.250~0 ~ DEpT S900. 0000 SFLU -49.0313 G R R,~OB 2.4238 DRH:O N~PHI 34.32.62 DPHI GR -999. 2500 DEPT 5800.0000 SFLU SP -53.0000 GR 0.0620 NRAT 14. 5445 NCNL 3.6357 ILO 249. 8750 GR -999.2500 NRAI' -999.2500 NCNL 3.8404 ILD 211.2500 GR -999.2500 NRAT -999.2500 NCNL 4.0057 iLO 138.00'00 GR -999.2500 NRAT -999.2500 NCNL 3.8329 tLD 142. 875.0 GR -999.2500' 'NRAT -999. 250'0 NCNL 2.3099 ILD 145.7500 GR -999.2500 NRAT -999.2500 NCNL 1. 8619 ILD 95.2500 GR 0.0464 NRAT 13.0059 NCNL 5.1214 ILD 87. 8750 G'R O. 0161 NRAT 13.1242 NCNL 3.79.08 I L D 125.6875 GR 0.0571 NRAT 13. 7160 NCNL 2.4235 ILO 91.6875 GR 3.5254 1846.0000 3.6906 -999.2500 -999.2500 -999.2500 2.9725 -999.2500 -999.2500 -999.2500 3.5'708 -999.2500 -999.2500 -999.2500 3.2709 -999-25,00 -999"~2500 -999.2500 2. 1956 -999. 2500 -999.2500 - 999.2500 1.96~26 95.2500 3 .14~6 1876100 0 2.892 9 87.8?50 2906:0 0 3.47'31 125.6875 31, 005 9 2314.0000 1.9282 91.68:75 RNRA FCNL ILM CALI RNRA FCNL ILM CALI R NRA FCNL ILM CALI RNRA FCNL ILM CALI R NRA F C NL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM C AL I 4.0313 457.5000 3.4967 -999.2500 -999.2500 -999.2500 3.0437 -999.2500 -999.2500 -999.2500 3.6598 -999.2500 -999.2500 -999.2500 3.3836 -999.2500 -999.2500 -ggg.2500 2.2623 -999.2500 -999.2500 -999.2500 1.9495 9.2891 3.5723 525.0000 2.7517 8.742.2 3.4668. 838.0000 3.6969 8.38,28 3.2129 720.0000 1.9708 8.5859 .VP 010.H02 VERIFICATION LISTING PAGE 6 IH06 2.4023 DRHO IPHI 40.2832 OPHI ~R -999.2500 )EPT 5700.0000 SFLU ;P -57.0313 GR ~HOB 2.4063 DRHO IPHI 40.869'1 DPHI ;R -999.2500 )EPT 5600.0000 SFLU ~P -59.5000 GR ~OB -999.2500 DRHO (PHI -999.2500 DPHI ;R -999.2500 )~PT 5500.0000 SFL'U ~,'P -53.0000 GR ~HOB -999.2500 DRHO ~HI -999.2500 OPHI ~ -999.2500 )E PT ~EPT ~:P H I PT ~"PH I DEPT SP RHOB ~PHI GR DE PT SP RHOB NPHI G'R DEPT SP 5400.0:0'00 SFLU -55.53t3 GR -999.2500 DR. HO -999.,2500 DPHI -999.2500 5300.0000 SFLU -56.03[3 GR -999.2500 DRHO -999.2'500 DPHI -999.250'0 5200.0000 SFLU -59.5313 GR -999.2500 DRHD -999.2500 DPHI -999.2500 5100.0000 SFLU -67.0625 GR -999.2500 DRHO -999.2500 DPHI -999.2500 5000.0000 SFLU -69.6250 GR -999.2500 DRHO -999.2500 DPHI -999.2500 4900.0000 SFLU -71.5625 GR 0.0288 NRAT 15.0180 NCNL 1.8607 ILD 125.1250 GR 0.0557 NRAT 14.7812 NCNL 2.4882 ILO 112.0000 GR -999.2500 NRAT -999.2500 NCNL 2.3773 ILD 110.5625 GR -999.2500 NRAT -999.2500 NCNL 3.1581 ILD 100.5000 GR -999.2500 NR'AT -999.2500 NCNL 2.2662 ILD 106.0000 GR -999.2500 NRAT -999.2500 NCNL 2.5084 ILO 102.8125 GR -999.2500 NRAT -999.2500 NCNL 3.3435 ILD 105.5625 GR -999.2500 NRAT -999.2500 NCNL 2.6370 ILD 102.2500 GR -999.2500 NRAT -999.2500 NCNL 2.3356 ILD 103.0000 GR 3.3477 2216.0000 1.8122 125.125{]~ 2. 3260 -999.25 -999.25 -999.25 2.490! -999.250 -999.25§ -999.25 3.2528 -999.250 -999.250~ -999.2509 2.6507 -999 2'50~ -999~250 -999.2500 2.2.867 -999.2500 -999.2500 -999.2500 3.2540 -999.2500 -999.2500 -999.2500 2.6761 -999.2500 -999.2500 -999.2500 2.4213 -999.2500 RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CA.LI 3.5508 624.0000 1.9047 8.6484 3.6309 552.5000 2.3499 -999.2500 -999.2500 -999.2500 2.5055 -999.2500 -999.2500 -999.2500 3.2674 --999.2500 -9.99.2500 -999.2500 2.5735 -999.2500 -999.2500 -999.2500 2.2863 -999.2500 -999.2500 -999.2500 3.2235 -999.2500 -999.2.500 -999.2500 2.6689 -9.99,2500 -999.2500 -999.2500 2.4049 -999.2500 ,VP 010.H02 VERIFICATION LISTING PAGE 7 IHOB -999.2500 DRHO tPHI -999.2500 DPHI ;R -999.2500 )EPT 4800.0000 SFLU ;P -73.06,25 GR I,HOB -999.2500 DRHO tPHI -999.2500 DPHI ;R -999.25.00 )EPT 4700.0000 SFLU iP -73.6250 GR HOB -999.2500 DRHO ~PHI -999.2500 DPHI ;R -999..2500 PT SFLU GR~ 10B DRHO HI OPHI ~PT 'HI }B I PT NP. HI GR RH 0 B NiPHI 4600.0000 -77.0625 -999. 2500 999. 2500 - 99,19.2'500 4500-0000 SFLU .7'8. :5§~2'5 GR' - 999,'25~00 DRH'O -999.2500 DPHI -999.2"500 ,,.,,oo.o. oo o -999.2 4300 0000 SFLU -78:5625 GR -999- 2,50'0 DRHO -999.2500 DPHI -999.2500 420,0.0000 SFLU -79*5625 GR -999.2500 DRHO -999.250'0 DPHI -999.2500 4100o0000 SFLU --81.50r00 GR --999.2500 DRHD --999.2500 DPHI --999.2500 4000.0000 SFLU -86.5000 GR -999.2500 NRAT -999.2500 NCNL 2.3154 ILD 96.6875 GR -999.2500 NRAT -999.2500 NCNL 2.4600 ILO 96~1875 GR -999*2500 NRAT -999.2500 NCNL 3.1361 ILO 88.5000 GR -999.2500 NRAT -999.2500 NCNL 2.7768 ILO 88. 2500 GR -999,2500' NRA'T -999,2500 NCNL 2.4436 I L O 76. 0000 GR -999.2500 NRAT -999.2500 NCNL 2.8525 ILO 90.937'5 GR -999.25.00 NRAT -999.2500 NCNL 1.9242 ILD 89.2500 GR -999.25'00 NRAT 999.2500 'NCNL 2.3227 ILO 93.8125 GR -999. 250,0 NRAT -999.2500 NCNL 3. 136,1 ~[LD 95.6875 GR -999.2500 -999.2500 2.2599 -999.2500 -999.2500 -999.2500 2.4131 -999.2500 -999.25'00 -999.2500 3.1690 -999.250"0 -999.2500 -999.2500 2 92~3 -999. ~ -999.2500 3359 -999 2.500 -999:2580 2.6877 -999.2500 -999.25Q0 999.2.500 I ~5o9 -.999 22:~:o o -999. 2500 -999. 2500 2 5761 -999i 2500 -999 2500 -999.25.00 3.6878 95.6875 RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL I,LM FCNL ILM CALI R'NRA FCNL ILM CAL.I RNRA FCNL ILM CALI RNR.A FCNL ILM CALI R'NRA FCNL ILM C AL I -999.2500 -999.2500 2.2643 -999.2500 -99'9.2500 -999.2500 2.3622 -999.2500 -999.2500 -999.2500 3.1103 -999.2500 -999.2500 -999.2500 2.8810 -999.2500 -999-2~0'0 -999.2500 2.3489 -999.2500 -999.2'500 -999.2500 2.222I -999.2500 -999.2500 -999.2500 1.9562 29999.2500 99,2500 -999.2500' 2.5509 -999.2500 -999.2500 -999.2500 3.4748 12.0938 ,VP nlO.H02 VERIFICATION LISTING PAGE IHOB 2.2930 DRHO IPHI 38.7207 DPHI ;R -999.2500 )EPT ;P EH 0 B IPH I )E P T ~HOB ~'PH I ~R PT [0 B I IB "HI HI ~HO B ~>PHI PT OB HI GR DEPT NPHI DEPT SP 3900.0000 SFLU -85 0000 GR 2:2773 DRHO 41.9922 DPHI -999.2500 3800.0000 SFLU -38.0000 GR 2'1387 DRHO 57.0801 OPHI 69.6875 3700.0000 SFLU -999.2500 GR -999.21500 DRHO -99'9.2500 DPHI 48.2500 3600.0000 SFLU -999.Z500 GR -999.2500 DRHO -999-2500 DPHI 50.6.875 3500.0000 SFLU -999.2500 GR ,-999.2500 DRHO -999.2500 DPHI 55.8750 3400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 43.8750 3300.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 45.1562 3200.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 ~DPHI 26.8281 3100.10000 SFLU -999.2500 GR 0.0327 NRAT 21.6461 NCNL 2.3850 ILO 92.8125 GR 0.0366 NRAT 22.5930 NCNL ZO00.O000 ILD 47.2187 GR -0.3257 NRAT 30.9965 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2'50'0 N'RAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -.999.25'00 NCNL -999.2500 ILO -999.2500 GR -999.25~00 NRAT -999.2500 NCNL -999.2500 ILD ' -999.2500 GR -999.2500 NRAT -999.2500' NCNL -999.2500 ILO -999.2500 GR 3.4707 2092.0000 2.263; 92. 812' 3.64 19.7 47. 218 4.25 1439 · -999.250~ - 999.2500 -999.2509 - 99 e. 250:0 -999. 2500 - 999- 2500 -999.2500 - 9 '99.2500 9 g 9.25 O0 -999. 2500 -999.2500 -999-2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999'2500 -999.2500 -999.2500 -99'9.2500 -999.2500 -99,9.2500 -999-2500 RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALl RNRA FCNL ILM CALI RNRA FCNL iLM CALl 3.7480 558.0000 2.2510 11.9922 3.8184 483.5000 2000.0000 8.5000 4.5742 314.5000 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .VP OlO.H02 VERIFICATION LISTING PAGE 9 ,~HOB -999.2500 DRHO tPHI -999.2500 DPHI ;R 42.9375 )EPT 3000.0000 SELU ;P -999.2500 GR {HOB -999.2500 DRHO dPHI -999,2500 OPHI ;R 24.9,219 )EPT 2900,0000 SFLU ~P -999.2500 GR {HOB -999.2.500 DRHO ~:PHI -999,2500 DPHI ;R 23.2656 oo.oooo !HI -999.2500 OPHI 36-:,,1 B 75 ~ ?PT 270'0.000'0 SFLU -999.'2500 lB DR'HO I DPHI · .PT 2600°,0000 SFLU -999. 2500 GR OB -999.,2500 DRHO HI -999.2500 DPHI 45.0 625 38-,7500 PT 2500.0000 SFLU -999.2500 GR )B -999.2500 DRHO 'HI -999.2500 DPHI 46.6875 OB ' H I D E P T OB HI GR DiE P T SP 2400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 30.0625 2300.0000 SFLU -999.2500 GR -999.2500 DRHO -999.250,0 DPHI 45.6250 2200.0000 SFLU -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR' -999.2500 NRAT -999,2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO GR NRAT -999.2500 NCNL -999.250'0 ILD -999.2500 GR -99.9.2500 NRAT -999-2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL ,-999.2500 ILD -999.2500 GR -999.2500 NRA'T '999.2500 NCN~ -999.2500 ILD -999.2500 GR -999.2500 RNRA -999,2500 FCNL -999,2500 ILM -999,2500 CALI -999,2500 RNR~ -999,2500 FCNL -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 FCNL -999~2500 ILM -999,2500 CALI -999,2500. RNRA -999,2500 FCNL -999.2500 ILM -999.250.0 CALI -999,2500 RNRA -999.250'0 FCNL -999.2500 ILM -999.2500 CALl -999.2500 RNRA -999.2500 FCNL -999.2500 ILM -999,2500 CALI -99'9,2500 RNRA -9,99-25~0 FCNL -999.2500 ILM -999.2500 CALI -999.25~0 RNR'~ -999.25 0 FCNL -999,2500 ILM -999,2500 CALI -'9'99,2500 RNRA -999,2500 FCNL -999.2500 tLM -999.2500 CALI -999.2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999,2500 -999,2500 -999.2500 -999.2500 .999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,250.0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.25.00 ,VP ~10.H02 VERIFICATION LISTING PAGE 10 ',HOB IPHI ~R ~EPT ;P ~itOB IPHI LR )EPT ;P [~HOB IPHI ;R )E PT HI ~PT I~ PT ~H:O s PT ~B ~IPH I ~R 3:'E P T ~HO B ~'PHI DE PT SP RHOB NP HI GR D'E PT SP -999.2500 DRHO -999.2500 DPHI 38.1875 2100.0000 SFLU -999.2500 GR -999.2500 ORHO -999.2500 DPHI 33..5938 · 2000.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 59.1250 1900'0~00 SFLU -999..2 O0 GR -999.2500 DRHO -999.2500 DPHI 28.2969 1800.0000 SFLU -999, ~H -999; 0 -999'25( OPHI 45.4063 1700.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 35.2187 1600.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 25.8125 1500.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPH'I 39.6875 1400.0000 SFLU -999.2500 GR -999.2500 DRHO -999.2500 DPHI 32.0938 1300.0000 SFLU -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999~25'0'0 NEAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2,500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2.500 ILD -999.2500 GR -999.2500 -999.2500 -999.250i -999.250 -999.25 -999.250 -999 250~ -999i250~~ -999 250!1" -999 250 -999.250'~ 999.25 999.25 -999.2500 -999 2500 -999.2500 -999 25ob -999:2500 -999.250Q -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2300 -999.2500 -999.2500 -999.2500 -999.2500 RNRA FCNL ILM CAL.: RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI R:NRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI -999.2500 -999.2500 -999.2500 -999.2500 -999 25~0 999:25 0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.250'0 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 .¥P OlO,H02 VERIFICATION LISTING PAGE 1! ~HOB -999,2500 ORHO IPHI -999,2500 DPHI ;R 29,7344 )EPT 1200.0000 SFLU OB -999.2500 DRHO ~PHI -999.2500 DPHI DR 29.0938 ~PT SF~U ~!P GR DRHO HI DPHI 1100.0000 -999.2500 -999.2500 -999.2500 33o2B13 !PT 1000.0000 SFLU -999.2500 GR OB -999.2500 DRHO HI -999.2500 OPHI 52.9375 996.5000 SFLU -999,250'0 GR -999,2500 DRHO -999,2500 DPHI 4B,6250 -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -999,2500 GR -999. 2500 NRAT -999.2500 NCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500- ILD -999.2500 GR -999.2500 NRAT -999.2500 NCNL -999.2500 ILO -99'9.250,0 GR -99'9',25'00 'NRA'T -999,2500 NC.NL FILE TRAILER ILE NAME :EDIT RVICE NAME RSION # : TE : ~XIMUM LENGTH : LE TYPE : XT FILE NAME : .001 : 1024 EOF ~~~ TAPE TRAILER ~= 'ICE NAME :EDIT :86/12/28 IGIN : 0000 ~:~E NAME :2132 TINUATION ~ :01 NEXT TAPE NAME .: COMMENTS :LIBRARY TAPE NAME : EDIT DATE :86/12/28 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.Z500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.25,00 -999.2500 -999,2500 -999,2~00 -999,2~G0 RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALI RNRA FCNL ILM CALl RNRA FCNL -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999,2500 -999.2500 -999,2500 -999,2500 -999.2500 -999.2500 -999.2500 -999.2500 -999,2500 -999.2500 -999.2500 -999,2500 -999.2500 ,VP 010.H02 VERIFICATION LISTING PAGE 12 IRIGIN : IEEL NAME :149474 iONTINUATION ~ :01 IEXT REEL NAME : OMMENTS :LIBRARY TAPE