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Home My WebLink About183-041MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, August 20, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1Y-11 KUPARUK RIV UNIT 1Y-11 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 08/20/2025 1Y-11 50-029-20926-00-00 183-041-0 W SPT 5860 1830410 1500 2462 2460 2454 2444 480 570 570 570 4YRTST P Austin McLeod 7/12/2025 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1Y-11 Inspection Date: Tubing OA Packer Depth 870 1810 1760 1745IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250713140617 BBL Pumped:0.8 BBL Returned:0.8 Wednesday, August 20, 2025 Page 1 of 1           MEMORANDUM TO: Jim Regg P.I. Supervisor K'e' 7 FROM: Matt Herrera Petroleum Inspector Well Name KUPARUK RIV UNIT IY-I1 Insp Num: mitMFH210706140315 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 1 Y-11 KUPARUK RIV UNIT IY-11 Src: Inspector Reviewed By: P.I. Supry IJ Comm API Well Number 50-029-20926-00-00 Inspector Name: Matt Herrera Permit Number: 183-041-0 Inspection Date: 7/5/2021 Notes: MIT -IA performed to 1800 PSI Per operator. IA bled back to 600 PSI per operations < BBL Return Tuesday, July 13, 2021 Page 1 of 1 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 lY-ll Type Ind W ' TVD 5860 Tubing 2589 2594 2595 - 2600 - PTD 1830410 ';Type Test SPT Test psi 1500 - IA 50 1815 - 1755 - 1745 i BBL Pumped: 2.5 - IBBL Returned: I OA 420 - j 580 580. 580 - Interval 4YRTST P/F P Notes: MIT -IA performed to 1800 PSI Per operator. IA bled back to 600 PSI per operations < BBL Return Tuesday, July 13, 2021 Page 1 of 1 WELL LOG TRANSMITTAL #905846298 To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1Y-11 Run Date: 7/19/2019 183041 31198 September 9, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 1Y-11 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20926-00 RECEIVED SEP 12 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: rX Z01 Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS R 1=G DEC 11 2019 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for plaudit ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Tubing Patch ❑� 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic ❑ Service ❑� 183-041 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20926-00 7. Property Designation (Lease Number):e. Well Name and Number: KRU 1 Y-11 ADL 25646 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pcol(s): N/A I Ku aruk River Field / Ku aruk River Oil Pool 17. Present Well Condition Summary: Total Depth measured 7,728 feet Plugs measured None feet true vertical 6,723 feet Junk measured 7187 7219 feet Effective Depth measured 7,176 feet Packer measured 6,723 feet true vertical 6,245 feet true vertical 5,860 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 15 112' MD 112' MD CE 10.75x9.625 2,187 feet 12 2,218' MD 2,218' MD PRODUCTION 7,639 feet 9 7,669' MD 6,674' MD Perforation depth: Measured depth: 6819-6914 feet 6921-6927 7033-7038 7046-7064 7078-7108 True Vertical depth: 5942-6023 feet 6028-6034 6123-6127 6134-6149 6161-6187 Tubing (size, grade, measured and true vertical depth) 3-1/2" x 2-7/8" L-80 / J-55 6,989' MD 6,085' TVD Packers and SSSV (type, measured and true vertical depth) Baker FHL Retrievable Packer 6,723' MD 5,860' TVD Paragon 2 Packer 6,735' MD 5,871' TVD Paragon 2 Packer 6,800' MD 5,926' TVD Baker FB -1 Permanent Packer 6,958' MD 6,060' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 11124 1800 12343 Subsequent to operation:0 0 794 300 2338 14. Attachments 0equired pe(20 Me 25 070, 25 071. & 25.283) 15. Well Class after work: Daily Report of Well Operations Z Exploratory ❑ Development ❑ Service ❑+ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑' GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 379-266 319-2 eve, Contact Name: Lewis Authorized Name: P.(A/ 15 ('� Authorized Title: \0 C uaC-r Contact Email: Brian.M.LewisPcop.eom Authorized Signature: Dale. 12/�0�� Contact Phone:(907) 265-6471 .0.404 Revised 4/2017 Submit Original Only r®MSL�DECL ^01q Well Name Start Date End Date 24 Hour Summary Rig Type BRUSH n' FLUSH PATCH AREA FROM 6850' TO 6700' RKB, DRIFT TBG W/ 2.72" X 36' DUMMY PATCH, SET LOWER 2.72" P2P @ 6800' RKB (ME) 1Y-11 7/19/2019 7/19/2019 (CAL 4.01/SN: CPP35199), SET 2.70" PBR SPACER ANCHOR LATCH DIGITAL SLICK LINE ASSEMBLY @ 6766' RKB (OAL 32.38' / SN: CPPBR3S021 / CPAL35016), SET UPPER 2.72" P2P @ 6735' RKB (ME) (OAL 35.1'/ SN: CPP35116 / CPAL35100), MITTBG 2500 PASS. COMPLETE, 1Y-11 4/28/2019 4/28/2019 RAN LEAK DETECTION LOG. POTENTIAL LEAK FOUND AT 6789'. ELECTRIC LINE 1Y-11 4/6/2019 4/6/2019 DRIFT W/ 1.75" BAILER & TAG TD @ 7084' RKB (EST. 24' OF FILL). JOB SLICKLINE COMPLETE & READY FOR E -LINE. KUP INJ WELLNAME 1Y-11 WELLBORE 1Y-11 Ips - Ml[fWMFes Max Angle & MQ TD Ash` n•111C. Field Name Wellbore ANN. Wellbore Status ncl I MOIttKB Act B[m NKBI KUPARUK RIVER UNR 500292092600 INJ 348 370000 ],]26.0 SSSVe NIPPLE H26 (ppm/ Date gnno....In Entl uses KBGeo (try Rig Release Data Last W9: 2/18/2000 35.01 312311983 tY-n, 7Ovo1 imaJ2ua Last Tag VadlcslsannmL(.as) Anmtatlon Depth ltlKBl End DaneWellbore foal Mod By Last Tag: PKE(Est. 24'ol Fill) ],0840 4x52019 1Y -it xambaej Irwcer; �.3 Last Rev Reason Annolatio^ Entl Duh Wellbore Ictal Mod By Rev Reason: Set Patch ]/2012019 1Y -it bworlhi Causing Hit a Casing Dsscnptlon O0(in) ID IIn Top01KS Set OeplP IXKBI Sel Depth(NGf,.. WVLen(I... Grate Top TM1rW CONDUCTOR 16 15.06 32.0 112.0 112.0 82.58 H-40 WELDED Caning Do an OD (int ID (int lop (XKBI Set DeplM1 (ttl(B) set Depm(rvDl.., wa-1 II, -Grade 1 -JT hread SURFACE 10.]5x9625 9518 8.83 315 2218.2 2,2178 40.00 J-55 BTC Lazing Descnptlon OD (int ID (In) Top (XKBI Set OepfM1(XKBI SN Depth (NDI...Grate Top Thea] PRODUCTION ] 6.28 29.9 ],669.0 6,6]38 26.00 755 BTC TUbin StNn s LONDVLTOa;3261120 NIPPLE:5f0.1 Tubing hzc True n string Ma... 10(inl Top IXKBI Set DeplM1 (tt.. Se[CepIM1 (NDI (.. WI(Ibllry Gratle Top Connection TUBING WO 31/2 2.99 26.3 6,9582 6,0600 9.30 L-60 EUEBRDMOD Completion Details Top(NDI Top Incl Nominal Top INKS) IXKBf (°I Rem Des Com ID (in) 26.3 28.3 0.13 HANGER FMCTUBING HANGER 3.500 eDRsncElmse.6x, ats 510.1 510.1 OA2 NIPPLE CAMEO DS LANDING NIPPLE .1 NO GO PROFILE 2.875 22162 6,700.8 5,842.0 31.]7 NIPPLE CAMCO W LANDING NIPPLE w/ 2.813 SELECTIVE PROFILE 2.813 GLBUFr;6W 1 6,708.8 5,848.8 31.]5 PBR BAKER 8040 PER 3.000 6,722.5 5,660.4 31.]9 PACKER BAKER FHL RETRIEVABLE PACKER, PINNED FOR 60K SHEAR 3.500 NIwIB 6PN6 8,813.5 5,93].] 32.05 BLAST JTS STEEL BLAST JOINTS(6) 2.992 6,943.5 6,047.5 3239 NIPPLE AVA PORTED NIPPLE 112.696" MN ID 2.695 Pen, Rrv. 6,956.2 6,058.3 3237 SEPL ASSY BAKER 80.40 GBH -22 LOCATOR SEAL ASSEMBLY 3.000 naturesciiption slang Ma... 10(n) Top (ft Bi) se[Cep1M1(X. acl-.) (... W[(IWXI Grade Top LonnMion TUBING Original 27/8 244 6,9582 8,9890 8,086.0 6.50 455 EUI( IPC PACKER: 6.T12.5 Condit eNon Details UPR PACKEn(ME). 57350 SPACER PIPE:6.73]0 Top(NDI Top Incl (ftKBImina) Top9581 (te (°I Ihm Des Com D,inl 6,9582 6,080.0 3238 PACKER BAKER FB -1 PERMANENT PACKER 4.000 6,9818 6,082.8 32.36 SBE BAKER 80.40 SFJ L BOREEXTENSION 4.000 INJECTION 1 x7615 6,9767 x075.6 32.33 NIPPLE CAMCODNPPLE NO GO 2.250 SPACER PIPE(W pard; amc- 6,988.2 60853 32.30 BOS BAKER SHEAR OUT SHIP 2-7/6" Tubing Tail (set on OF -25-90). 2441 ELMO TTL ® 6986' during (PROF on 51252008 Der PACKER (ME), dello Mar In Hole fell reline retrievable pings, valves, PUMPS, flab, etc.) - T^p (No) Top ha Top(XKBI (ttKS) (°) ces Com Run Dale In (in) 6,7350 5,8]1.1 31.82 UPR PACKER 3-12" P2P wl Anchor Latch(OAL 35.1'ISR 7/19/2019 1.625 (ME) CPP35116 l CPAL35100) IPERF, RanDoSe140- 6,]3].0 5,872.8 31.82 SPACER PIPE 2-1116"P-110 Spacer Pipe /1812019 1610 6]68.0 5,8991 31.90 SPACER PIPE 2-1/16"P-110 Spacer Pipe with PSR and Anchor LalcX ]/1912019 1.810 WPYR) (OAL 32.38'1 SN: CPPBR35021 I CPAL35G16) 8,800.0 5.928.2 31.98 LWB ACKER &I/TP2P(OAL4.0V/SN: CPP35999 711912019 1.625 (ME) 8,943.0 8,04].1 32.38 SLEEVE -C 275"AVA BPI SLY. 29"OAHNEWSTYL )-(C-SANDS 91102017 2.310 CLOSED) IPEnP'6'P2inuit".0- 7,1870 6,254.2 31.32 FISH 1.5" OV Lost DV In hole. 6,2511990 7,2190 6,201.6 31.07 FISH VANN GUN FISH 36].]4' Vann Gun Fish left in hole; 5118/1990 see 5118/90 Hand Over Pon. 0 .6LEEVEL:8Wa NIPPLE'.13 Parferationa&.Slots shot Dens &EPACKER.Sand 2 PACKER: 6.x.2 Top(NDI Btm(ND) 'alp TRKe) Unked]nne Dads (ahe)tai Top(XKB) rimtXKED ) Type Com 6818.0 8,914.0 5,9423 8,0226 UNI S,1Y-1, 3/23/1983 12.0 PERF 120 deg ph; 5"Geo-Vann UNITS, IY-11 -U ME."i 92 9927.0 70265 0334 UNITY, IY-11 323/1983 12.0 IPERF -F- ],033.0 ],0380 6,1232 91274 775, 1Y-11 312311983 12.0 IPERF -r-- -TC-46 0],048.0 ],064.0 6,134.2 6,149.6 h4, iV-it 323I1983 12.0 IPERF 120 deg ph; 5"Geo-Vann NIPPLe6p7x7 ],070.0 7,108.D Q1814 6,188.9 A-3, 1Y -ll 323/1983 12.0 IPERF 120degphl 5"Geo-Vann Mandrel Inserts 606;x6%2 St N Top (XKBI Top TV ItIKBj Mall Model OD (In) 3ery Was 1-cM1 PortslU TRORun Type Type (in) (psi) Run Date Com 1 Q6509 5,803.0 CAMEO MMM 11/2 GAB LIFT Cray RK 0OK 0.0 31612000 2 6,767.5 5,8988 CAMEO MMM 11/2 INJ DMV RN 0.000 00121182000 Close IPERP;7,o3CD7,W60- I I 1 tl - tea: Qeneral& taty End DAM. annohnon Iv6ap 7.)MACI.CN.o- 227/1999 NOTE. 11/4'"toolsiring naetled to pass SBR�fi95]"RKY (see WSR) 10252010 NOTE: View Schematic w/Agara SchBmaB09.0 IPERF 7.Mfi 7..lMO� FISH, 7 ho C::: FISH, 1,2190 PR^OUC7I0N,"9.31a6a0- THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Brian Lewis Sr. Petroleum Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU IY-11 Permit to Drill Number: 183-041 Sundry Number: 319-266 Dear Mr. Lewis: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.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 further 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, Or�� Daniel T. Seamount, Jr. Commissioner S r DATED this 3 / day of May, 2019. RBDMSELt' JUN 0 31019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �® 5: "res ii L'a.' ws MAY 2 3 2019 ar)rr;r; 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing Patch O 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: a ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service ❑, 183-041 3. Address: 6. API Number: e P. O. Box 100360, Anchorage, Alaska 99510 50-029-20926-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1Y-11 Will planned perforations require a spacing exception? Yes ❑ No O ` 9. Property Designation (Lease Number): r 10. Field/Pool(s): r ADL 25646 Kuparuk River Field / Kuparuk River Oil Pool it. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7,725' 6,723' 7176 6245 3149psi NONE 7167, 7219 Casing Length Size MD TVD Buret Collapse Conductor 80' 16" 112' 112' Surface 2,187' 9 5/8 2,218' 2,218' Production 7,639' 7" 7,669' 6,674' Perforation Depth MD ft) JPerforation Depth TVD (ft) ITubing Size: Tubing Grade: Tubing MD (ft): 6819-6914, 6921-6927, 7033- 5942-6023, 6028-6034, 6123- 31/2x27/8 L -80/J-55 6,989' 7038, 7046-7064, 7078-7108 16127, 6134-6149,6161-6187 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - BAKER FHL RETRIEVABLE PACKER MD= 6723 TVD= 5860 PACKER - BAKER FBA PERMANENT PACKER MD= 6958 ND= 6060 SSSV -NONE N/A 12. Attachments: Proposal Summary 0 Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑+ 14. Estimated Date for 6/17/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O 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: Brain Lewis Contact Name: Brian Lewis Authorized Title: Sr. Petroleum Engineer Contact Email: Brian.M.Lowis@cop.com Contact Phone: (907) 263-4535 Authorized Signature: ej�Date: 0523 19 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,r I l{l� Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: J/ Post Initial Injection MIT Req'd? Yes ElNo M Spacing Exception Required? i BDMSK�' JUN 032019 Yes❑ NoEe Subsequent Form Required: /a—gQ¢- APPROVED BY Approved by: THE COMMISSION Date: f J 6 1 /��f4t 11k,1 (t j11 VTZ 5/z 9 // 9 �r Formlosaly� d 4/2ov Alp proved application is valid for 12 months from the date of approval. �l4 l ',Submit Form and Attachments in Duplicate 1Y-11 Tubing Patch Installation A leak detect log ran on 04/28/2019 confirmed that the C -Sand is taking 100% of produced water injection at leaks near gas lift mandrel #2 at 6,768'. Following a successful drift, a 65' retrievable tubing patch will be set at 6,735'-6,800' RKB to isolate GLM #2 at 6,768'. 1Y-11 will then be returned to PWI as an A -Sand only injector. Procedure: Digital Slickline 1. Brush & flush 3.5" tubing from 6,715'-6,815', where tubing patch will beset. 2. RIH with dummy patch drift assembly to mimic 2.72" OD, ^'68' OAL (65' mid -element to mid -element) tubing patch. 3. RIH with a 2.72" OD packer and set it at 6,800' RKB. POOH with setting tools. 4. RIH with tubing patch spacer pipe assembly consisting of PBR, lower spacer pipe, and anchor latch assembly to sting into the lower packer. 5. RIH with upper patch assembly consisting of upper packer, upper spacer pipe, and anchor latch seal assembly. Sting into PBR, setting the upper packer mid -element at 6,735'. 6. RIH with test tool to sting into the upper packer and perform MITT to 2500 psi to verify good set integrity of the upper patch packer. Pull test plug. RD. 7. Return 1Y-11 to A -Sand only produced water injection. KUP INJ WELLNAME 1Y•11 WELLBORE 1Y-11 CUr11)ll)P$ AVaska,U1C. Well Attrihutes Max Angle&MD TD FIaM Name WeIIMre APIILWI WeIIWrc Shcus nal l'1 MOItMB) MBM InKBI KUPARUKRIVERUNIT 500292092600 INJ 368 3]00.00 Commanl X$$(pPm) pate gnmla4on Entl gala N&Grtl (fl) RIp Re. -ch. SSSV: NIPPLE last WO: &1812000 35.01 W2311903 1Y11. M/1w9B il: <]RH Last Tag Venial xhnale lecwap Armed- peplM1 Mine I E.F. WIIEe last Moi By HANGER. ib.6 7N.�l1120 NPPLE,Edl SURFACE taT9gei5; 11.1 d2la2 0.GS DFT: fi.65a.8 NIPPLE: aAne PER: Rates PACKER. 6.]526 1NIECTIDN:6fi>s (PERF; a,ataae.916.11- IPERF:6.921 p6,PD0- SLEEVE-c:aN30 WPPLE: a.9a3.s SEaLA65Y;6.9ff5] PACKERe9563 6BE:a,561,6 NIPPLE14W6] spa, aE61 IPERF:T.p33.67rds � PERF, ]pa4.d).pfi4G- IPER1:],W86]1Lfl0- F16N', 7,16]0 FIS4:].219.0 PRODUCTidN', 23.5].6BA0� Last Tag: BOB (Est 24' of 1110 ),006.0 Nfi2019 1V-11 2emhaej a \� a[` DLL") o O Last Rev Reason Anmbtbn End pM WAlhorc tei<MW By Rev Reason: Updated Tag Depth 4Ifi12018 1Y-11 ivormar, Casing Strings Cmm9Daaa,iwion Go lint IDhm Topalorn at CeR RI bet Depml-D1.,, WULena_Gratle Tep TMeal CONDUCTOR 16 1506 32.71 112.0 112.0 62.58 H-00 WELDED Cuing au Rumt 00 (In) ID lint Tq IBN01 Bel -ton r-, Sel peplM1(MII-� Worm,,... Grade Tep TM1 lesl SURFACE ;035a9�625lesl9A8 8.83 31.5 2.2102 2,217.8 40.00 J55 BTC Cnim Oescrlwian DD lest lognl Tq (RKB) 9N pewM1fllNe1 Set OewM1ITVOI__ WIILen 11... Gude Top TM1rtad PRODUCTION ) 6.20 29.9 ],689.0 6.6>3.6 26.00 J-55 BTC Tubing Strings Tubing 0ezuiwian Strlq Ma... ID lint Top IXKB Set DeplM1 frt.. sa p.wn (NDI L.. Wt01wp Gude Top C'va"vn TUBING WO 3112 2.99 26.3 6,958.2 6.060.0 930 L-80 EUEBRDMOD Completion Details TopINDI Toplml Npmi,ul Top(Real IXKBI 111 Ibm pas Cwn u,m) 26.3 26.3 0.13 HANGER FMC TUBING HANGER 3.500 510.1 510.1 0.42 NIPPLE CAMCO DS LANDING NIPPLE .1 NO GO PROFILE 2.675 6,)00.8 58720 31 73 NIPPLE CAMCO W LANDING NIPPLE vol 2.813 SE TWEPROFILE 2.01 5]08.8 5,M48.8 31.75 PBR BAKER 8040 PER 3.000 6,]22.5 5.860.4 31.79 PACKER BAKER FHL RETRIEVABIE PACKER. PINNED FOR 60K SHEAR 3.500 6.813.5 5,937. 32.05 BLAST JiS STEEL BLAST JOINTS (6) 2.992 6.93.5 6,047.5 .39 NIPPLE AVA PORTED NIPPLE w/1695' MIN ID 2.695 6.956.2 6,0583 .3 SEAL ASSY BAKER80-00 GBH- p OR SEAL ASSEMBLY 3.IR10 TUMq peeniplbn 64inp Ma../Olin) 11 -Pi flNB) 9tl pale (n,. Se[Oewnnnah L.. W1(INIry pntle Tq CannMbn IDBINGOrigmal 2J/8 2.44 6.956.2 6,989.0 6.006.0 6.50 1JS5 JEUE IPC Completion Details Top Wel Taplrcl Nominal Top IXNBI @KB) (-1 Nem pas Com hUhm 6,956.2 6,0600 J2.J6 PACK R BAKER FB -1 PERMANENTPACKER 4,000 5961.6 6062.8 J2.J6 SBE BAKER 80-00 SEAL BORE EXTENSION 4.000 6,9)6.7 6.0]5.6 32.33 NIPPLE CAMCO D NIPPLE NO GO 2.250 8,988.2 6,085.3 3230 SOS BAKER SHEAR OUT SUB, 2-)l8"Tuping Tail sH an DP 525-9D). 2.441 ELMO TTL @ 6986' during IPROF on 5/2512000 Other In Hole CW!reline retrievable plugs, valves, pumps, fish, etc.) Top ITVDI Toplml TgmKel Eta.) PI pu Com RURDM HE (in) 6,943.0 6,04).1 32,395LEEVE-C 2.75"AVA BPI SLV, 29"OAL(NEWS L)-CSANDS WlOQO17 2.310 CLOSED) 7,187.0 6, 31.32 FISH 1.5- Do Lost DV in hale W2511990 ].219.0 .6 31e) FISH VANN GUN FIS ].]' Vann Gun Fish lett in hotel SI10I1990 see 5110190 Hand Over Farm. Perforations & Slots Shut Dens Torjado Ban(ND) Pheadve Tg(MB) SWMB) MBI INXBI uhakdd me IS. ) TYPe Com 6019.0 6,914D 5.942.3 400.6 O3,C-2,C-1. N2W1983 12.0 WERE 120 deg ph; Y Geo -Vann UNRB, 1Y-11 6,921.0 6,92].0 6,026.5 6.033.6 UNITS IY-11 3I23I1983 12.0 PERE 120 deg pM1; 5'Geo-Vann 7,033.0 ),038.0 6,123.2 6.12].4 A5, 1V-11 3r231i963 12.0 IPERE 120 degph; 5"Gad- an 7,046.0 .464.0 5134.2 6,1 7-0,1Y-11 T- 3 12.O IP 1 tll:g ph: SG.Vann ).0)8.0 ).100.0 6,161.4 4186.9 A-3, tY-11 72W1983 12.0 IPERF 120 deg pM1: S°Geo-Vann Mandrel Inserts St M N Top(M(B) TupREM Ms. MWeI ODllnl Sery type Typ L'!).11: ln iae TRO Ed Pun Date Com 6.fi54.9 5,803.0 CAMCO MMM 11/2 GpS LIFT DMY RK 0.000 0.0 Y611000 2 6.76).5 5,898.6 CAMCO MMM 11R INJ DMV RK 0.000 0.0 v16/2000 Close tl Notes: General & Safety Em DR. Anwmlbn 2/0/1999 NOTE: 11/4""' Ioolslring needed to pass SBR @ 95T' RKB (see WSR) 1W2W2010 NOTE: View Schematic w/ Alaska Selveratia9.0 Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: m AOGCC ATTN: Natural Resources Technician 11 )— Alaska Oil & Gas Conservation Commision -,,b 333 W. 7th Ave, Suite 100 - A Anchorage, AK 99501 183041 30718 TRANSMITTAL DATE TRANSMITTALN REPUP MW L, M11 111 Na Date return via courier or sign/scan and email a copy to Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. r' r • r r 1A -04A 2A-09 1R-07 50-029.20621-01 50-103.20059-00 50-029-21332-00 EBNL-00001 EOSH-00041 EOSH-00042 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL Caliper Rev1 Caliper Caliper FINAL FIELD FINAL FIELD 17 -Apr -19 18 -Apr -19 1 1 2A-08 1y-11 50-103-20049-00 50-029.20926-00 DWUJ-00092 EBNL-00016 KUPARUK RIVER KUPARUK RIVER WL WL [PROF LDL FINAL FIELD FINAL FIELD 28 -Apr -19 28 -Apr -19 1 1 213-07 1A-01 2X-10 3H-21 25-315 50-029-21080-00 50.029-20590-00 50.029.21187-00 50-103-20094.00 50-103-20776-00 DWUJ-00093 EBNL-00018 DWUJ-00094 EBSI-00004 EBNL-00020 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL IPROF PPROF PPROF Caliper PPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 29 -Apr -19 30 -Apr -19 30 -Apr -19 3 -May -19 5 -May -19 1 1 1 1 1 10 Na Date return via courier or sign/scan and email a copy to Schlumberger and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: T� DATE: Tuesday,July 11,2017 Jim Regg P.I.Supervisor � 7 t 71/ SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1Y-11 FROM: Brian Bixby KUPARUK RIV UNIT 1Y-11 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1Y-11 API Well Number 50-029-20926-00-00 Inspector Name: Brian Bixby Permit Number: 183-041-0 Inspection Date: 7/6/2017 Insp Num: mitBDB170708102104 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1Y-11 Type Inj W 'TVD 5860 ' Tubing 2352 2352 2350 " 2340 PTD 1830410 " Type Test SPT Test psi 1500 IA 910 1800 - 1770 ' 1770 BBL Pumped: 0.7 ' BBL Returned: 0.7 • OA 380 460 460 460 Interval 4YRTST PAF P Notes: SCANNED Af I P 1 5 2017" Tuesday,July 11,2017 Page 1 of 1 ge Project. Well History File i~ver Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. [ ~ 0 ¢ L Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. n Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: Logs of various kinds NOTES: [] Other BY; BEVERLY E~REN VINCENT SHERYL MARIA LOWE!~L DATE; /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ Scanning Preparation ~ x 30 = ~ + .~ = TOTAL PAGES BY: BEVERLY BREN VINCENT SHERY~LOWELL DATE: 1~5/0~ ~ Production Scanning Stage I BY: Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: _~YES (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INOIVIDUAL PAGE BASIS DUE TO QUALITY. GRAYSCALE OR COLOR IMAGES ) NO IF NO IN STAGE 1, PAGE(S)DISCREPANCIES WERE FOUND: YES NO BEVERLY BREN VINCEN~ MARIA LOWELL DATE/. /,,"~;/'/ IS/ ReScanned (individ~at pa~e [spe, cia~ attention] F{ESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA General Notes or Comments about this file: LOWELL DATE: Is~ Quality Checked Ill IIIIIlllllllllll • • )0r ConocoPhillips Alaska P.O. BOX 100360 • - ANCHORAGE, ALASKA 99510 -0360 JAN 2 4 201 i December 30 2010 i 4 ?Di Commissioner Dan Seamount Alaska Oil & Gas Commission Arc c`;P ;? G$ a ,> ftS " scion 333 West 7th Avenue, Suite 100 ttcrir° age Anchorage, AK 99501 ig3-0(4-1 Commissioner Dan Seamount: V V Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The cement was pumped September 8 2010 and the corrosion inhibitor /sealant was pumped December 21 22 23 24 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 12/30/2010 1C, 1 E, 1 F, 1 G & 1Y PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal 1C-07A 50029205690100 2090290 3'2" n/a 3'2" Na 4.3 12/23/2010 1E-09 50029207200000 1820280 13' 1.00 13" 09/08/2010 3.8 12/22/2010 1E-15A 50029207690100 2100130 3'9" Na 3'9" Na 11.6 12/22/2010 1 E -16 50029207770000 1821100 4' n/a 4' Na 13.7 12/22/2010 1E -17 50029207930000 1821160 3'11" n/a 3'11" Na 8.5 12/24/2010 1 1F-13 50029210200000 1831440 6" n/a 6" n/a 3 12/23/2010 1F-17 50029226570000 1960470 SF n/a 18" n/a 7.65 12/23/2010 1F-20 50029226610000 1960530 6" n/a 20" Na 6.1 12/23/2010 1G-13 50029210160000 1831400 13'10" 1.50 30" 09/08/2010 2.5 12/24/2010 1Y-01 50029209330000 1830500 SF Na 6" n/a 1.9 12/21/2010 - 1Y-03 50029209430000 1830610 SF n/a 6" n/a 1.7 12/21/2010 1Y-04 50029209480000 1830660 SF n/a 6" n/a 1.7 12/21/2010 1Y-11 50029209260000 1830410 9" Na 9" Na 2 6 12/21/2010 r 1Y-12 50029209130000 183026 4' Na 4' Na 8 12/21/2010 1Y-13 50029209030000 1830150 15" Na 15" n/a 1.7 12/21/2010 1Y-14 50029209100000 1830230 24" Na 24" Na 1.7 12/21/2010 1Y-16 50029209270000 1830420 12" n/a 12" n/a 1.7 12/21/2010 - u MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~~ ~ 7~~D~ FROM: LOU Griri131d1 Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 30, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 Y-I 1 KUPARtJK RIV LJNIT ]Y-11 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: KUPARUK RIV iTNIT 1Y-11 API Well Number: 50-029-20926-00-00 Inspector Name: Lou Grimaldi Insp Num: micLG090703140931 Permit Number: 183-041-0 ' Inspection Date: ~~3/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~Y-~~ Type Inj. ~ TVD ss6o '~ Ip zzo zsoo ~ za3o zazo _ P.T.D 183oaio TypeTest SPT Test psi zsoo '~I OA o 0 0 0 Interval 4YRTST P~F' P '~ Tubing 3220 3224 3224 3224 ; NOtes: 2•5 bbl's pumped, good 4 yeaz test. n~~ r_~s~-- Pre~,~. i sc oPs; _ ~ ;, ~~ :~~ ~^r~~~ t ~ "~ ~ ~ . `~ ~,... , _ _ ~~..; ,~ ~ , ~_, . Thursday, July 30, 2009 Page I of 1 ~~h Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth • ~.'~ Well Job # .XJ~`-' -~taN~ ~uN a i zoos Log Description NO.4732 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnke~n 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 05/30/08 iF-04 11964615 INJECTION PROFILE I ~ / 05/26/08 1 1 3F-10 11964609 PRODUCTION PROFILE - ~ / ~ 05/23/08 1 1 iJ-101 11970685 GLS < < 05/23/08 1 1 1J-166 11970681 GLS / 05/20/08 1 1 2N-306 11964608 INJECTION PROFILE - / ~/ V (-~- 05/22/08 1 1 3K-13 11970688 INJECTION PROFILE ~ 05/26/08 1 1 iB-08A 11970686 INJECTION PROFILE ( -~ / 05/24/08 1 1 1Y-11 11964613 INJECTION PROFILE (jj - /~?+~ 05/25/08 1 1 3K-19 11964616 INJECTION PROFILE U"' - d 05/27/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 06/08/07 Schlumbel'gel' NO. 4286 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: SCANNED JUN 1 4 2007 Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 ]. 20m Field: Kuparuk ~v . UTe.. /153 - CI-II . .........A T~f: . . Well Job# Log Description Date BL Color CD 2L-321 11629010 MULTI-FINGER CASING INSPECTION 05/12/07 1 2C-16 11629008 PPROF/LDL 05/10/07 1 2G-11 11638863 PRODUCTION PROFILE 05/05/07 1 1C-125 N/A MEM INJECTION PROFILE 05/05/07 1 2D-13 11638861 PRODUCTION PROFILE 05/03/07 1 2D-08 11638862 PRODUCTION PROFILE 05/04/07 1 2G-09 11638864 PRODUCTION PROFILE 05/06/07 1 2N-349A 11629004 RST/ WFL 05/04/07 1 3H-19 11638867 PRODUCTION PROFILE 05/09/07 1 1Q-10 11628771 MEM PRODUCTION PROFILE 05/03/07 1 1 E-11 11629012 INJECTION PROFILE 05/14/07 1 2L-321 11665439 USIT OS/25/07 1 2V-OSA 11629013 PMIT 05/15/07 1 1J-160 11632704 PRODUCTION PROFILE 03/19/07 1 1 H-07 11665436 SBHP SURVEY OS/20/07 1 2F-11 11665434 PRODUCTION PROFILE 05/19/07 1 2X-07 11665433 INJECTION PROFILE 05/18/07 1 1 B-01 11665432 PRODUCTION PROFILE 05/17/07 1 2X-01 11637338 INJECTION PROFILE 05/15/07 1 2Z-29 11665438 PRODUCTION PROFILE OS/22/07 1 1 H-22 11637339 INJECTION PROFILE 05/16/07 1 1Y -11 11632708 INJECTION PROFILE OS/23/07 1 1 G-03 11637336 INJECTION PROFILE 05/14/07 1 1A-23 11665443 MEM PRODUCTION PROFILE OS/29/07 1 1 F-08 11665435 SBHP SURVEY OS/20/07 1 1 J-170 11632709 INJECTION PROFILE OS/24/07 1 1D-109 N/A INJECTION PROFILE 05/13/07 1 2M-24 11665440 SBHP SURVEY OS/28/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission . ,,..--¡ 07f'IClt-. TO: JlTI1 Regg \<fl.!;,'l P.I. Supen'isor '\ (( Dr\. TE: Wednesday, June 23. 200~ SlIBJECT: t\1echamcallmegTlt) Tests CONOCOPHILLlPS ALASKA TNC FROM: Chuck Scheve Petroleum Inspector I Y-II KUPARUK RIV UNIT I Y-ll Src: Inspector Re\'iewed Bl:,...-: P.I. Suprv .J~---- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IV-II Insp Num: mitCS0406I92I0636 Rellnsp Num: API Well Number: 50-029-20926-00-00 Permit Number: 183-0~I-O Inspector Name: Chuck Scheve I nspection Date: 6/19/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 l\lin. Well IV-II Type Inj. P TVD 6723 IA 550 2120 2100 P.T. 1830-110 TypeTest SPI Test psi 1-165 OA -100 500 500 Inter,,;!1 -1YRTSI PIF P Tubing 2-1501 2-150 2-150 Notes: Pretes[ pressures observed for 30+ minUles and found stable. \Vell demonstrated good mechanical integrity. 2100 500 2-150 Wednesday. June 23. 2004 Péige I of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11 N, RgE, UM At top of productive interval 1397' FNL, 1285' FEL, Sec. 2, T11N, RgE, UM At effective depth At total depth 1495' FNL, 1735' FEL, Sec.2, T11N, R9E, UM 5. Type of Well: Development __ Explorato~ Stratigraphic__ Service__X (asp's 530800, 5974755) (asp's 528387, 5973916) (asp's 527938, 5973816) 6. Datum elevation (DF or KB feet) RKB 96 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1Y-11i 9. Permit number / approval number 183-041 10. APl number 50-029-20926 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 110' SURFACE 73' SURFACE 2180' PRODUCTION 7634' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7725 feet 6723 feet Plugs (measured) Tagged Fill (5/28/00) @ 7176' MD. 7176 feet Junk (measured) 6245 feet Size Cemented Measured Depth 16" 300 Sx AS II 110' 10-3/4" 1000 SxAS III, 250 AS I 73' 9-5/8 ....... 2218' 7" 980 Sx Gl G, 250 AS I 7669' 6819- 6914'; 6921 -6927'; 7033 -7038'; 7046 -7064'; 7078 -7108' 5942 - 6023'; 6029 - 6034'; 6123 - 6128'; 6134 - 6150'; 6162 - 6187' True vertical Depth 110' 73' 2218' 6674' RECEIVEr_ FEB 1 6 001 Alaska Oil & Gas Cons. Comrnissi~ Anchorage 3-1/2", 9.3~, L-80, Tubing @ 6958' MD; 2-7/8", 6.5#, J-55, Tubing @ 6989' MD. Baker FHL Perm Packer @ 6722' MD; Baker FB-1 Perm Packer @ 6958' MD. Camco TRDP-1A-ENC @ 510' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiFBbl Shut In Representative Daily Average Production or Injection Data Gas-Mc/ Water-Bbl - 9OO Casing Pressure Tubing Pressure - 245O 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 16. Status of well classification as: Oil __ Gas __ Suspended Service ~(WAG).~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ /~ Title: Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1Y-11i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT ' 5/28/00: RIH & tagged fill at 7176' MD. 6/2/00: MIRU & PT equipment to 7800 psi. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 6819 - 6914' MD 6921 - 6927' MD 7033 - 7038' MD 7046 - 7064' MD 7078 - 7108' MD Pumped Scour Stage #1: a) 200 bbls Pad, followed by b) 50 bbls Scour stage w/1 ppa proppant, followed by c) 200 bbls Flush @ 30 bpm, followed by d) Shutdown. ISIP @ 2690. Pumped Scour Stage #2: e) 47 bbls Gelled Diesel w/2700 lbs Rock Salt Diverter, followed by f) 50 bbls Scour stage w/1 ppa proppant, followed by g) 200 bbls Flush @ 30 bpm, followed by h) Shutdown. ISIP @ 2997. Pumped Scour Stage #3: i) 32 bbls Gelled Diesel w/1300 lbs Rock Salt Diverter, followed by j) 400 bbls Pad, followed by k) 150 bbls Scour stage w/1 ppa proppant, followed by I) 250 bbls Flush @ 30 bpm, followed by m) 310 bbls Slick Water, followed by n) Shutdown. ISIP @ 2877. Returned the well to water injection & obtained a valid injection rate. RECEIVED FEB 1 6 200! Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Pull tubing _X 2. Name of Operator: 15. ARCO Alaska, Inc. 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface: 568' FNU 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval: 1397' FSU 1285' FEU Sec. 2, T12N, R9E, UM At effective depth: At total depth: 1495' FSL, 1735' FEU Sec. 2, T12N, R9E, UM i 12. Present well condition summary Total Depth: measured 7725' true vertical 6723' Effective Deptt measured 7669' true vertical 6673' Casing Length Size Conductor 110' 16" Surface 37' 10,75" Surface 2180' 9.625" Production 7634' 7" Liner Stimulate__ Alter casing _ Type of Well: Development Exploratory Stratagrapic ~ Service .X Plugs (measured) Junk (measured) Plugging _ Perforate _ Repair well _X Other _ 6. Datum of elavation (DF or KB feet): 26' Rig RKB 7. Unit or Property: Kuparuk River Field 8. Well number: 1Y-11 9. Permit number/approval number: 83-41/300-020 10. APl number: 50-029-20926 11. Field/Pool: Kuparuk River Field/Kuparuk Oil Pool Cemented Measured depth True vertical depth 300 sx AS II 110' 110' same as 9.625" 73' 73' 1000 sx AS III & 25O sx AS I2218' 2218' 980 sx Class G & 7669' 6673' 250 sx ASI Perforation Depth measured true vertical 6819'-6914', 6921 '-6927', 7033'-7038', 7046'-7064', 7078'-71C,~~ 5942'-6022', 6027'-6033', 6123'-6127', 6134'-6149', 6161 '-61~"/" Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 6958', 2-7/8", 6.5#, J-55 @ 6989 Packers and SSSV (type and measured depth) Baker 'FHL' Perm Pkr @ 6723', Baker 'FB-I' Perm. Pkr @ 6958', No SSE~V 13. Stimulation or cement squeeze summary Intervals treated (measured~ N/A Intervals treated (measured) 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure N/A N/A Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ._~ 16. Status of well classification as: Oil _ Gas _ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /~~.. ~. /~-'~k.~. Title', Drilling Engineering Supervisor Chip Alvor~l Suspended _ Service _X Questions? Call Mark Chambers 265-1319 Date Form 10-404 Rev 06/15/88 Prepared by Sharon AIIsup-Drake SUBMIT IN DUPLICAT,~ Date: 03/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 REMEDIAL AND COMPLETION OPERATIONS WELL:iY-11WO RIG:NORDIC 3 STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:02/14/00 START COMP:02/14/00 FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-20926-00 02/14/00 (C1) TD: 7725' PB: 7588' KILL WELL W/ 11.6 PPG MUD MW:ll.6 LSND SUPV:DONALD L. WESTER Turn key rig move from 1G pad to 1Y. Accept rig ~ 1000 hrs. 2/14/2000. PJSM. Pump seawater down tubing. Pump 11.7 ppg kill weight mud. 02/15/00 (C2) TD: 7725' PB: 7588' MW:ll.6 LSND SUPV:M.C. HEIM Displace well to 11.6# mud. Freeze protect flowline w/diesel. Continue displacing well to 11.6# mud. Set BPV. N/D tree. N/U choke and BOP stack and function test. test BOPs to 250/3500#. Annular failed test, leaked thru element. PJSM. Change annular preventer element. Pull 3.5" tubing. 02/16/00 (C3) TD: 7725' PB: 7588' CIRC. BOTTOMS UP.= RIG 0 MW:ll.6 LSND SUPV:M.C. HEIM POH slow laying down 3.5" tubing, hanging up approx, every 30', lay down control line. Lay down packer. Set test plug and test blind rams to 250/3500#, OK. RIH with 3.5" DP. Drop ball, circ ball down, work pipe & fish for packer elements. Pump dry job. Check for flow. 02/17/00 (C4) TD: 7725' PB: 7588' TESTING BOP BREAKS AFTER MW:ll.6 LSND SUPV:M.C. HEIM POH w/reverse basket. Make up storm packer & set ~ 6770 mule shoe, packer @ 49'. Test packer to 3000#OK. Quarterly safety assessment review. Remove & dress LDS,s & gland nuts=7" casing in compression, 2 LDS,s broke=7" casing come up hole 13". Remove 2 broken LDS. Attempt to install packoff. 02/18/00 (C5) TD: 7725' PB: 7588' SETTING BAKER 'FHL' RETRI MW:ll.6 LSND SUPV:M.C. HEIM Complete modifying packoff. Install packoff. NU BOP, test packoff to 2600#,0K. Set test plug, test BOPE 250/3500#, pull test plug. Pull storm packer. CBU. RIH w/lead impression block. POH. PJSM. Run 3.5" single injector completion. Date: 03/02/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/19/00 (C6) TD: 7725' PB: 7588' CLEAN CELLAR. MW: 8.6 SW SUPV:M.C. HEIM Running 3.5" completion. Set packer. Phase 3 weather conditions. PJSM. N/D BOPE, N/U tree and test packoff to 5000#. Pull BPV, set test plug, start tree test, test plug leaked, pull test plug, install new seals, set plug, test tree to 250/5000#. Freeze protect down annulus. 02/20/00 (C7) moved rig MW: 0.0 TD: 7725' SUPV:M.C. HEIM PB: 7588' Finish cleaning out pits. Prepare for move. Rig released 1200 hrs. 2/20/2000 DAILY:$ 41,132 CUM:$ 415,317 ETD:S-2,147,483, EFC:$-2,146,436, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface ,/" ,/ J 568' FNL, 1132' FWL, Sec. 1, T11 N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T12N, R9E, UM At effective depth At total depth 1495' FSL, 1735' FEL, Sec. 2, T12N, R9E, UM 5. Type of Well: Development__ Exploratory __ Stratig raph ic __ Service __X 6. Datum elevation (DF or KB feet) RKB 121' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 9. Permit number/approval number 83-41 10. APl number ~ 50-029-20926 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measu red true vertical Casing Length Conductor 1 10' Surface 37' Surface 2180' Production 7634' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 7725 feet v~ Plugs (measured) 6723 feet v/' ORIGINAL 7588 feet Junk (measured) DV & SOS @ 7153' 6602 feet Size Cemented Measured Depth True vertical Depth 16" 300 sx AS ~ 110' 110' 10.75" same as 9.625" 73' 73' 9.625" 4000 sxAS IH & 25o sx AS I 221 8' 2218' 7" 98O sx C~ass G & 7669' 6673' 25o sx ASI 6819'-6914', 6921'-6927', 7033'-7038', 7046'-7064', 7078'-7108' 5942'-6022', 6027'-6033', 6123'-6127', 6134'-6149', 6161 -~.. '- ( '¢ ,. 3.5", 9.3¢, J-55 ~ 6966', 2.875", 6.5¢, J-55 Otis Baker HB Pkr G 6739' MD, Baker FB-1 ~ 6944', SSSV: Camco TRDP-1AENC ~ 1826' 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation February 25, 2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Gas__ Service Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~'. (~,~ Title: Drilling Engineering Supervisor Chip Alvord Questions? Call Mark Chambers 265-1519 Date Prepared by Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test ~/~ Location clearance __ Mechanical Integrity Test~, Subsequent form required 10- J--l[C) ~ J Approval_~¢.~. E>~ ~ . Approved by order of the Commission ORIGINAL SIGNED BY Robert N. Chdstenson Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 1Y-11 GENERAL WORKOVER PROCEDURE PRE-RIG WORK: RU wireline unit. : A. RIH and set isolation plug in 2-7/8" 'D' Nipple @ 6,963'. B. RIH and set isolation sleeve in AVA Ported Nipple. C. RIH and pull DV from GLM # 1 @ 6,681' leaving an open pocket. Set BPV in tubing and install VR plug in annulus valve. Remove flow riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits and displace well with seawater. Shut in and determine kill wt fluid requirements. 3. Load pits and displace well with kill weight fluid. Ensure well is dead. 4. ND tree. NU and test BOPE. 5. POOH laying down 3-1/2" tubing and jewelry. 6. RIH with spear. Latch PBR and release retrievable packer. POOH standing back DP. 7. RIH with bit and scraper. Clean out to top of permanent packer. POOH laying down DP. . 10. 11. 12. 13. 14. PU above perforations and set storm packer. ND. Change wellhead equipment. NU and test. Release storm packer and continue POOH laying down DP. RIH with selective single completion picking up 3-1/2" tubing. RECEIVED JAN 2.4 000 OD & Cons. Comm lon AnchoraDe Stab seals into bottOm packer. Set top packer. Spaceout and land tubing. Pressure test tubing and annulus. ND BOPE. NU and test tree. Flush well with seawater. Freeze protect well with diesel. Lower Limit: Expected Case: Upper Limit: 7 days No problems pulling completion or squeezing well. 8 days 12 days Difficulties encountered pulling existing completion. MAC 1/19/OO 1Y-11 Workover Schematic (Injector) w. 3-1/2" 5M FMC Gen II Retrofit Tubing Hanger with 3-1/2", L-80, 9.3# EUE 8rd Mod pin down. V. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the tubing hanger. U. 3-1/2" Camco 'DS' Landing Nipple with 2.875" ID No-Go profile set @ +/- 500' MD. 10-3/4" 45.50# K-55 BTC @ 73' 9-5/8" 40.00~ J-55 BTC 73' to 2,218' C3, C2, C1, B Sand Perfs 6,819' - 6,914' MD B-Sand Perfs 6,921' - 6,927' MD A5-Sand Perfs 7,033' - 7,038' MD A4-Sand Perfs 7,046' - 7,064' MD A3-Sand Perfs 7,078' - 7,108' MD 7" 26~ J-55 BTC @ 7,669' T. 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing to the 'DS' Nipple. S. 3-1/2" x 1-1/2" Camco 'MMM' GLM w/DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. R. 1 Joint 3-1/2", L-80, 9.34f EUE 8rd MOd Tubing. Q. 3-1/2" Camco ~/V' Landing Nipple with 2.813" Selective Profile P. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. O. Baker'80-40' PBR. N. Baker 7" x 3-1/2" 'FHL' Retrievable Packer. Minimum ID through the packer ???. M. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. L. 3-1/2" x 1-1/2" Camco 'MMM' GLM w/ 6' L-80 handling pups installed on top and bottom of mandrel. K. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. J. 3-1/2 x 20' Steel Blast Joints 3-1/2" EUE 8rd. 6 total joints (+/- 120') to cover all C-Sand Perfs w/at least 5' ovedap above & below perfs. I. 10' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing w/XO coupling to 3-1/2" BTC Mod on top. H. AVA Ported Nipple. G. 10' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. F. Baker 'GBH-22' Locator Seal Assembly (5' seals w/Iocator). E. Baker 'FB-I' Hydraulic Set Permanent Packer w/5' Seal Bore Extension @ 6,944' (4" ID through SBE). D. 10' Pup Joint 2-7/8", J-55, 6.5#, EUE 8rd Mod IPC Tubing. C. 2-7/8" Camco 'D' Nipple w/2.25" No-Go Profile. B. 10' Pup Joint 2-7/8", J-55, 6.5#, EUE 8rd Mod IPC Tubing. A. Baker 2-7/8" Shear Out Sub w/ WL Re-entry Guide. Tubing tail @ 6,975' MD. PBTD @ 7,101' - Fill tagged on 2/27/99 PBTD @ 7,588' - Actual 7" casing PBTD to FC. TD @ 7,725' RECEIVED jAN 24 2000 Anchorage 1/19/00 MAC: MAY 20 ~ O~:2~AM KU~ARUK PETROLEUM EMGIME£~IMG MAY 20 ' 94 09: 30AM KUPARUK PETROLEUM EMGIMEERIMG ~. ~-x r ~',~-" STATE ~ ~ '~- ,- APPLICATION FOR SUNDRY APPROVALS 1- T~ ~ R~St: ~d~ __ S~_ ~refi~ ShOwn __ ~e-enter ~.~ well __ A~r ~slng ~ Re,Ir wall _ ~i~ ~ Time e~enslon _ samurais _ ~: N~e of ~rat~ I 6~lop~nt ~ .J Explm~o~ ~ RKB g6 fee~ ~BCO Alaska. Inc. . j Sffaflgraphio ~ 7. Un~ or Pro~rty na~ ~. k~s 99510 ' ~ K~k ~er Unit 10O360 4. Location of well at surfaoe 568' FNL, 1132' FWL, Sec. 1, T11N, RgE, UM At top of produce'va InterveJ 1397' FSI., 1285' FEI.., Sec. 2, T12N, RgE, UM At effe<~tive depth 1482' FSL, 1670 FEL, Seo. 2, T12N, RgE, UM At total depth 1495' 1735' FEL 2. present well condition summa~J - Tr;f~ Depth: measured 7 7 2 5 true vertic~al 6 7 2 3 8. Well number 1Y.-_11 ..... g. permit number 83-41 -- -- t0. APl numbe~ SO -029-_20926 11. Field/Pool Ku aruk River Field/Oil Pool feet Plugs (measured) N0rle feet Effeot~ve depth: measured 7 5 8 8 feet Junk (measured) true vertical 6 6 0 2 .feet Size Cemented DV & SOS in rat I~ole below 7153' (last tag) Measured depth True vertical depth 1 6" 300 SX AS Ii 115' 1 1 5' 9 5/8" 1000 AS III & 221 8' ;2218' 250 SX AS I 7" 980 SX Class G & 7 6 9 9' 6 6 7 3' 250 SX AS I 7046'-7064', 6134'-6149', casing Length Structural Conductor I 1 5' Surb~e 21 8 0' Intermediate Pr~uc~on 7 6 3 4' Liner Perfmation del)th: measured 6819'-6914', true vortical 5942'-6022', 6921 '-6927'0 6027'-6033', 7O33'-7038', 6123'-6127', Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 6962' & 2.875", 6.5#, J-55 @ 6962'-6988' Packers and SSSV (type and measured depth) PKR'S: Baker "HB" 6739' & Baker "FB-I" ~$SV: CAMCO TRDP-1A-EN~ 18. Attachments Description summary of proposa] .2L Detailed operation program _ 3.$' x 7" Communication. Estimated date for ~ommencing operation 15. 7078'-7108' 6161'-6187' 1826' BOP sketch _ Status of well classification as: oi~ x <~s__.. Suspended _._ 18. I[ proposal was verbally apPr°ved Name of approver Date a 17. i hmel lng is true and [~orre~ to the best of my ned Title Sr. En ineer FOR CC)IV~ISSK:~ USE ONLY Conditions of approval: Notify Commission so representative may witness KUPARUK P TROLEUM ENGINEERING Serv~ Date ]Apl)royal No. Plugintegrity _ BOP, Test _. L.~:~fio~ deadeye __ .,. , J ' Mechanical lnt~e ~v-.~ the~%~"~~~~~-~~ C omm~ Form 10-403 Rev -r[~t~.~, ~RIPLICATE ' ' 1994 I AY 20 J:994 Atask~ 0il & 6as Cons. Commission 41aska 0Jj & ba~ ~ons. C0mmis$i_0.n ,--~- ..... Arlchnrnrm Attaohment 1 Request for Variance Kuperuk Well 1Y.11 As per Area Injection Order No, 2, Rule 7, ARCO Alaska is hereby notifying the Commission of pressure communication between the tubing and casing in Water Injectio, n Well 1Y-11. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well, As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class I! injection activities by 40 CFR 147,102(b) (3) and 20 AAC 25,440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW), Well 1Y-11 was converted from an oil producer to water injector in June 1989, and to a WAG injector in October 1990. The well is currently injecting approximately 6000 BWPD at an average surface injection pressure of 2200 psi, Diagnostic work indicates that the source of the communication is the maria tubing patch located at 6741' WLM- RKB (Attachment 2), The patch was set in November of 1992 across the Baker 'HB' packer to repair a leak identified with a downhole camera. After setting the patch the tubing and 7" annulus passed a pressure test, as indicated in the field Well Service Report shown in Attachment 3, The well was subsequently fracture stimulated, and shortly thereafter developed slow tubing to 7" annulus communication. · Diagnos!ic'work indicates that there are no e~e_r~n,~.i..casing leaks, and injection fluids are confined to the Kuparuk River Sands, An .~ MIT is requested, consisting of a combined tubing and casing pressure test, in order to satisfy Area Injection Order No. 2, 'Rule 6. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. RECEIVED MAY.20 Alaska Oil & Gas (Jons. Anchorage RECEIVED FEB "9 199¢ 0il & ~ ~ Commission A~l~mge Etpud Date: 0~-07 Oompletion Dam'. 0 3- Original Rig RKB: All ~epth mrs RKB MD t= top of ~ulp~nt. I'IRY ~0 "':34 09; E:61:II'1 KUPRRUN PETROLEUH EHGTHEERTHG..., ,,~ i~~ r'. '.+/':, , A~ AI.A~K,~ IPlr~. - i,~Ui-"Al'lU~ FI Well TyPe; .lAG INJECTOR Tree TYl~'. FMC; GP..N il 3.1t8" ,50001t Tree ¢~ Tyl~: OTB, UNION Tree ~ 8~: $. $' Tree Cap O.Hn$ AeN:30~2.75~G L~t Wor~over Date: 0 $ - 2 7- g o 1 55$V: O~MCO TRDP.IA-ENC ~ PBR; BAKER ID 0,0~ 3 PKR: BAKER HB ID ~LLAR 8TO~ S PKR: ~K~R FB.1 ? N~O:~o 'D' NiXie E.~;~ w/AVA 1.8~" ID Nipple R~. ~ ~' 8 5HEAR O~: ~ER ~ ~7' Minimum IDI '1,$?~"t0 AVA Reduced Nipple $1w, $ G~' Oas Lift Information I~uth ~ Valve TVOI SZ, ~ port sz. &U~Jit G660' 1 !:~' 1.6" ~ 6775' 2 ~ 1 :S" RK G944' 3 AVA TPL TI=C 1.875" (1 .-~70 ID) CC)MM 1.13.93 ~ommeflts: DV tun 06.~S-~O lost in hole..ghe=r out sub in rate h01e 1~3-62. 'AV~ ~a~"x1,81" nipple reducer ~ ~61~'1 AVA pe~ nipple I,D. thru sl~ ~ SG44' 1.37S"(Pull wl2.O"G.~.) Top of ~toh 67~,8' Oo~om of patch 6746,4' ~p~ lo be a t~, X 7" oemmunloetlon Bt the MERLA PATCH ~ST TD:71s3' t.13.g3 ~TD: 7~8' PBTDS8: ~06' LAST RE~$1ON:4-11-~3 MRY 20 '~d 09:31RM KURRRUK PETROLEUM EHGIHEERIHG ?.~/r ARCO Alaska, inr'-'OP_. '-'~-~ WELL SERVICE REPORT .__ . $1 DY.~r_TOa;,~G P~re~ _ _ -- --il _- , · [FIELD-DISTRIOT- STAT~ ....... /_/: 3.~-- v.~ ...... ]OI=EF~TION AT REDORT TIME 1 (.;~. mp-~6 ;'6 ...... - _ .. Et;-, ~s'r: ~'/"/,c,c,.~,.. _ - ,,f, · CHECK THIS BLOCK IF SUMMARY C.,,ONTINUED ON IBACK W~hm' i l'.mp.' I cbt. F'.,~v t VWb..i I W,.dw 18~i..d' ',~ , ,".. --'-'----- "'"'" 1.-3 "__I -~,~ "1... "'"".~ ,.""'! ."f-~ ~*"'/ ----.-- MR¥ 20 '94 09:27RM KUPRRUK PETROLEUM EHGIHEERIHG ARCO Alaska, Inc.. ,~" DATE DAY TIME DESGR!PTION OF WORK CONTRACTOR/KEY PERSON ~..r / ::r,~,,, .,v,,,.,.,..,, OPERATION AT REPORT TIME . ~C,,OMPI.ETE O INCOMPLETE FI ELD EST: $ +tlr,tz P'. KUPAFIUK RIVER UNIT 1/I/ECL SERVICE FIEPORT 14-15' I,.c4o , , AFC/C~Co~; ¢012~ ACCUMULATEO COST PAGE i CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK we-afiier Temp. I *F/ miles J knots i ..,,,,, I --,,,, o,. Ic''''',''''''' r,,,.,,.,,,;,~" w,.,v'.,. I;-'."'~, ¢._'-~.~~ AR31B.?0,31 · ~',% ' ~' ---- HR¥ 20 '9~ 09:32RH KUPRRUK PETROLEUM EHGIHEERIHG /(RCO Alaska, Inc. ~'- WELL /Y-it DATE DAY ! TIME _/3.._o0_ ·/<~/~ _ 4~_s'o ,. · DESCRIPTION OF WORK- CONTRACTOR 1 K~ PERSON /'/£X / ;7',~,., ,//,,,,.,.,.,-, OPERATION AT REPORT RUE ~(COMPLETE [] JNCOMPLE3~ ~'. (/ ( KUPARUK RIVER UNIT WELL SERVICE REPORT AFC/C~Cc~: 401 ~.4. ACCUMULATED COST J--) CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp, Chill Fa~t°r- Visibility Report -- / () *F miles ARBB-7031 jWind Vel. knots ~, W,J' ' · ,i PAGE 1 OF ARCO Alaska, Inc. Post Office Box ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 12i5 May 2, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Reports of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells.are listed below. WELL ACTION ~.~ -- zo 1 H- 18Other (cony) ";~- !-~'~ 1L-06 Other (sssv) ~.,5--~t 1Y-11 Other (sssv) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments (original + one) Well Files (atch only) FTR050396 (w/o atch) RECEIVED MAY -5 1994 Al~sk~ Otl & Gas Cons. Commission ,Anchorage AR3B_6003_93 242-2603 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T12N, R9E, At effective depth 1482' FSL, 1670' FEL, Sec. 2, T12N, R9E, At total depth 1495' FSL, 1735' FEL, Sec. 2, T12N, R9E, 12. Present well condition summary Total Depth: measured 7 7 2 5 true vertical 6 7 2 3 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X UM UM feet feet 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 feet 9. Permit number/approval number 83-41/94-036 10. APl number 50-029-20926 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 5 8 8 true vertical 6 6 0 2 feet feet Junk (measured) DV & SOS @ 7153' Casing Length Size Structural Conductor 1 1 0' 1 6" Surface 21 8 0' 9 - 5 / 8" Intermediate Production 7634' 7" Liner Perforation depth: measured 6819'-6914' true vertical 5942'-6022' Tubing (size, grade, and measured depth) Cemented 300 SX AS II 1000 AS III & 250 SX AS I 980 SX Class G & 250 SX AS I Measured depth True vertical depth 110' 110' 2218' 2218' 7669' 6673' , 6921'-6927', 7033'-7038', 7046'-7064', 7078'-7108° , 6027'-6033', 6123'-6127', 6134'-6149', 6161'-6187' 3.5", 9.3#, J-55 @ 6962', 2.875", 6.5 #, J-55 @ 6962'-6988' Packers and SSSV (type and measured depth) Otis Baker HB @ 6739', Baker FB-1 @ 6957', SSSV: Camco TRDP-1A-ENC @ 1826' 13. Stimulation or cement squeeze summary 14. Continuing to inject, shut-in C sand. Intervals treated (measured) N/A Treatment description including volumes used and final pressure Performed alternate MIT on 4/10/94, fp: 7" csg @ 2825 psi, tbg @ 2550 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl RECEiViD MAY -5 1994 ,,t~s~ ul~ & Gas ConS. C Prior to well operation Casing Pressure Tubing Pressure 2325 Subsequent to operation 0 0 5331 2700 0 0 1150 1600 2375 Service WAG Injector 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Repprt of Well Operations X Oil Gas Suspended 17. I hereb~/~?ertify/t~ahthe.foreg/~ing, iLtrue and correct to the best of my knowledge. Signed ~//'~~' ~ Title Sr. Engineer SUBMIT IN DUPLICATE Form 10-404 Rev 06/15/88 ARCO Alaska, Inc. -O KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME ~COMPLETE [] INCOMPLETE FIELD EST: $ AFC/C~Ccd: 401 ~30PS[° ACCUMULATED COST PAGE 1 OF ~ ooo /~C ) [-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp. IChiilFactor I Report ~[O °F °F AR3B-7031 Visibility I Wind Vel. milesI knots ~'~ -- 5 ~994 .,.,o~ 0~ & ~as Oons. Commission ~98-3486 A v/¢ T?/ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 7, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in triplicate is an Applications for Sundry Approval on the following Kuparuk well. Well Action 1Y-11 Variance · Anticipated Star~ Date February 1994 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED FEB -9 1994 Alaska 0ii & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program __ Operation Shutdown ~ Re-enter suspended well ~ _ Plugging __ Time extension _ Stimulate _ Pull tubing ~ Variance X Perforate ~ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T12N, R9E, UM At effective depth 1482' FSL, 1670 FEL, Sec. 2, T12N, R9E, UM At total depth 1495' FSL, 1735' FEL, Sec. 2, T12N, R9E, UM 12. Present well condition summary Total Depth: measured 7 7 2 5 true vertical 6 7 2 3 5. Type of Well: Development ~ Exploratory _ Stratigraphic __ Service _.~ feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 96 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 9. Permit number 83-41 10. APl number 50 -029-20926 11. Field/Pool Kuparuk River Field/Oil Pool None Effective depth: measured true vertical 7 5 8 8 feet Junk (measured) 6 6 0 2 feet Casing Length Structural Conductor 1 1 5' Surface 21 8 0' Intermediate Production 7 6 3 4' Liner Perforation depth: measured 6819'-6914' true vertical 5942'-6022' Tubing (size, grade, and measured depth) Size Cemented 1 6" 300 SX AS II 9 5/8" 1000 AS III & 25O SX AS I 7" 980 SX Class G & 250 SX AS I DV & SOS in rat hole below 7153' (last tag) Measured depth True vertical depth 115' 115' 2218' 2218' 7699' 6673' , 6921'-6927', 7033'-7038', 7046'-7064', 7078'-7108' , 6027'-6033', 6123'-6127', 6134'-6149', 6161'-6187' 3.5", 9.3#, J-55 @ 6962' & 2.875", 6.5#, J-55 @ 6962'-6988' Packers and SSSV (type and measured depth) PKR's: Baker "HB" @ 6739' & Baker "FB-I"@ 6957'; SSSV: CAMCO TRDP-1A-ENC @ 1826' 13. Attachments Description summary of proposal ~ 3.5" x 7" Communication. 14. Estimated date for commencing operation February 1994 16. If proposal was verbally approved Name of approver Date approved Detailed operation program _ BOP sketch 15. Status of well classification as: Oil ~; Gas Service Suspended Signed17' I her:~~ ~)t the,, ~f°reg°ing is true and correct to theTitle Sr, EngineerbeSt of my knowledge. FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test Location clearance Mechanical Integrity Test ~ Subsequent form require 10- l,{dq. Original Signed By David W. Johnston Approved by order of the Commission RFc~IVED -- Form 10-403 Rev 06/15/88 An~orage IApproval No. Commissioner Date ,~//'~"(/? ~,' SUBMIT IN TRIPLICATE Approved Copy Returned Attachment 1 Request for Variance Kuparuk Well 1Y-11 As per Area Injection Order No. 2, Rule 7, ARCO Alaska is hereby notifying the Commission of pressure communication between the tubing and casing in Water Injection Well 1Y-11. As set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW). Well 1Y-11 was converted from an oil producer to water injector in June 1989, and to a WAG injector in October 1990. The well is currently injecting approximately 6000 BWPD at an average surface injection pressure of 2200 psi. Diagnostic work indicates that the source of the communication is the merla tubing patch located at 6741' WLM- RKB (Attachment 2). The patch was set in November of 1992 across the Baker 'HB' packer to repair a leak identified with a downhole camera. After setting the patch the tubing and 7" annulus passed a pressure test, as indicated in the field Well Service Report shown in Attachment 3. The well was subsequently fracture stimulated, and shortly thereafter developed slow tubing to 7" annulus communication. Diagnostic work indicates that there are no external casing leaks, and injection fluids are confined to the Kuparuk River Sands. An ~ MIT is requested, consisting of a combined tubing and casing pressure test, in order to satisfy Area Injection Order No. 2, Rule 6. Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. RECEIVED FEB -9 1994 WelI:IY-1 I Attachment 2 ARC{., _~LASKA INC. - KUPARUK FIELI APl# 50-029-20926-00 Spud Date: 0 3 - 0 7 - 8 3 C Sand: OPEN Completion Date: 0 3 - 2 3 - 8 3 A Sand: OPEN Maximum Hole Angle: 43 deg. @ 3700'MD Original Rig RKB: 26,3' All depth are RKB MD to top of equipment. Well Type: MWAG INJECTOR Tree Type: FMC GEN II 3-1/8" 5000# Tree Cap Type: OTIS UNION Tree Cap Size: 3.5" Tree Cap O-ring ASN:302-7856 Last Workover Date: 0 5 - 2 7 - 9 0 Jewelry I sssv: CAMCO TRDP-1A-ENC ID 2.812" @ 1826' 2 PBR: BAKER ID 3.00" @ 6725' 3 PKR: BAKER HB ID 2.89"@ 6739 Otis Patch ID 2,347" & COLLAR STOP ID 2" 4 SBR: BAKER ID 3.000" @ 6956' 5 PKR: BAKER FB-1 @ 6957' 6 CROSSOVER: 3.5" x 2 7/8 @ 6962' 7 NOGO:Camco 'D' Nipple 2.25" w/AVA 1.81" ID Nipple Red, @ 6976' 8 SHEAR OUT: BAKER @ 6987' 9 TUBING TAIL @ 6988' Minimum ID: 1.370"1D AVA Reduced Nipple Slve. @ 6944' Casing and Tubing Size Weight Grade Top Bottom Description 1 6" 65# H-40 0 11 0' CASING 9.625" 40# J-55 0 2218' CASING 7" 26# Jo55 0 7669' CASING 3.5" 9.3# J-55 0 6962' BTC-Mod IPC TUBING 2.875" 6.5# J -55 6962' 6988' TUBING Gas Lift Information Depth Stn# Valve Type Sz. Latch Port Sz. ~,ID# Date Run 6680' I DV 1.5" RK 1 -1 3-93 6775' 2 DV 1.5" RK 01 -21-91 6944' 3 AVA TPL TPC 1.875" (1.370 ID) COMM 4-10-93 RECEIVED FEB -9 1994 Alaska Oil & Gas Cons. Commission Perforation Data Anchorage Interval SPF Date Zone Comments 681 9-6914 1 2 C 5" Geo-Vann120phase 6921-6927 1 2 B 5" Geo-Vann120phase 7033-7038 1 2 A5 5" Geo-Vann120phase 7046-7064 1 2 A4 5" Geo-Vann120phase 7078-71 08 1 2 A3 5" Geo-Vann120phase Comments: DV run 06-25-90 lost in hole. Shear out sub in rate hole 12-03-92. *AVA 2.25"xl.81" nipple reducer @ 6976'/ AVA ported nipple reducer 2.75"x 1.875"@6944'. I.D. thru sleeve @ 6944' 1.375"(pull w/2.0"G.S.) Top of patch 6740.8' Bottom of patch 6745.4' Appears to be a tbg. X 7" communication at the MERLA PATCH LAST TD:7153' 1-13-93 PBTD: 7588' PBTDSS: 6506' LAST REVISION:4-11-93 ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL CT'~'g"' //' PBDT REMARKS ~/T~ - ~EeC~ '7" ~. -/~c.c ~ WELL SERVICE REPORT FIELD- DISTRICT- STATE !DAYS IOPE~ATION AT REPORT TIME IDATE //- 3L-- ~.2 O'?CD 08'-/5 fcOO i /O~Tc~ ~.?5"x ~.ef'(s~ r~ s~'~) /i5 ~h~ i05,2 P.u. ~T ~ p,~7~w ~ ?GH ,szow~y ~j ~$~.d' eeL ~~. ~ObNC; m_$. I'?C.O /¢'$T ) RECEIVE[.: FEB -9 1994 ~/~ET~ '~B' /%(:~'E~ C;-' &"75c/' ,4:',~"~''~K" u~l & Gas Cons. Comm,,s,, ~ncnorage · ?AE$$u~£ 7'~$TE.b I'--BG. '~c 5t-C, CU'~. 7"A,v,t/c~L~S io°~0~ 13(¢ ~ CC,u3/STS' 6'P eS~4~A~./xlG Ou_'T '7-/4E ,,$'/-t~AR CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Report - ~ 'F - ~.3 'F mila knots MAY 20 '94 09:30AM KUPARUK PETROLEUM EHGIMEERIMG Attachment 1 Request for Variance Kuparuk Well 1Y-11 · As per Area Injection Order No. 2, Rule 7, 'ARCO Alaska is hereby notifying the Commission of pressure communication between the tubing and casing in Water Injection Well 1Y-11. AS set forth in the Rule 7, ARCO Alaska is requesting Commission approval to continue water injection into this well. As found in Area Injection Order No. 2, the aquifers described by a 1/4 mile area beyond and lying directly below the KUparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b) (3) and 20 AAC 25.440(c). As such, continued injection will not endanger any Underground Source of Drinking Water (USDW). Well 1Y-1 ! was converted from an oil producer to water injector in June 1989, and to a WAG injector in October 1990. The Well is currently injecting approximately 6000 BWPD at an average surface injection pressure of 2200 psi. Diagnostic work indicates that the source of the communication is the merla tubing patch located at 6741' WLM- RKB (Attachment 2). The patch was set in November of 1992 across the Baker 'HB' packer to repair a leak identified with a downhole camera. After setting the patch the tubing and 7" annulus passed a pressure test, as indicated in the field Well Service Report shown in Attachment 3. The well was subsequently fracture stimulated, and shortly thereafter developed slow tubing to 7" annulus communication.. Diagnostic work indicates that there are no ex_t.e_r.n,a_J_casing leaks, and injection fluids are confined to the Kuparuk River Sands. An ~ MIT is requested, consisting of a combined tubing and casing pressure test, in order to satisfy Area Injection Order No. 2, 'Rule 6..Casing and tubing pressures will continue to be monitored and reported as per Area Injection Order No. 2, Rule 4 to ensure that the casing pressure does not exceed 70% of the casing's minimum yield strength. RECEIVED FEE) -9 1994 ~ & Gas ~ns. Oommission Anchorage MAY .20 W. i !=..'[X_~-1-1. APl# 50.029-20926-00 Spu¢l Date: 03-07-83 C~~ ~mple~on D=~: 03 -2 3 - 8 3 A~: ~ximum Hole A~le: ~ d~. ~ 3700'MD OHgin~ Rig R~: 26.3' All-depth a~e RKB MD to top of ~uipment. 09: 3lAM KUPARUK PETROLEUM EHGIHEERIH~.-,,,~, ~ ~.,,- AR~ AI.A~KA Ir~t;. ' e,u~'~n~,~, FIE. . Welt Ty~ ~IVVAG INJECTOR Tree Type: FMC GEN II 3-1/8" 5000# Tree Cap Type: OTIS UNION Tree C, ap Size: 3,5" Tree Cap O-ring ASN:302-7856 Lest Workover Date: 0 5 - 2 7 - 9 0 ewelr¥ SSSV: CAMCO TRDP-1A-ENC, ID 2.612" @ 1826' PBR: BAKER ID 3.00' @ 6725' PKR: BAKER HB ID 2.89" @ 6739 Otis Patch 113 2.34T' & COLLAR STOP ID 2" SBR: BAKER ID 3,000' @ 6956' PKR: BAKER FB-1 (~ 6957' CROSSOVER: 3.6" z 2 716 @ 6962' NOGO:(~atnco 'O' Nipple 2.25" w/AVA 1.81" ID Nipple Red. @ 6976' SHEAR OUT: BAKER @ 6987' TUBING TAIL ~) 6988' Minimum iD: 1.370"1D AVA Reduced NIpple Siva. @ 6944' Ceain9 and Tubing ~ Weielht Grade ~ ~ 1 6" 66# N-40 0 11 0' GASlNG 9.6 25' 40# J -55 0 2218' ~1~ ~ 26~ J-55 0 7669' 3.5" 9.3~ J-55 0 6962' BTC-Mod IPC TUBING 2.875" 6.5e J-SS 6962' 6986' ~NG 6775' 2 IN' 1.5" RK 6944' 3 AVA TPL TPC 1.875~ (1.370 ID) C, OMM 01-21.91 4.1 0-93 Perforation Data Interval ~ Date Zon~ ~ 6819.6914 12 ¢ 6" <3eo-Vann120phase 69;~1.6927 1 2 B 6" Geo. Vann120phase ?033-7038 1 2 A5 5" Geo,Vann120phase 7046-7064 1 2 A4 6" Geo. Venn120phsSe 7078-7108 12 A3 5" Geo-Venn120phase Comments: OV run o6-25-90 lost in hole. Shear out sub in rate hole 12-03-92- *AVA 2.25"x1.~1" nipple reducer ~ 6976'/ AVA ported nipple reducer 2.73"x 1.675"(~6944'. t,D. thru aleev® @ 6944' 1.373"(pull wl2.0"G.$,) Top of I~eteh 6740.6° Bottom of pet(th 6745.4' Appee~ to be a tbg, X 7" eommunleatlon at the MERLA PATCH LAST TD'7153' 1-13-93 pB'FD: 7588' PBTDSG: 6506' LAST REVISION:4-11-93 STATE OF ALASKA /-~ AI.A,.51<A OIL AND G/sS CONSERVATION COMMI~ON (,_,/'~ REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate Alter casing Repair well Other 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T12N, R9E, UM At effective depth 1482' FSL, 1670' FEL, Sec. 2, T12N, R9E, UM At total depth 1495' FSL, 1735' FEL, Sec. 2, T12N~ R9E~ UM 12. Present well condition summary Total Depth: measured 7 7 2 5 true vertical 6723 6. Datum elevation (DF or KB) RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-11 9. Permit number/approval number 83-41/90-1 25 10. APl number so-029-20926 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 7 5 8 8 true vertical 6602 feet feet Junk (measured) DV & SOS @ 7153' Casing Length Size Structural Conductor 1 1 0' I 6" Surface 21 8 0' 9 - 5 / 8" Intermediate Production 7 6 3 4' 7" Liner Perforation depth: measured 6819'-6914', true vertical 5942'-6022', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 300 SX AS II 1 10' 1 10' 1000 AS III & 221 8' 2218' 250 SX AS I 980 SX Class G & 7669' 6673' 250 SX AS I 6921'-6927', 7033'-7038', 6027'-6033', 6123'-6127', 7046'-7064', 6134'-6149', 7078'-7108' 6161'-6187' 3.5", 9.3#, J-55 @ 6962', 2.875", 6.5 #, J-55 @ 6962'-6988' Packers and SSSV (type and measured depth) Otis Baker HB @ 6739', Baker FB-1 @ 6957', SSSV: Camco TRDP-1A-ENC @ 1826_'_ RE 13. Stimulation or cement squeeze summary Continuing to inject. Intervals treated (measured) N/A JUL Treatment description including volumes used and final pressure N/A .laska 0il & Gas Cons. C;0rnm'tss~0~ 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service WAG Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned --'--' Title Sr. Engineer --orrn 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE KDC~S MORNINQ WELL REPORT FOR 04/29/93 .............. DR iLC§'iYE -:i?':x-~-~7' 7--..-'. PAgE 1 PRODUCTION WELL STATUS gAS LIFT STATUS i,90R = 30000 SI DAT, ......... . W Z S GAS E 0 T CHOKE ...... '7" ' -' :Ti~'~-";7ZTT--;7 ....... INd .OPT OPT L N A OR WC H2S CS~._. ..... csg ........ ~ETER VOL RATE <}L. L E T % FTP FTT %, PPM PSI ' PSI --- READIN¢ MSCF M~EF-',~.,. u ROOTS. 3 B' PR 176'--186' 127- 75 -44 1420 860 .: ;'-_- ....... 0 1580 4 A TS 17~ ISl 7~ 30 200 1400 le0 0 1238 5 B PR 178 ~91 '139 69 ' ~5"-1320" i'20o~ ....... ; ........ -~o -ilJl 6 A PR 176 163 62 90 65 740 0 0 5i8 14 A PR t00 193 89 ' 5 .... 50 7800 ..... 9~0 .... -" 7 ......:'-~'; 596 i6 A PR 176 i85 88 2 35 '400 720 0 507 25 B PR'"---'i7& 197-':/l'3b"'eb ..... 7,:-'--: .... .... ¥e4 26 B PR 176 196 142 78 40 1400 960 0 807 ~9 B PR -'I76 267 ~i38 84 '60 'l'6~'-;'--',220-'x~-":'~':'-!'-T%: ..... ';'0 .... 0 30 B PR i76 219 14.0 8.4 80 2000- 880 0 0 32 B PR 176 236 136 84 80 1300"-"-¥8~0'-; ''':--;''-: .... 7-'_ .... 0 1252 500 5. 8 0 O. 0 121 6. 0 500 ~,%. 7 655 ]. 1.3 50(} 5. 4 775 5. 7 ..... 5.1 0 0. 0 0 O. 0 462 !. 9 .. TO, m~ ..... ...... -"- ..................... 8413 6646 INJECTION WELL. S'I'ATUS ..... - ..... INJECTION VOLUMES S! D*''-'' w z s .................. - : -.WATER .RECMD gAS E 0 T CHOKE 7" 10" . - t. INd INd INd H M 0 L N'-;A ..... OR'-' iN,J ....... CS-~-.;7'cSe .... :RETER .... ,MOL.--"'~'ATE VOl_ R L E T % PSi FTT PSI PSI READIN~ BBLS BWPD MMSCF S ~ B MI ~00.34'71 109 325 0 0 0 0 ~. t,/,,~. ,,.. ,, = B MI lO0 3,.~ 108 90 0 ; -0 ...... .:.' '-0 - 0 1~ 2n" ~'~c, nO (} 7 B PW 176 ~']0:~ 144 560 t40 0 3854' 4085 0 0(',0 ~ ~ '-- ~ ........... ~,. -~ ..... -,- ...... ~ .... . .... . . ,~ .. ~ / .L ,~,~' -~' 8 B PW 176 ~309' t51 40~ ' 360 ........ 0 ....4413 4477 O. 0(}0 0000 O 9 B MI- 100 3403 1~0 0 0 0 0 0 5. C, OOPi 0000 0 tO B PW 100 2269 ~151 660 350 ...... - ;~-'--~'3i].-- 5~01 O. 000 000(} 0 12 B PW 176 2287 157 -1560 900 ' -- 7;.0'-.7-~24' 5574 O. OOC, 0000 0 · 3 ~ PW lO0 '~ . '? =.=..~ 151 1040 400 0 7968 6743 O. 000 ,.-~ ,, ,, ~ ,. ............ i5 ~ PW I00 a2~19 fsi aSOOa 725 ................. 0 .... ;'4-~25 7T 7~54 O. 000 OC.(;;:O 0 TOTAl S' 7'.J ' ' .' .......... ..... I¢.41 0 + PWI' J7308'= --~7308 -38701 35 2,.'~:; H M f R I ~ S N ; 0000 0000 ,. 0000 0000 0000 0000 0000 0000 0000 OOOO 0000 JUL i AlaSka Oi~ & GaS Goos. STATE OF ALASKA ~ OIL AND GAS ~RVATION COMIVli,~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforateot h~e r~_~ I Pull tubing Alter casing Repair well //'~1 . 5. Type of Well: 6. Datum elevation (DF or KBS- Development ' ;ee'~t~ Exploratory _ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Stratigraphic Service X 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T12N, R9E, UM At effective depth 1482' FSL, 1670' FEL, Sec. 2, T12N, R9E, UM At total depth 1495' FSL, 1735' FEL, Sec. 2, T12N~ R9E, UM 12. Present well condition summary Total Depth: measured 7 7 2 5 true vertical 6723 m RKB 96 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 9. Permit number/approval number 83-41/9-232 10. APl number s0-029-20926 11. Field/Pool Kuparuk River Field/Oil Pool feet Plugs (measured) None feet Effective depth: measured 7 5 8 8 true vertical 6602 feet feet Junk (measured) DV & SOS @ 7153' Casing Length Size Structural Conductor I 1 0' 1 6" Surface 21 8 0' 9 - 5 / 8" Intermediate Production 7 63 4' 7" Liner Perforation depth: measured 6819'-6914', true vertical 5942'-6022', Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 300 SX AS II 1 1 0' I 1 0' 1000 AS III & 221 8' 221 8' 25O SX AS I 980 SX Class G & 76 6 9' 6 6 7 3' 25O SX AS I 6921'-6927', 7033'-7038', 7046'-7064' 6027'-6033', 6123'-6127', 6134'-6149' 7078'-7108' 6161'-6187' 3.5", 9.3#, J-55 @ 6962', 2.875", 6.5 #, J-55 @ 6962'-6988' Packers and SSSV (type and measured depth) Otis Baker HB @ 6739', Baker FB-1 @ 6957', SSSV: Camco TRDP-1A-ENC @ 1826' RECEIVED J U L 2 5 t99 5 Alaska 0il & Gas Cons. C0mt'nissi0 13. Stimulation or cement squeeze summary Converted oil producer to MWAG injector on 6/11/89. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1650 749 1937 157 1334 Subsequent to operation - 0 - - 0 - 2800 1400 2400 15. Attachments Plot of Inj. Rates & Pressure 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations Oil Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C ~(.~. .~'~~ Title Sr. Engineer Form 10-404 Rev 06/15/88 Service MWAG Injector SUBMIT IN DUPLICATE To: isle: Well Name I .o~ Run I)atc Kuparuk Kupamk Kuparuk Kuparuk Kupamk Kupamk Kupamk Kuparuk Kuparuk Kupamk Kuparuk Kuparuk Kuparuk K u pal uk Kuparuk Kuparuk Kupamk Kupamk Kuparuk Kuparuk Kuparuk River Unit IA-Il P, iver Unit 11~-10 River Unit .River Unit 1[,-17 Rivet Unit 1I~-22 River Unit 1R 04 lover Uni! 1¥'-10 12ive. r [.~nii | River Unit 17--12 tU,~er U.it 1Y--IS River Unit 21-3-08 River unit 2c-o2 River Unit 2C 05 River Unit 2C-06 River Unit 2V~ 13 ~ver Unit 3G-12 River Unit River Unit 3G-20 Water How i.og ('ii)T--P) Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile Injection Profile j ii ..... in ex: on l~rOt~le Injection Profile Injection Profile Injection Profile Injection Profile Inj~tion Profile Survey Inieclion Profile Survey Injection Prefile Production Production Log Injection Profile Injection Profile Survey Injection Profile 07.IA N 1991 10-1-91 03 NOVEMBER1991 4 NOVEMBER 1991 4 NOVEMBER 1991 11-06~ 1991 6/30/91 12-13-1991 I I-i9-9i 11--17-1991 12-2-91 12-27-.1991 26 DEC 1991 10-27d991 11/25/91 11~16-1991 8-.IiJNE-1991 31-JULY--1991 11 NOV 1991 10/119/91 11-29-1991 HcceiYed by:_ ~ Dated: Copy sent to sender: Yes // No ~ RECEIVED MAR 2. 6 1992. Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 0 1. Operations performed: Operation Shutdown Pull tubing X Alter casing Stimulate __ Plugging Perforate Repair well Other . 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T11N, RgE, UM At effective depth 1482' FSL, 1670' FEL, Sec. 2, T11N, RgE, UM At total depth 1495' FSL, 1735' FEL, Sec. 2, T11N, R9E, UM 12. 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) 96' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 9. Permit number/approval number 83-41/9-{~)4 10. APl number 50-029-20926 11. Field/Pool Kuparuk River Oil Pool Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7725' feet Plugs (measured) None 6723' feet 7588' feet Junk (measured) 6602' feet feet Tubing conveyed perf gun @ 7219' md Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 47' 1 6" 300 Sx AS II 73'md 73'tvd 21 92' 9-5/8" 1000 sx AS III 2218' md 2218' tvd 250 SX TOP JOB W/AS I 7643' 7" 980 sx Class G 7699' md 6673' tvd 25O SX ASI measured 6819' - 6914', 6921' true vertical 5942' - 6022', 6027' - 6033', 6123' - 6127', 6134' - 6149', 6161' 6927', 7033' - 7038', 7046' - 7064', 7078' - 7108' - 6187' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 TBG W/ TAIL @ 6989' Packers and SSSV (type and measured depth) Baker "HB" Pkr @ 6739', Baker "FB-I" Pkr @ 6957', Camco "TRDP-1AENC" SSSV @ 1827' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X Reoresentative Daily Averaoe Production or Iniection Data · ~' ~'.- OiI-Bbl Oas-Mcf - Water-Bbl Casi.n.g PreSSure. ~' !" ~u~i~g Pressure · 16. Status of well classification as: Water Injector__ Oil _ Gas Suspended servic~'"~W'AG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 ReY~ 05/17/89 Title Area Drilling Engineer Date ~~~ SUBMIT IN DUPLICATE ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel~;rt" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to Spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough ARCO ALASKA INC. I NORTH SLOPE Field ILease or Unit KRU I ADL: 25646 ALK: 2577 Auth. or W.O. no, ITitle I WORKOVER IState AK Iwell no. 1Y-11 Operator ARCO Spudded or W.O. begun IDate IHour SPUD I 03/07/83 J12:00 Date and depth as of 8:00 a.m. 05/19/90 (1) TD: 7725 PB: 7588 SUPV:DEB O5/20/90 (2) TD: 7725 PB: 7588 SUPV:DEB 05/21/90 (3) TD: 7725 PB: 7588 SUPV:DEB 05/22/90 (4) TD: 7725 PB: 7588 SUPV:DEB 05/23/90 (5) TD: 7725 PB: 7588 SUPV:DEB 05/24/90 (6) TD: 7725 PB: 7588 SUPV:DEB Complete record for each day reported NORDIC 1 MOVING RIG MW: 0.0 MOVING RIG FROM DRILL SITE 2K TO DRILL SITE 1Y IARCO w.i. 55.8533 Prier status if a W.O. DAILY:SO CUM:SO ETD:SO EFC:$585,000 MW:10.8 NaC1/Br FINISH MOVING RIG, ACCEPT RIG 19-MAY-90 09:30, FLUSH PITS, PULL BPV, RU OTIS SLICKLINE, PULL GLM @ 6642, POH, RD OTIS, KILL WELL, KILL ANNULUS, CIRCULATE, WELL DEAD, FLUID LOSS = 13 BBLS, SET BPV, ND FMC GEN II 3 1/8' TREE, NU BOPE, TEST BOPE, STEM DAMAGED, REPLACEMENT ORDERED DAILY:S79,887 CUM:$79,887 ETD:S79,887 EFC:$585,000 POH W/ 3.5" TBG MW:ll.0 NaCl/Br CONT. TST BOPE, PULL TP & BPV, NU FLOW NIPPLE & FLOW LINE, BOLDS, PU TO 120K#, WORK OEJ FREE, WEIGHT UP TO 11 PPG MUD, WELL STABEL, POH W/ 3.5" TBG, CHG COUPLINGS, ELEVATORS STICKING DAILY:S31,295 CUM:$111,182 ETD:S111,182 EFC:$585,000 RIH W/ HOWCO 7" RBP MW:ll.0 NaCl/Br CONT. POH W/ 3.5" COMP. ASSY., CHG CPLGS, RECOVERED ALL COMPLETION ASSY. INCLUDING PACKER, MU HALLIBURTON OVERSHOT AND RBP, RIH ON 3.5" DP DAILY:S33,416 CUM:$144,598 ETD:S144,598 EFC:$585,000 REAM 7" W/ BIT & SCRAPER MW:ll.1 NaCl/Br CONT. RIH W/ RBP, SET @ 6490, TEST RBP& 7" CSG, RIH W/ RTTS & STORM VALVE & SET @ 36', HANG OFF DP,ND BOP, ND FMC GEN II TUBING HEAD, NU FMC GEN II RETROFIT, TUBING HEAD, NU BOP, RIH, UNSEAT RTTS, POH W/ STORM VALVE AND RTTS, RIH W/ STANDS DP, BREAK CIRC. AND CIRC. OVERSHOT ONTO RBP, POH W/ RBP, RU SCHLUMBERGER, RIH W/~.95" GR & JB, SET DOWN AND STUCK W/ SAME @ 6840', SPRANG FREE, POH, RIH W/ 3.5" DP & 6.125" BIT & SCRAPER, REAM IN SINGLES FROM 6773- 6830 DAILY:S41,731 CUM:$186,329 ETD:S186,329 EFC:$585,000 The above is correct DAILY: $50,518 CUM: $236,847 ETD: 5236, U47 For form preparation an~ ~,,,~ibu, i_on. ,~ see Procedures Manual,%,~ection 10, Drilling, Pages 86 and 87. RIH W/ 6" TAPERED MILL MW:ll.1 NaCl/Br CONT. REAMING, CLEAN OUT FILL TO 7209', CIRC. HOLE CLEAN, NU, CIRC. HEAD, CIRC. AND CONDITION SALT CONTAMINATED MUC, POH, RU SCHLUMBERGER, MU 5.95" GAUGE RING & JUNK BASKET. K£~, TAt~J~D OD~T~U~TION AT 6840' WLM, POH, PU' ~.~" RING AND JUNK BASKET, RIH TO 7071' WLM, OK, POH, MU BOTTOM COMP. ASS., RIH ON WL, TAG OBSTRUCTION AT 6840' WLM, WORK WL REPEATEDLY-NO GO, POH, LD PACKER, NO SCARS, RD SCHL., RU TO RIH W/ 3.5" DP AND TAPERED MILL, RIH ~FC:~b~D,U00 AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. Page ,o. ARCO Oil an¢] ~as Company ~, Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or peHorating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Field ~n,~.~..,~ ..~.~. ....... JLease or Unit ADT,: ~;4R ALK.- 2577 Cate and ~ Complete record for each day while drilling or workover in progress as of 8:00 a.m. 05/25/90 ( TD: 7725 PB: 7588 SUPV:DEB 05/26/90 ( TD: 7725 PB: 7588 SUPV:DEB 7) 8) POH W/ FB-1 PKR MW:ll.1 NaCl/Br RIG SERVICE, CONT. RIH W/ 6" TAPERED MILL, REAM 6775'-7050', ROUGH PERFS @ 6830', REAM THROUGH SEVERAL TIMES, REAM_ EACH SINGLE DOWN 3 TIMES TO BELOW PKR SETTING, RIH W/ 2 STANDS TO 7180', CIRC. HOLE CLEAN, POH, RU HLS, MU 5.9" GR/JB, RIH, 2 STANDS WL BROKE, POH, REHEAD A/qD RESTRING LINE, RIH W/ 5.9" GR/JB TO 7083' WLM, NO OBSTRUCTOINS, POH, RIH W/ PACKER, SET DOWN @ 6844' WLM, WORK LINE TO GET PAST, NO GO, POH W/ PKR ASS. DAILY:S31,327 CUM:$268,174 ETD:S268,174 EFC:$585,000 RUNNING 3.5" COMP. ASS. MW:ll.1 NaC1/Br CONT. POH W/ WL, LD PACKER/TAILPIPE ASSY. RD HLS, NU FLOW NIPPLE, RU TO RUN DP, PU PKR/TAILPIPE ASSY., RIH ON 3.5" DP, RU HLS, RUN INSIDE DP W/ GR/CCL, CORRELATE PKR DEPTH, TOP OF PKR @ 6944' DPM (6957' WLM), POH AND RD HLS, DROP BALL, SET PKR, POH W/ 3.5" DP, LD PKR SETTING TOOL, RU TO RUN TBG, RUN COMP. ASSY W/ RERUN TBG W/ NEW CPLGS, 9 STANDS IN @ O600 DAILY:S43,954 CUM:$312,128 ETD:S312,128 EFC:$585,000 Well no. 1Y-11 Signature ~ ~ For form preparation a~t distribution see Procedures Manual-Section 10. Drilling, Pages 86 and 87 AR3B-459-2-B Number all daily well history forms consecutively as Ihey are prepared for each well. IPage no. ARCO OI, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday alter allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" Iorm may be used for reporting the entire operation if space is available. Accounting cost cenler code District County or Parish Stale A~.CO ALASKA IN:C. Lease NOlO. TH SLOPE AK Well no, Field or Unit KRU ADL: 25646 ALK: 2577 1Y-11 Aulh. or W.O. no. [ T t e I Operator A.R.Co. W.I. ARCO Date 55. 8533 Spudded or W.O. begun SPUD 03/07/83 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 05/27/90 ( TD: 7725 PB: 7588 SUPV:DEB Iotal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our Prior status if a W.O. RIG RELEASED MW:ll.1 NaCl/Br CONT. RUNNING 3.5" COMP. ASSY, MU REDRESSED CAMCO SSSV, MU 1/4" CNTL LINE AND TST TO 5000 PSI, FINISH RUNNING 3.5" TBG, TAG PKR, MU FMC GEN II RETROGIT TBG HNGR, LAND TBG AND RILDS, SET PKR, BOLDS, SHEAR PBR, RELAND HNGR, RILDS, CLOSE SSSV, NU FMC GEN II RETROFIT, TST PACKOFF TO 5000 PSI, OK, DISPLACE WELL TO CLEA/~ DIESEL, SHUT-IN AND MONITOR WELL, CLOSE CV IN GLM @ 6681, SECURE WELL, RELEASE RIG @ 2400 DAILY:S66,775 CUM:$378,903 ETD:S378,903 EFC:$585,000 Old TD Released rig INew TD PB Depth Date Kind of rig Classifications (oil, gas, etc.} Type completion (single, dual, etc,) Producing method Official reservoir name{s) Potential test data Well no. Date Reservoir Producing Intelwal Oil or gasTest time Produclion Oil 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 " Date Drilling, Pages 86 and 87. AR3B-459-3-C Number ell daily well histo~ forms consecutively I Page no. as they are prepared for each we . I I Dlvl~on of AtllntlcRIchfleldCompa~y ARCO Alaska, Inc Post Office =ux 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 21, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in triplicate is an Application for Sundry Approval on the following Kuparuk well. , W~ll Action Anticipated Start Date 1 Y- 1 1 Variance February, 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 r -. ' ~'" STATE Of ALASKA AL,~,~KA OIL AND GAS CONSERVATION COMMISSION ~ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate__ Pull tubing _ Vadance X Perforate _ Other 2. Name of Operator ARCO Alaska, lng. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well' Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T11N, R9E, UM At effective depth 1482' FSL, 1670' FEL, Sec.2, T11N, R9E, UM At total depth 1495' FSL, 1735' FEL, Sec. 2, T11N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 6819'-6914', 7725' 6723' measured 6602' Length 47' 2192' feet feet 7588' feet Size 16" 9 5/8" 7643' 7" measured 6921 '-6927', Plugs (measured) feet Junk (measured) 6. Datum elevation (DF or KB) RKB 96' 7. Unit or Property name Kuparuk River Unit 8. Well number 1Y-11 9. Permit number 83-41 feet 10. APl number 5o-029-20926 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool ~ : ?- ~'~ !'~ i! :~ ':~ '~ ' i: ~-' ~"~' ~ '~' ;~' ~'~:' ii.' i~i Cemented Measured depth 300 Sx AS II 73' 1000 SxAS III & 2218' 250 Sx top job w/AS I 980 Sx Class G 7 6 9 9' 250 Sx AS I 7033'-7038', 7046'-7064', 7078'-7108' True ~ei~J~l; ~lepth 73' 2218' 6673' @ 12 SPF true vertical 5942'-6022', 6027'-6033', 6123'-6127', 6134'-6149', Tubing (size, grade, and measured depth 3 1/2", 9.3#, J-55 set at 6741' RKB Packers and SSSV (type and measured depth) Camco HRP-1 SP packer @ 6709', Camco TRDP-1AE-SSSV @ 1895' 61 61'-6187' @ 12 SPF 13. Attachments Description summary of proposal ~X Detailed operation program ~ BOP sketch 14. Estimated date for commencing operation ~ Continued Operation 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~ Service ..WAG In!ector Suspended 17. I he. by certif_y that .the foregoing is true and correct to the best of my knowledge. SignedI,\~.)(~I~O. ~ ~'~-~.'~-" ~;) Title Senior Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form require JApproval NO~)_.../,,~ I Approved by the order of the Commission Form 10-403 Rev 5/03/89 ORIGINAL SIGNED ~¥ ~ flr,NIE C, ~MITH Commissioner Date ~' '-//- ~ ~ SUBMIT IN TRIPLICATE 1Y-11 WAG Injector Sundry Notice to Continue Injection Request Approval to continue injection into Well 1Y-11. Slight communication from the tubing to the 7" production casing has been noted. The communication is not enough to cause the well to fail an AOGCC witnessed MIT nor subject the production casing to a pressure that exceeds the hoop stress regulation set forth in rule 4 of AOGCC Area Injection Order No. 2. The present condition of the well is operationally safe and poses no threat to the integrity of the production casing. The communication will be monitored closely to note any changes in it's present condition. A workover is planned on this well in early March to prepare the well for higher pressure WAG injection service with upgraded wellhead and tubing couplings. Background This well was converted from production to injection service in June 1989. After installing dummy valves in all gas lift mandrels, pressure testing revealed minor tubing by 7" communication. Significant scale buildup in the wellbore hampered attempts at locating the point of communication. The well's 7" annulus was pressure tested with a 5% decrease in 30 minutes. The well subsequently passed an AOGCC witnessed MIT and was placed in injection service. The 7" casing pressure is closely monitored and bled occasionally as appropriate. Sequence of 4/11-14/89 4/26-27/89 5/4/89 5/30/89 6/2/89 6/15/89 Events Dummy off gas lift mandrels/broach scale (Well Service Report attached) Check dummy valves for source of communication (Well Service Report attached) Check dummy valves for source of communication (Well Service Report attached) Electric Line Leak Detection Survey. No leak detected at any of the mandrels. Possible packer leak. (Well Service Report attached) Pressure test 7" annulus to 2200 psi. Pressure bled 5% in 30 minutes. (Well Service Report attached) Passed an AOGCC witnessed MIT. Report attached ARco Alaska, Inc. ~ WELL SERVICE REPORT Subsidiary of Atlantic Richfield Company WELL.. / y .,_ /// IPBDT I'FIELD'DISTRICT'STATE/I¢"/~/"~/~ j[DAYS! IDATEo/-, ,~, ' 8~ ITRACTOR ~,,/~.,~..~ _ ~~ ~~ ~~ISPE~TION ~T RE'RI TIME ~ ~~ ,R. Is'o =~ ./ (.._ ,all o -,¢ ,¢¢',,, ~ ~ i m4-Tr~.y . ~o ~ ~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. I Chill Factor i ~slblllty I W,.d Vel. ARCOAlaska, In '~ Subsidiar~ of Atlantic Richfield Company WELL I PBDT -~. ONTRACTOR r,,.MARKS FIELD- DISTRICT- STATE ~'.-~. ~. IOPERATION AT REPORT TIME WELL SERVICE REPORT j DAYIs jDATE #,.2/ l~q~ r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK 'ARCO Alaska, Ir~'., {) ,Subs. idtarry of Atlantic Richfield WELL / y - // [PBDTT~__~.~ / ~ONTRACTOR ' ~ 7'/s - _MARKS WELL SERVICE REPORT IFIELD- DISTRICT- STA/~ OPERATION AT REPORT TIME I--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ITemp' [ Chill Fact I Visibility IWindVel'Report OF °reF miles knots WELl; ARCO Alaska, Ir~. ~ Subsidiary of Atlantic Richfield Comp,..., IFIELD - DISTRICT- STATE ~ ~. ~_/. WELL SERVICE REPORT .. .. "4TRACTOR REMARKS PBDT 75~' _ IOPERATION AT REPORT TIME /AJ ,,",,'~m,~,,' ~ !~!~ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK ,w..~. I:"~ o, Ic''''"''- .,Iv''''''''~ .,,-Iw'""v'''- ,.o,.1~ ,~.~ ARCO Alaska, In~ <> S~Jbs,id4ary of Atlantic Richfield Company WELL/V-J/ I 7.5~ 'JPBDT J FIELD- DISTRICT-/~, ~./~'STATE "- ITRACTOR JOPERATION AT REPORT TIME I REMARKS WELL SERVICE REPORT I/DAYS I D~/,Ec~_~, ~'~ I-'] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather ] Temp. Report Chill.~.Factor I Visibility Wind Vel. ARCO Alaska, ~ubsi~ry of Atlantic Richfield Company WELL SERVICE REPORT ' WELL PBDT · ITRACTOR REMARKS IFIELD - DISTRICT- STATE o~ERATION AT REPORT TIME I'-I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather,Temp..Report, ,.IT-/7-"~ 'F Chill Fact°r ! VisibilitY/t--/// 'F ~ miles ] Wind Vel. -~ knots J~~.~.Si -~.~J"'~~..-' ARco Alaska, In,~. ~ Subsa:liary of Atlantic Richfield Company WELL -~' I¥-/~ JNTRAGTOR REMARKS PBDT I FIELD - DISTRICT- STATE 7~g~'I ,k--K. "~.//. IOPERATION AT REI~0RT TIME l',~"-_,o/-~?Z~ d ~ 410 -p-p/u/ WELL SERVICE REPORT DAYS J DA~,/ ]~" CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather j Temp. J Chill F~ctor.. [Visibility I wind Vel. D.~.....,,4 I '~')~"" .-- . ~ __,, _ _ ~ , ...... 'ARCO Alaska, Ir-~ {) · Subsidiary of Atlantic Richfield Com~. , WELL ly- // WELL SERVICE REPORT ; '-NTRACTOR -,', REMARKS FIELD- DISTRICT- STATE KUP~R OPERATION AT REPORT TIME r-"l CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK wo.,~o~ i~.~,, lc~,,:.~l~.,~,,,~ i-vo,. Report .,~,¢~ 0F er'F ~ miles ,-----' 'ARCO Alaska, Ir~ ~ Subsidiary of Atlantic Richfield Com~ W~ELI._ ty -/t "~NTRACTOR REMARKS WELL SERVICE REPORT IPBDT~..~! IFIELD-DISTRICT-STATE IDAYS , IOATE IOPER_..ATIoN AT RE~RT TIME .?~- r-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport i Temp. knots [Signal Ai'~'-'" fA OIL AND GAS CONSERVATION COM[ '"'-'";ION APPLICATION FOR SUNDRY APPROVALS0 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing X~ Variance _ Perforate _ Other~ change 2. Name of Operator ARCO Al~,ska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service feet 6723? feet 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FSL, 1285' FEL, Sec. 2, T11N, R9E, UM At effective depth 1482' FSL, 1670' FEL, Sec.2, T11N, R9E, UM At total depth 1495' FSL, 17,~5' FEL, Sec. 2, T11N, R9E~ UM 12. Present well condition summary Total Depth: measured 7 7 2 5' true vertical 6. Datum elevation (DF or KB) wellhead RKB ~)6 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-11 9. Permit number 83-41 10. APl number 5o-029-20~)26 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Effective depth: Casing Structural Conductor 4 7' Surface 2 1 9 2 Intermediate Production 7 6 4 3' Liner Perforation depth: measured measured 7 5 8 8' feet true vertical 6 6 0 2' feet Length Size I 6" 9 5/8" 7" Junk (measured) Tubing conveyed perf gun at 7,219' MD Cemented Measured depth True vertical depth 300 Sx AS II 73 1000 Sx AS III & 221 8' 250 Sx Top job w/AS I 980 Sx Class G 76 9 9' 250Sx AS I 6819'-6914', 6921'-6927', 7033'-7038', 7046'-7064', true vertical 5942'-6022', 6027'-6033', 6123'-6127', 6134'-6149', Tubing (size, grade, and measured depth 3 1/2" J-55 Tubing with tail @ 6741' Packers and SSSV (type and measured depth) Camco HRP-1-SP pkr @ 6709', Camco TRDP @ 1895' 7078'-7108' @ 12 SPF 6161'-6187' @ 12 SPF 73' 2218' 13. Attachments Description summary of proposal X Detailed operation program __ BOP ske~h X Convert water injector to a water alternating gas injector. (Wellbore schematic attached). 14. Estimated date for commencing operation I 15. Status of well classification as: October. 198~) ' I Oil _ Gas _ Suspended _ 16. If proposal was verbally approved j I Name of approver Date approved I Service Water Alternating Gas (WAG) Iniector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Mechanical Integrity Test FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness jtz/MAC Plug integrity_ BOP Test__ Location clearance__ Subsequent form require 10-/f-c'2ff Approved by the order of the Commission Form 10-403 Rev 06/15/88 Date IApproval No.~ .. I ORIGINAL SIGNED BY i N?,!,~.I!.,; n Commissioner Date//~-' ~'--8'~' .... r,'-m~ecl Copy SUBMIT IN TRIPLICATE 1Y-11 WORKOVER PROCEDURE SUMMARY: The 1Y-11 workover will be done to convert the well from a single completion water injector to a single selective water alternating gas (WAG) injector. The workover will require changing out the tubing string and upgrading the wellhead equipment from 3,000 psi to 5,000 psi working pressure. Prior 'to running the single selective completion a cement bo~n_~_r log will be run to evaluate the cement isolation between the "A" and "C" sands. If required a cement squeeze will be performed. 1Y-11 WORKOVER PROCEDURE 1. Move in and rig up Nordic 1. 2. Kill well with 11.2 ppg mud. 3. Nipple down tree and nipple up BOP. Test same. 4. Shear off of Camco OEJ. POOH and Lay down tubing. . Run in hole picking up 3-1/2" drill pipe and retrieve packer and tail assembly. 6. Rig up wireline and run CBL. . Perforate and squeeze as required to isolate "C" sand from "A" sand. Drill out squeeze . Run in hole with retrievable bridge plug. Change out well head equipment to 5,000 psi. Pull RBP and pull out of hole laying down drill pipe. 9. Run 3-1/2" single selective completion assembly. 10. Nipple down BOP and install 5,000 psi tree. 11. Displace out annulus with diesel. 12. Secure well and release rig. 5000 PSI BOP ST CK I I 5 I I . . . . 10. KRU 1Y-11 1. 9 5/8" CASING HEAD 11" -3000 PSI FLANGE 2. 11" - 3000 PSI X 7 1/6" - 3000 PSI TUBING HEAD 3. 7 1/6" - 3000 PSI X 11" - 5000 PSI CROSS-OVER AND SPOOL. 4. 11" -5000 PSI BLIND RAMS 5. 11" -5000 PSI PIPE RAMS 6. 11" -5000 PSI ANNULAR 11. 12. 13. 14. 15. ACCUMULATOR CAPACITY TEST 1 · CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH BRINE. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 'OPEN PIPE RAMS. BACKOFF RUNNING JOINT AND PUll OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF BRINE AND ALL VALVES ARE SET IN THE DRILLING POSITION. TEST STANDPIPE VALVES TO 3000 PSI. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLEI'E BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. NORDIC SRE 9/89 KUPARUK WELL 1Y-11 - APl #: 500292092600 SPUD DATE: 03/07/83 ADL LEASE: 25646 PERMIT #: COMPLETION DATE: 03/23/83 WORKOVER DATE: 83-41 ORIGINAL RKB: SURFACE LOCATION: 568-FNL,1132-FWL,SEC1 ,T11 N,R9E TOP OF KUPARUK: 1397-FNL,1285-FEL,SEC2,T11N,R9E TD LOCATION: 1495-FNL,1735-FEL,SEC2,T11 N,R9E All depths are MD-RKB to top of equipment unless otherwise noted 96 TUBING SPOOL: 26.3 PAD ELEVATION: CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16" 65# H-40 110 9.625" 40# J-55 2218 7" 26# J-55 7669 3.5" 9.3~ J-55 BTC 6743 SIZE LINER DETAILS WEIGHT GRADE TOP BTM TUBING JEWELRY TYPE ID DEPTH CAMCOTRDP 2.812" 1898 CAMCO OEJ 6689 CAMCO HRP 6712 CAMCO 'D' NIPPLE 2.75' 6730 VANN 6742 MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 2330 MAX HOLE ANGLE: 43.5 deg 4049 HOLE ANGLETHRU KUP: 32 deg LAST TAG DATE: 5/13/89 7189 RATHOLE: 81 ft FIS H/OBSTR UCTION: 7219 VANN GUN 367.74'LONG PBTD: 7588 PBTDSS: 6506 WELLTYPE: ITEM Sssv SBR PKR NOGO SHROUT STN DEPTH MANDREL 1 2001 CAMCO KBUG 2 3716 CAMCO KBUG 3 5182 CAMCO KBUG ~ 4 6108 CAMCO KBUG 5 6642 CAMCO KBUG .-.-.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:-:.:.:-:-:-:.:-:-:.:-.-:-:- ==================================================================== :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 66 GAS LIFT and FLOW INFORMATION VALVE PERFORATION DATA SIZE 1.o" 1.o" 1.o" INTERVAL ZONE FT SPF PHASE 6819-6914 c 95 12 120 6921-6927 ' B 6 12 120 7033-7038 A5 5 12 120 7046-7064 A4 18 12 120 7078-7108 A3 30 12 120 REVISION DATE: 9/11/89 REASON: UPDATE PORT SIZE DUMMY DUMMY DUMMY DUMMY DUMMY COMMENTS TO: THRU: _ MORANDUM State of Alaska ALASKA OIL ~2{D GAS CONSERVATION CO~\."lI SS IO~.] Lonnie C. smi t- :--:- DATE: June 23, 1989 Co,mi s s i oner FILE NO: D. [tRtl. 045 TELEPHONE NO: Michael T, Minder ~.~.,~, SUBJECT: Sr. Petroleum Engineer Mech Integrity Test AAI KRU CPF-1 Kuparuk Rv Field FROM: Harold R. Hawkins Petroleum Inspector Thursday, June 15, 1989, I witnessed two Mech Integrity Tests, AAI KRU ~P~ZIY-9 and 1Y-11. There were no failures. They were tested correctly in accordance with ACX~CC re~lations 20 AAC 25.412, and Area Injection Order #2. I filled out an AOGCC Field report which is attached. In sun,mary, I witnessed the Mech Integrity tests on two wells, AAI KRU CPF-1Y-9 and 1Y-11. The tests were satisfactorily performed. Both wells passed. Attachment ALASKA OIL AND GAS CONSERVATION C(]vNISSION MECHANICAL IbrlY_LT, ITY %]~ST Company: /~ A ! Field: ...... rg~rEgr STAra~"'15 ~P *I TYPE OF PKR CASING TBG REQ 'TBG Tlbm TIbm W~.I, *S --- ANNIR.US ~%rD SIZE/WT/GRADE SIZE TEST CSG TBG TBG lI~ CCb~ENTS *~ *N E33~D ~m rr, ESS PRESS CSO CSO CSO PRESS PRESS . PRESS ....... . ...., ........ %.~.o 2,?0 .&~'° ./fFP 7'5~a~q ' ?~o~ .. ~, I , , il , , i Il , , ,, ,,,, ! I I I I -- i i i i i i i i i i i ii1! i i , i i i iii ii , , , , , i , , , , J , , · ii i i i ii ! i i i i i i it ~ i i I I I I , i i i i i i i i i iiii i i I i .. ~! ! · , ~ , , , ii i I ! II I I II i ii .f *TUBING tlIIE~I~ FLUID.. P .' PRODUCE WAIER INJ S - SALT WATER INJ M - MISCIBLE INJECI'ION I - INJECTING N - NOT INJECTING A~~ FLUID: DIESEL GLYCOL SALT IqATER DRILLING MUD UIIlER AOGCC WITNESS SIGNATURE CC~W~ REP SIGNAIURE 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 25.252(d) AL,, ,A OILAND GAS CONSERVATION COMMI, .ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X.~ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. ©. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FNL, 1285' FEL, Sec. 2, T11N, R9E, UM At effective depth 1482' FNL, 1670' FEL, Sec. 2, T11N, R9E, UM At total depth 1495' FNL, 1735' FEL, Sec. 2, T11N, R9E, UM RKB 96 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1Y-11 9. Permit number 83-41 10. APl number 50-029-20926 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical 7725' 6723' Effective depth: measured 7588' true vertical 6 6 0 2' Casing Length Size Structural Conductor 47' 1 6" Surface 21 92' 9 5/8" Intermediate Production 7 6 4 3' 7" Liner Perforation depth: measured 6819'-6914', 7033'-7038', 7046'-7064', true vertical 5942'-6022', 6027'-6033', 6123'-6127', Tubing (size, grade, and measured depth 3 1/2", J-55, tbg w/tail @ 6741' Packers and SSSV (type and measured depth) feet Plugs (measured) feet None R£CEI.VED tV,P~r',, d: ', feet Junk (measured) feet None ~J&'$~(a .0ii & Gas Cons. ' .... 'ch0r Cemented Measured dopth" ~o vo~al dopth 300 Sx AS II 73' 1000SxAS III & 2218' 250 Sx Top job w/AS 1 980 Sx Class G & 7 6 6 9' 250 Sx AS I 73' 2218' 6673' 7078'-7108' @ 12 SPF 6134'-6149', 6161'-6187' @ 12 SPF Camco HRP-1-SP pkr @ 6709' & TRDP SSSV @ 1895' 13. Attachments Description summary of proposal X Convert oil producer to water iniection. Detailed operation program BOP sketch 14. Estimated date for commencing operation April 1 989 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ ~ FOR ~MI~ USE ONLY 9 Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test_ Mechanical Integrity Test '~ Approved by the order of the Commission Form 10-403 Rev 06/15/88 Location clearance Subsequent form ORIGINAL SIGNED BY LO.NME C. $~./t!TH IApproval No.¢ ...- ~:~ _ require 10- ~ Comm,ss,oner '~ ~- ~'~a~e- SUBMIT IN TRIPLICATE Well 1Y-11 Conversion to Water Injection . Wireline BOPE will be used in conversion of the well to water injection service. . The static bottomhole reservoir pressure is estimated to be 3500 psi based on recent measurements in offset wells. 3. No workover fluid will be used. 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANOE 2. 5000 PSI WlRELINE RAMS (VARIABLE SIZE) ,3. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4 1/6" FLOW TUBE PACK-OFF '! , I I I I I ~, I N I REL I NE BOP EGU I PNENT ARCO Alaska, In, Post Office uox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: September 15, 1987 Transmittal #:6054 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3C-16 Kuparuk River Unit 'A' Sand 100598H 8-26 thru30-87 2Z-1 Kuparuk River Unit 'A' Sand 100557H 8-31 thrug-2-87 3Q-2 Kuparuk River Unit PBU 100559H 8-25 thruS-29-87 3M-12 Kuparuk Well Pressure Report(Otis) Static A Sand 9-3-87 3M-13 Kuparuk Well Pressure Report(Otis) Static A Sand 8-28-87 3M-14 Kuparuk Well'Pressure Report(Otis) Static A Sand 9-1-87 1Y-14 Kuparuk Well Pressure Report(Camco) C Sand 8-23-87 1Y-6 Kuparuk Well Pressure Report(Otis) 8-21-87 1Y-5 Kuparuk Well Pressure Report(Otis) Static C Sand 8-23-87 1Y-16 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-11 Kuparuk Well Pressure Report (Otis) Static 8-21-87 1Y-9 Kuparuk Well Pressure Report (Otis) 8-21-87 1Y-3 Kuparuk Well Pressure Report (Otis) Static C Sand 8-22-87 2X-14 Kuparuk Well Pressure Report (Otis) Static C Sand 7-18-87 2Z-! Kuparuk Well Pressure Report (Otis) Static C Sand 7-2-87 2X-lO Kuparuk Well Pressure Report (Otis) C Sand 7-19-87 Receipt ~cknowledged: DISTRIBUTION: 0il & Gas Cons. Commission Anchorage D&M .-~"State"of-Alaska BPAE Chevron Mobil ARCO Alaska, Inc. ts a Subsidiary of AtlanticRichlleldCompany Unocal STATE OF ALASKA ~-'--. ALAS~... OIL AND GAS CONSERVATION COMM..,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension ~ Change approved program ~ Plugging [] Stimulate ~ Pull tubing~Amend order ~ Perforate~ther,~ 'k~----~ -( - 5. Datum elevation(DF or KB) RKD ~6' 6. Uniter Property name Kuparuk River Unit 2. Name of Operator ARCO Alaska~ Inc. 3. Address P. 0. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UM At top of productive interval 1397' FNL, 1285' FEL, Sec. 2, T11N, RgE, UM At effective depth 1482' FNL, 1670' FEL, Sec. 2, T11N, RgE, UM At total depth 1495' FNL, 1735' FEL, Sec. 2, TllN~ RgE~ UM 11. Present well condition summary Total depth: measured 7725 ' MD feet true vertical 6723 ' TVD feet Effective depth: measured 7588 ' MD feet true vertical feet 6602 ' TVD Casing Length Size 7. Well number 1Y-11 8. Permit number 83 -41 9. APl number 50_029-20926 10. Pool Kuparuk River Oil Pool Plugs (measured) None Junk (measured) None Cemented Measured depth True Vertical depth Conductor 73' 16" 300 sx AS i I Surface 2218' 9-5/8" 1000 sx AS III & 250 sx AS I Production 7669' 7" 980 sx Class G & 250 sx AS I Perforation depth: measured 6819'-6914', 6921'-6927', 7033'-7038', 7046'-7064' true vertical 5942'-5938', 6027'-6033', 61 23'-6127', 6134'-6149' Tubing (size, grade and measured depth) 3-1/2", 9.2#, J-55, BTC (~ 6741' Packers and SSSV (type and measured depth) CAMCO HRP-1-SP ¢ 670g,_ C. AMC_g TRr~p ~;~_q~_/ r~ !895' 12.Attachments DescriptiOn summary of proposal'!-I Detailed operations program 13. Estimated date for commencing operation April 20, 1987 73'MD 73'TVD 2218'MD 2218'TVD 7669'MD 6673'TVD Date approved 14. If proposal was verbally approved Name of approver Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I ,. ~ ..~'.--' ~~ Commissioner ~,- BOP sketch ,~_..~- 15. I hereby ce, i;tify that the foregoing is true and correct to the best of my knowledge Signed ~a~ (~gtj~ ? ..¢_'~~..¢ Title Associate Engineer / Commission Use Only (JLQ) SA2/31 Approved by :" :"" :':':~ :'-. ¢~:?;-'.ct Form 10-403 Rev 12-1-85 Date by order of the commission Date feet Submit in triplicate Kuparuk Well iY-11 Conversion to Selective Single Preliminary Procedure 1. RU wireline. Obtain BHP. 2. Move in and rig up workover rig. Kill well. 3. Nipple down tree. Nipple up and test BOPE. 4. Shear out of SBR. POOH and stand tubing in derrick. Install A/B modified couplings. 5. Pick up 3½" drill pipe and retrieve the packer. POOH. 6. RU wireline. Run CET. 7. Perform cement squeeze as necessary. (Use BP and retainer). 8. RIH and set retrievable bridge plug. Install 5000 psi wellhead and test casing. Retrieve bridge plug. 9. RIH with bit. Drill out retainer & cement to BP. 10. POH. PU RTTS. RIH & test squeeze perfs. POH. 11. RIH with bit. Drill out BP. 12. Make casing scraper run and filter brine. 13. Rerun CET. Reperforate 'C' sand as necessary. 14. Run GR/JB to PBTD. RIH and set permanent packer between "A" and "C" Sands. 15. Run 3½" single selective completion assembly. 16. ND BOPE. NU tree and test. 17. Displace well to diesel by reverse circulation. 18. Test annulus and tubing to 2500 psi. . Bottom Hole Pressure: 2900 Antici_ated Workover Fluid: NaCl/NaBr Brine YP~/1Y-1 lc ,, - p ANNULAR PREVENTER § PIPE RAMS 4 BLIND RAMS TUBIN6 HEAl) 2 1. 16" CONDUCTOR SWAGED TO 9-5/8" 2. 11"-3000 PSt STARTING HEAD :3. 11 "-3000 PSI X 7-1/16"-5000 PSI TUBING HEAD 4. 7-1/16" - 5000 PSI PIPE RAMS 5. 7-1/16" - 5000 PSI BLIND RAMS 6. 7-1/16" - 5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2.ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARC.T~!C:~,IE~E~ 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. 4. TEST ALL C~PONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSi AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD F~ 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTPEA~ OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND WITH ZERO PSI DOWNSTREAm. BLEED SYSTE~ TO ZERO PSI. 9. OPEN PIPE RAHS. BACKOFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAHS AND TEST ~0 3000 PSI FOR 10 ~INUTES. BLEED TO ZERO PS1. 10. OPEN BLIND RAHS AND RECOVER TEST PLUG. r'IAKE SURE ~ANIFOLD AND LINES A~E FULL OF ARCTIC DIESEL AND ALL VALVES A~E SET IN THE DRILLING POSITION. 11. TESTSTANDPlPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOO~EY PUMP. t3. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FOR~. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BORE DAILY. dULY 28, 1986 ( klC~f'~r~lC~ I~IC~- (~__~' /~"~ ATTACHMENT II Dri 11 Si te lA Wel 1 No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-12 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Lo9' Date Drill Site Well No. Lo9 Date, 7/6/83 10/29/83 2/8/82 5/7/82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/82 6/8/82 18 18-1 12/26/81 18-2 6/25/81 18-3 11/16-18/81 3/12/82 18-6 11/18/81 9/10/82 18-7 11/23/81 18-8 12/28/81 8/4/82 18-9 6/24/82 8/3/84 Drill Site lC Well No. 1C-1 1C-2 1C-3 1C-4 1C-5 1C-6 1C-7 1C-8 ' -. Lo9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 10 1D-1 ~ 1/80 5/23183 10-3 815/80 10-4 7/30~80 8/13/80 1D-5 6111181 1D-6 6/9/81 1D-7 6/8/81 D-S (WS-8) 5110178 Alaska Oil & Gas ¢o:,~. ........ Attachment ~-~"~, Page 2 Drill Site Well No. Log Date 1H 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Lo9 Date lQ ~1q?~~12/1/85~' Drill Site Well No. Lo9 Date 1E 1E-lA 8/19/81 1E-2 8/17/81 1/17/84 1E-3 10/18/81 11/7/81 1E-4 8/4/80 9/2/81 11/5/81 1E-5 10/27/81 1E-6 10/21/81 11/12/82 10/28/81 1E-8 8/28/81 11/1/81 1E-12 11/28/84 1E-15 8/26/82 1E-16 8/29/82 1E-17 9/1/82 1E-20 5/7/83 1E-24 2/17/83 1E-25 1/17/83 1E-26 1/13/83 1E-27 10/31/82 1E-28 10/27/82 6/13/83 1E-29 10/18/82 7/18/83 1E-30 10/16/82 Dri 11 Si te 16 Well No. Lo9 Date 16-1 16-2 16-3 16-4 16-5 16-7 16-8 Drill Site Well No. .Lo9 Date 1F 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 3/12/83 Ata,sk~ Oil & Gas ~ons. Oommi::'- 1F-1 2/19/83 1F-2 2/3/83 1F-3 1/31/83 1F-4 5/29/83 1F-5 10/25/82 1F-6 10/28/82 1F-7 11/19/82 5/7/83 Attachment Page 3 Drill Site 1Y Well No. Lo? Date 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~~ 6 / ~ 8 / 8 3 1Y-4 7/2/83 IY-5 6/29/83 1Y-6 6/27/83 IY-8 6/22/83 !Y-9 6/20/83 ~_~ 5/10/83 ~.~. 11/21/83 '~~7/28/8~ !Y-!2 5/25/83 1Y-i3 5/27/83 IY-14 5/13/83 5/18/83 !Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site ~'ell No. Lo~ Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 ~ 2C, 16'-~_~7~ 12/11/85 Drill Site 2Z g~ell No. Lo9 Date ~ Z 1:-'~_. 7 / 10 / 83 ~~~/22/85 2Z-2 ~ 6/24/83 7/!9/83 2Z-3 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF-pg-0052 R' C "/ED '-Alaska Oil & Gas Cons,. 0o:.%~..:':. Page 3 · Dri 11 Si te 1Y Well No. Lo0 Date .10/21/83 'lY-2 '~6/10/83~ ",,,3/4/84./ -~' 1Y-3 ~' 6/18/83 '1Y-4 '~ 7/2/83 _~,~~~1Y-5 ~'~6/29/83 Y-6 ~6/27/83 Y-8 ~6/22/83 1Y-9 "6/20/83 ~1Y-11 '~5/10/83'~ ~11/21/83/ 1Y-12 %5/25/83 1Y-13 ',~5/27/83 ~1Y-14 '~5/13/83~ '~5/18/83 / ~1Y-15 ' '~5/29/83 ~ 1Y-16 '~'5/30/83'-- "~10/23/83 '"., Yin! ey Drill Site Well No. Log Date 2Z "2Z-1 ~2Z-2 '"-zz-3 '~2Z-4 ~2Z-6 '~J2Z-8 7/10/83 6/24/83xx. 7/19/83/ 8/5/83 7/12/83 7/27/83 7/28/83 8/3/83 Drill Site Well No. Log. Date 2C --- 2C-4 "'"2/19/85 ~ 2/28/85~' ~' 2C-7 ~10/15/84 VLF:pg'O029 RECEIVED FEB 2 1 19B~ Alaska' 011 & Oas Corm. Anchorage ARCO Alaska,~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TRANSMITTAL NO: 5296 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETU~q ONE SIGNED COPY OF THIS TRANSMITTAL. SEQUENCE OF PRESSURE DATA EVENTS FROM WELL SERVICE REPORTS "~1C-4 '- 07-23-85 STATIC BHP CAMCO '-~ 1C-5 ' 07-29-85 PBU DRESSER ATLAS '~ 1C-5 t? 07-30-85 PSU DRESSER ATLAS '~iC- 6~ 07-25-85 STATIC BHP CAMCO "'-1C-6 ~' 07-24-85 STATIC BHP CAHCO '-~lD-8-" 07-30-85 STATIC BHP CAMCO -"lH-3r 07-3 0-8 5 STATIC BHP CAMCO ----1R-5 07-05-85 DHP & MISC. CAMCO --'-iH-6' 07-06-85 BHP & MISC, CAMCO -"'lR-8 07-~8-85 STATIC BHP & [,~I$C. CAMCO 1Y-10- 07-27-85 STATIC BHP CAMCO '~iY-11~ 07-28-85 END OF PBU DRESSER ATLAS 2A-2 .~ 07-04-85 'C' SAND STATIC BHP OTIS 2S-13~' 07-30-85 PKESSUkE DATA OTIS -'- 2U-14~ 06-30-85 'A' SAND PBU OTIS 2U-14~ 07-01-85 'A' SAND PBU OTIS 2U-15 07-08-85 PRESSURE TEST & MISC. OTIS 2V-2 07-27-85 'A' SAND PBU OTIS 2V--2~ 07-28-85 'A' SAND PBU OTIS ~2W-7-~ 07-26-85 'A' SAND ONLY PBU OTIS '~2W-7-' 07-27-85 'A' SAND PBU OTIS 2X-15' 07-09-85 FLO%~ING BHP & FLUID I.D. OTIS 2X-15-'' 07-U4-85 FL~)WING BHP & TEMPERATURE OTIS 2Z-l' 07-05-85 BHP SURVEY & MISC. OTIS ~- 2Z-6- U4-08-85 STATIC BHP CAMCO ~3B-7~ 06-27-85 STATIC BHP & MISC. CAMCO 3B-8~ 06-28-85 STATIC BHP & MISC. OTIS 3B-8-~ 06-27-85 BHP & MISC. CAMCO -~3B-9/' 07-18-85 STATIC BHP & HISC. CAMCO 3B-11 07-20-85 BHP SURVEY & MISC. CAMCO 3B-12~' 07-21-85 STATIC BHP & MISC. CAHCO RECEIPT ACKNO~L~.DGED: DISTRIBUTION: ~?A~* DKILGING W. PASHER STATE OF B. CURRIER. L. JOHNSTON EXXON SOHIO* CHEVRON* HOBIL* PHILLIPS OIL* UNION* D & t~* NSK CLERK J. RATRMELL* - K.TULIN/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichlieldCompany ARCO Alaska, Post Offic _.. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. KU PAKU K OPERATIONs RECOKDS CLERK ATO-1tl5B P.O. BOX 100360 ANCHORAGE, AK 9951U DATE: 08-16-~5 TRANSMITTAL NO: 5267 ENGINEERING TRANSMITTED ~LECEIPT AND PRESSURE FINALS DRESSER ATLAS 1C-5 PBU ' IC-9 TUBING PRESSURE !G-15 FLOWING PRESSURE GRADIENT ~Y-tl FLOWING PRESSURE & PBU lA-1 P~U ' 2B-13 PBU !U-1 FLUWING BOTTOMHOLE PRESSURE HEREWITH ARE THE FOLLOWING ITemS. PLEASE ACKNO%~LEDGE KETUF~4 ONE SIGNED COPY OF THIS TRANSMITTAL. 07-29-85 07-24-85 07-30-85 07-28-85 08-3/4-85 0~-01-85 08-04-85 ~CEIPT ACKNO~LEDGED: -'AE* CURRIER & M* DRTLLING L. JOHNSTON · MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. t{A%'HMELL* · ~z~ & G~s Qms. Cc, mm~ssior~ S~A~ O~ A~AS~A* .'SOHIO* UNION* K.TULIN/VAULT ARCO Alaska, Inc.' Post Office Bo,. 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 R E 'f' U R i:,! T 0 · · r F:.: A; .... , ,,. H I 'f"l- I':: Iii: C Iii; I I::' T Al4 f) F:' F:: IE.7.'...." U 1:;,' Iii: I:;: Ii!; F:' ORT;?;" (ONIE COI:"Y OF' IZACH) TURN CA,NCO t 1::' -.- t,_ ':) ~ I::' B U I:,: I;."1F" 0 I';.: 'f' () 4 .... I '1 -"..'::.'" 'i (~ .... '1 ;-2 ''/' F' B t.l I::: li~. F' 0 F;.: T' (') ~ .... 'i ;3 "' 8 !5 i Y-' i 'lj [:' Ii: t.J R F:: F:' 0 1'4 T 0 -4 ---,.,(') .... 'i -- ( !f:~;,... 2 A--' t :~'1' A'F 217 ("7. ~ F;,' A D 1 1:5 i',! T F;-: F' T '.":) ~ -- ,='. ,3 -' t :.:2 '1' I!i; T I-1 ]Z 5; F:'A I ;," 'i ;1: C lJ I... A I:;-.' O 'q' -- O 9 '"' ii,) 25 (:" 4-- i C' -' 8.q: ('.') 3 .... f t -" 8 15 A I.. [_ 0 F:' I':' ""._-" -"! -' ('.:' 7 -',(ii !S (i:. 4 .... "~ 9.--8 !5, O4---t 8-...8':'.'; (:.4 .... t i .... 8:5 TH :1. i',i . ) ARCO Alaska, In/'-``` Post Offi¢ ,.~x 100360 Anchorage, Aiaska 99510-0360 Telephone 907 276 1215 RETURN TO- TIR "' "' ,..,, i,.,,_, ,, I TTED RECEIF'T AND 2F--9 ~.r:_7 ARCO ALA,~t<A, INC ATTN' RECORD.? CLFZRK ATC)-ti iSB F'. O. BOX t ANr'HORAGE,.. , AK 9 I.-IFI-'::r. rI.,.IZTI.-I "'~ .......... F~ F.,:. THE RETURN ONE ;~'.I.r;-NED FBI..LOWING DATE' AF'RIL t 9, I98.....,"~' TRAN.?MITTAL NO' 5t 4'7. PAGE t, OF' '"2' I I'IEMZ¢, F'!._,:EA,.?E ACK NOW[..EDGE COPY OF THI,~' TRANSMITTAL. EVENT,S' · 'A' SAND FRAE-GELLED WATEB ;'. TATI C B!.-IP F'BU - F'BU ,-,T.,ll I*' F~ ... F'BU PBU GELLED WATEF..' FRAE HYDRAULIC FRA6 POST FRAE TEHF" LO~,.., F'BU F'BU .2TATIC BI-IF' . F'BU F'BU GELLED WATER BATCH FRAC F'O,~T FRAC TEHF' LOG YTATIC BHF' STATIC BHP INJECTIVITY TE~T I$IP STATIC BI"IP BHF' BHP BHF' F'BU F'O£T FRAC TEHF' LOG BHF' · POYT FRAE TEMP LOG .HYD,. FRACTURE F'BU F'BU · 4/3/8~ 413185 4/2/8~ o~ 4/t -2/85 5/-5f/85 3/3t/85 4/t/85 4/I/85. 4/2/85 4/9- f ¢/85 4/7-8/85 4/8/85 4/t i-t 3/85 4/t t t 2/85 41t 2/85 4/f2/85 4/t3/85 4/t3/85 4/t3/85 4/t t/85 4/f 2/85 4/t..~/8~_. 4/t.-~/85 ' 4/t0--t t/8_5 41t 4-t 5185 4/t 4/85 4/t5/8-5 4/t -5/8-5 4/t 3-t 4/85 4/t 4-t~/85 RECEIF'T ACK.HOWLED6ED ' DISTRIBUTION: E,F f-,E DRILLING W FA~FIER B., C~JRRIER L, ,.JOHNSTON EXXON CHEVRON HOBIL PI4ILLIF'Y OIL 0 & H N~K CLERK J. RAI'HMELL ARCO Alaska, Inc. ii a Subsidiary of AtlanticRichfieldCompany RECEivED APR 2 5 ]985 Alaska Oil &.,.Gas Cons...~m,~ssion D ATE' -~'~;~.T~ ' ~.ATE_ OF A~A~ ~'Ol"llO UNION K ,~UL I N/VAUL. T KUPARUK EHGINEERING TRANSMITTAL .='.'.~<2~,' TO- ~:Z'c_~c~_~ FROM: Transmitted herewith are the following' WELL NAME- D. Fay Allison PLEASE NOTE' BL - BLUELINE, S SEPIA, F - FILM, T TAPE, PHOTOCOPY //IPT ACKNOWLEDGED: DATE' PLEASE RETURN RECEIPT T.O' ARCO ALASKA, IHC. AICpa'Oil &A~chen~oGas Cons. ATTN' D. FAY ALLISON -- ATO/l115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 January 17, 1984 Chat Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Dear Chat' Commission Attached in duplicate following wells at the are subsequent notices on the Kuparuk River Field' Well Action Date Performed 1F-9 Perforation 11/30/83 1Y-11 Stimulation 11/14/83 1Y-14 Production/Injectivity Test 5/24/83 SWPT 01 Mud acid wash 11/22/83 SWPT 01 Water Injection see attached 2X-1 Perforation 12/9/83 2X-2 Perforation 12/10/83 2X-3 Perforation 12/11/83 2X-5 Perforation 12/12/83 2X-6 Perforation 12/13/83 2X-7 Perforation 12/14/83 If you have any questions, please call me at 263-4527. Charles K. House Kuparuk Operations Coordinator CKH/kmc Attachment (Duplicate) ARCO Alaska. Inc. is a subsidiary of A!lanlicRichfieldCornp~.ny STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ 2. Name of Operator 7. Permit No. ARCO ALASKA, INCo 83-41 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50- 029-20926 9. Unit or Lease Name OTHER [] 4. Location of Well SURFACE LOCATION' TllN, RgE, UH 568' FNL, 1132' FWL, SEC. 1, BOTTOM HOLE LocATION. 1495' SEC. 2, T11N, RgE, UM 5. Elevation in feet (indicate KB, DF, etc.) FEL, 1735' FEL, q6 ' CRKB) 12. KUPARUK RIVER UNIT 10. Well Number 1Y-11 11. Field and Pool KUPARUK RIVER FIELD I 6. Lease Designation and Serial No. KUPARUK RIVER OIL ADL 25646. ALK 2";77 POOl chec~ ~,ppropriate Box To Indicate NatL~re of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit iQ Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~] Abandonment [] Repair Welt [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertiner~ details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105o170). · Stimulated on 11-14-83 with 12% HCL through lines and BOP's were pressure tested to 4000 pressure was 3400 psig, and maximum wellhead acid rate was 2,818 BOPD. Pre-acid rate was coiled tubing. Al/ surface psig. Maximum coiled tubing pressure was 800 psig. Post 1,873 BOPD. ,JAN, 8 ~.~84 Alaska 0il & Gas Cons. C0mmissJ01~ Ansh0rauo 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~ ~~ Title~U~ARU~ The space below for Commission use OPERAT IONS COORD I NATOR Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-11 Dear Mr. Chatterton. Enclosed is a Subsequent Sundry Report you have any questions, please call me Sincerely, Gruber Associate Engineer JG/GRU5L23'tw Enclosure for the subject at 263-4944. well. If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ?--. STATE OF ALASKA ---. . ALASKA L _ AND GAS CONSERVATION CO ~IlSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL i-1 COMPLETED WELL l~ :~. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-41 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20926 OTHER [] 4. Location of Well Surface: 568' FNL, 1132' FWL, Sec.1, T11N, RgE, UN 5. Elevation in feet (indicate KB, DF, etc.) 96' RKB, 67' Pad 12. I 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170).~, ~..}~'.,.~-~ .,t.~;.J~.lh,~ ~t~/~3 r~d " ! ,, Spudded well ~ 1200 hrs, 03/07183. D 12-1/4 hole to 2242 . Ran 1 jt 10-3/4 , 45.5#/ft, K-55, BTC csg to 73 and ran 9-5/8 , 40.O#/ft, J-55, BTC csg f/73 - 2218 . Cmtd with 1000 sx AS III & 250 sx AS I Drld 8-1/2" hole to 7398'; ran logs, & continued drilling 8-1/2" hole to TD. Ran & cmtd 7" csg. Ran 3-1/2" completion assembly. Secured well & released rig ~ 0200 hrs, 03/23/83. 14. I hereby ce~i~fy that the foregoing is true and correct to the best of my knowledge. Signed.Z',Zz"~//_,,//~, _ / Title Area Dri 11 ing Engineer Conditio/~s of Appr~,v~l, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 GRUS/SN02 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office B(,,, 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 November 4, 1983 Mr. C. V. Chatterton State of Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commission Dear Mr. Chatterton' Attached are notices of our intent to Wells 1Y-11 and West Sak SWPT No.1, If you have any questions, please call harles K. House uparuk Operations Coordinator CKH/kmc Attachment (In Triplicate) stimulate Kuparuk Unit and perforate well 1F-9. me at 263-4527. Alas'Ka Oi[ & Gas ~;on~. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany r STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL EX OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION' 568' FNL, 1132' FWL, T11N, R9E, UM SEC. BOTTOM HOLE LOCATION' 1495' FEL, 1735' FEL, SEC. 2, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 96' (RKB) I ADL 2.5646, ALK 2577 12. 7, Permit No. 83-41 8. APl Number 50- 029-20926 9. Unit or Lease Name KUPARUK RIVER 10. Well Number 1Y-11 11. Field and Pool KUPARUK KUPARUK POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data UNIT RIVER FIELD RIVER OIL NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate ~ Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] [] [] [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska production designs. efficiency any format completion is assumed wells in th , Inc. proposes that Kuparuk Well 1Y-11 be acidized to improve and provide information to optimize future acid stimulation An acid stimulation has the potential to increase flow from 33% to 70% (increase production to 4240 BOPD) by removing ion and wellbore damage caused during the drilling and of 1Y-11. An average post stimulation flow efficiency of 70% for 1Y-11 based on the post acid well test results of s~xl- e CPF-1 area. See attached detailed procedure. Expected start date' jl-~-~ Subseque~t Work lqeportecl Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~-~--41~ ~~ Title KUPARUK The space below for Commission use 0 P E RAT I ON S COORDINATOR Date Conditions of Approval, if any: Approved by Approved Copy Returned 7 - By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate !111111 SPUD DATE:'S-O7-&S COHPLETION DATE: SURFACE LOCATION: 56&-FNL,[1SI-FNL,SEC[,TlIN,RgE TOP OF KUPARUK: lS97-FNL,[I&S-FEL,SECI,T12N,RgE PBTD LOCATION: 1462-FNL,X670-FEL,SECZ,TX[N,RgE ELEVATIONS ABOVE SL: KB: 96 PAD: 66 REFERENCE DATUM: 'KB/BRADENNEAD: 29.95 ALL DEPTHS HD-RKB ZONE C4-CZ (UPPER) SAND: ZONE O[ (HIDDLE) SAND: 6&S& - 69[0 ZONE Aa-A! (LOWER) SAND: 702~ - 7[69 COHPLETZON (TBG TALLY DATED ~-[&-&$ ): _ __9-62S"___45-5~ K-SS a 221& W/12SOSX S.5" 9.2~ J-SS-BTC 2.~&7" DRIFT CAHCO__T~'DP SSSV 2.&12" . CAHCO__OEJ S~R ID CAHCO_N~P. ~ [/2w X 7w PKR CAHCO__D NO GO 2.75w ID VANN TBG RELEASE PACKER ~ 6712 CAHC0 OL HANDRELS 2.$75" -ID ~: 200~, ST[~,, 5162, 610&, 6642 TUBING TAIL a 6742 STIHLILATION: PERFD: 3-25-&2 ~ 6&[9-6914, 70~-703&, 7046-7064, 707&-TXO&, ~/[2 SPF, 60 PHA$[NG COMMENTS: VANN_GUH_FISH_~N~HOLE(~67.7-4-~ONO). TOP_OF_FISH@7219~. CSG_[O-S/4w_TO_7S~. PBTD 8 26~ K-SS 7669 W/X2~OSX REVISION NO: 0 DATE: Acid Stimulation Procedure Kuparuk Well 1Y-11 Rage 3 13. When clean oil is obtained, flow well to test facilities to establish rate. 14. Schedule PBU/DD test with production logs after seven days of continuous production. Acid Stimulation Procedure Kuparuk Well 1Y-11 Rage 2 Procedure 1. Obtain a pre-stimulation production test. 2. RU separator, cleanup tanks, anU associated flowlines. Filter water for acid make up. Collect water sample 4. Test an acid sample to confirm concentration. 5. RU CTU and pumpers. Pressure test pumps, lines and coiled tubing to 4000 psi. RIH with coiled tubing to 7130' MD (approximately 20' below bottom perforation) while circulating a minimum volume of diesel· Pull up 50' at each restriction to check drag. 7. With coiled tubing at 7130'MD choke well to minimize flow and spot 630 gallons (15 bbls). Do not bullhead acid· 8. Immediately after spotting acid, shut in the well and pull coiled tubing uphole to 6775' MD. 9. Acidize the well as follows: NOTE: Do not exceed 4000 psi pump pressure or 1450 psi WHTR. Monitor WHTR when BAF hits perforations. Quantity of diverter (BAF) to be adjusted as deter- mined by onsite engineer/Drill Site Supervisor. a · e · h · Pump 1000 gallons acid with 200# BAF Pump 1000 gallons acid with 100# BAF. Rump 772 gallons acid with 100# BAF. Rump 2000 gallons acid containing 400 SCF N2/42 gallon. Displace CTU with N2. Open well to tanks· Surge well for 20 minutes at 2000 SCF/min and SD for 10 minutes. Repeat g. 10. POOH with CT circulating a minimum amount of nitrogen· 11. RD CTU and pumping equipment. 12. Continue to flow well to tanks until fluid is compatible with the CPF. ACIp S, TIMULATION PROCEDURE KUPARUK WELL 1Y-11 Well Data All depths RKB (RKB=IO2'MSL, PAD EL:66'MSL) SSSV (ID=2.812") GLMs (ID=2.875") Packer No Go (ID=2.75") Tubing Tail Perforations (Vann Gun, 12 SPF) PBTD Expected top of Vann Fish Hole Angle at Perfs Hax Hole Angle 1898' MD 2001, 3716', 5182', 6108', 6642' 6712' 6730 ' 6742' 681 9-6914', 6921 -6927', 7033-7038', 7046-7064' , 7078-7108' 7588 ' 7220' 32° 43.3° at 3700' Summary of Work The A and C Sands are to be acidized with 12% HC1 acid and BAF (benzoic acid flakes - for diversion) using a CTU. The final 20.00 gallons of the treatment will be energized with nitrogen to enhance cleanup. A post stimulation PBU/DD test with production logs will be run after one weeks continuous production. Fluid Requirements 12% HC1 Nitrogen Diesel Benzoic Acid Flakes 6032 gallons 1400 gallons 4000 gallons 400# NOTE: Filter water prior to make-up of acid formula. Collect water sample. All acid is to contain: ~50#/gal L-41 (iron sequesting agent) 0.1% F-75N (surfactant) 0.5% A-250 (inhibitor .2% W-35 (anti-sludge additive) .2% L-53-W (clay stabilizer) NOTE: Under no circumstances include "MSR" type additives. K!JP/-,;~JK I~GINEERI ~Ei 'I~ANS~41TTAL \,~JELL N,~'E: D. \¥. Bose/Shelby J. tCetthews Transmitted herewith are the followi~j- PLEASE hDTE: BI'_ - BLUEL! NE, S - SEP IA, F- Fl Uvl, T- TAPE,~.'~PY~ IFF AC_XNO,'.~3)SED: PLEASE P~-TUI~'4 RECEi PT TO- /~,~30 ALASKA, INC. ATTN: DUlEIJgY J. MA-I-I¥1B.':.G - ATO/111 5-B P. O. BOX 100360 ANt3~?vNSE, Al(. 99510 / KUP~K Eh~ I NEERI TO: William VanAien ~: D.W. Bose/Shelby J. Matthews Transmitted herewith are the followincj- PLEASE FDTE: ~__~ S .- SEP ! A, F - F i ~4, T - TAPE, RECEIPT ~~/I_EDGED: PLEASE RETUP~I RECEIPT TO: k~ ALASKA, ! N~.. A-i-[lq. SHELBY J. IVATTH~/S - ATO/1115-B P. O. BOX 100360 ~qCHGPvN:SE, AK. 99510 ARCO Alaska, Inc. Post Office Bo× 360 Anchors_ge, Aiaska 99510 Telephone 907 277 5637 Hay 23, 1983 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1Y-11 Well Completion Report Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for 1Y-11. If you have any questions, please call Jo Ann Gruber at 263-4944. Sincerely, P. A. VanDusen District Drilling Engineer PAV/JG3L12'sm Enclosures MAY 1. 83§ Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany " ~-'-: STATE OF ALASKA '-':~" 0 R 16 IN A [ ALASKA:~¢,'L AND GAS CONSERVATION C(...,;MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well oILXJ~] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 83-41 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20926 4. Location of well at surface 9. Unit or Lease Name 568' FNL, 1132' FWL, Sec. 1, TllN, R9E, UM ~Ti~i~ Kuparuk River Unit At TopProducinglnterval i ~/~?,iFiED"/ l'0. WellNumber 1397' FNL, 1285' FEE, Sec. 2, T11N, RgE, UM I,~urf,_~.~! 1Y-11 AtTotal Depth J~.~. ~- ~-~ 11. Field and Pool 1495' FNL, 1735' FEL, Sec. 2, TllN, 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 96' RKBJADL 25646 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore116.No. of Completions 03/07/83 03/14/83 03/23/83 N/A feet MS LI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+l-VD) 19. DirectionaISurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 7725'MD,6723'TVD 7588'MD,6602'TVD YES~ NO []I 1902 feet MDI 1350' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/FDC/CNL/GR/SP/CAL, GR/CBL, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 73' 24" 300 sx AS II 10-3/4" 45.5# K-55 36' 73' 12-1/4"~1000 sx AS III & 250 sx AS I 9-5/8" 40.0# J-55 73' 2218' 12-1/4" 7" 26.0# J-55 Surf 7669' 8-1/2" 980 sx Class G & 250 sx A,~ 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) 6819' -6914 ' 3-1/2" 6741 ' 6709' 6921 ' -6927 ' 7033'-7038' 12 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 7046' -7064' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7078'-7108' 6988'-6990' 250 SX Class G 6760'-6762' 250 sx Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test- Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I Flow Tubing Casing Pressure CALCULATED -~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) , press- 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None . Form 10-407 Submit in duplicate Rev. 7-1-80 ¥' CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS 30. FORMATION TESTS NAME Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand 691 O' 702,~' 7169' MEAS. DEPTH TRUE VERT. DEPTH 59~2' 6019' 6116' 6239' 31. LIST OF ATTACHMENTS Drilling History, Gyroscopic Survey (2 copies) 32. Include interval tested, pressure data. all fluids recovered and gravity, (~OR, and time of each phase N/A I hereby certify that the foregoing is true and correct to the best of my knowledge Signe ~- _ Title Area Dri i 1 ~ r,g Engr. Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". TEST TYPE: _ ~,~'J,=:~'~ ) WELL TYPE: Old' PRODUCTION (INDECTIDN) '[EST DATA TEST SUMMARY , o. YELL: ,]z~/_ I I Producer Injector PERFORATIONS: TEST SUMMARY PRE-TEST (If well is currently fl~, AVG PROD (IN3) RATE AVG GOR , ~""~OR WHP ~,,-'P'-S I ° AP I WHP _ °F CH~ / 6A DATE ~BDPD · e 60 ACTUAL TEST DATA AVG PROD (.IN3) RATE /'~8OPD AVG GOR . A Y G.,,,W~R WHP ' PSI/'~'"'" "API" - ~' 60 WHP '~ CHOKE ~ /64 / - HP ~ FI HP O SS TD~/~L PROD (INJ) TIME /TALSHUT IN TIME FT HR' HR HA3OR WELL EVENT HISTORY DATE START END EVENT .o CUMULATIVE PRODUCTION (IN3ECTION): . TOTAL PRODUCTION (INJECTION) TIME: TIME SINCE LAST HAOOR SHUT IN: KUPARUK RIVER UNIT SEQUENCE DF EVENTS DATE: · , .. 1000 /V~T_. P.u WlP. F_L.J~E. U~tT-. WE. LC I I O0 PP, F..SsU P_,.IT_. TE..ST LU~P-tCATOP. A., t~c)P TO NY b Co~Tp_,ot_. i_~ ~ E. 19__45 TAGGE. D ANib ST/kC'~,,T..ib OUT' Ol, A coGSX/ ~ l e~4Z.' WL/V~, PUM, PED TOP OF' VAL/N GU~ ~ 7'9 e~A. W L/v~, POIA. WELL i--t EA6 w / DUAL A/V~E_RJ~.~A l~,O/V~E,% , i+so g..J~ w/ ~AR. A/~tb DUAL TO ~30 WL/vk ~00 POFA, Fi/',,JAL.. WIAP' T'AK~t~ l kl L.U~CA.T-oIZ_ 'w'/A/V~P~AI3A.S I iG45 ~ EiEL. I~ tMTER, pP..P_.TATtoAJ Lu~>~c~,T'o~, ~,~J~ 8,50 ,- $ .g/o ,, -.. 1Y-11 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1200 hrs, 03/07/83. Drld 12-1/4" hole to 2242'. Ran 55 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2218'. Cmtd 9-5/8" csg w/lO00 sx AS II, 250 sx AS I. ND Hydril. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7398'. Ran logs DIL/SFL/FDC/CNL/GR/SP/Cal. Run #1 f/7262'-2218'. Run #2 f/7262'-2218' w/GR/BHC. Cont drlg 8-1/2" hole to 7725' TD. (03/14/83) Ran 195 jts 7", 26#/ft, J-55, BTC csg w/shoe @ 7669'. Cmtd 7" csg w/390 sx lead - 590 sx tail. NU BOPE tst to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus. Ran Gyro, ran CBL over Kuparuk f/6600' to 7300'. Ran 4" squeeze gun and shot from 6988'-6990.5' w/4 spf. Set cmt retainer @ 6950' and squeezed 250 sx Class "G" cmt. Ran 4" squeeze gun and shot 6760'-6762.5' w. 4 spf. Set cmt retainer @ 6720' and squeezed w/250 sx Class "G" cmt. Tst csg to 1500 psi - ok. Drl cmt to 6997' - all soft. -PBTD 7588'. Tst csg to 1500 psi - pressure bbl off. Pumped 100 sx Class "G" across squeeze perfs and drilled out - ok. Run GR/CBL. Run Geo Van guns. (Ran 213 jts of 3-1/2", 9.2 #/ft, J-55, BTC tbg.) Tbg tail @ 6741' top of fiSh @ 7219'. Tst SSSV to 5000 psi - ok. ND BOPE. NU tree & tst to 2500 psi - ok. Disp well to diesel. Set pkr. Fire guns. Dropped ball & sheared off guns. Close SSSV. Rig released at 0200 hrs, 03/23/83. HILL/DH4 MAY 2 ,s, i983 Al~tsk~ Oi! &- Gas Oons. 6omimssioD ¢IRt!.O IqL. ASKA, INC, GYROSCOPIC DIREC. TIOi,I¢4t. SURVEY RADIUS OF' CURVATURE t'tETHOD OF' COH?UTA]"]OH SURVEY RAH BY tJALTER/PERIRY C:Oi~IPUTED FOR'$Di BY OCE~NTEC:H(FI'~ LiNDSEY & :~qSSOC'., ) R E C: 0 R D () f::' S L,i R '¢ E Y TRUE I'iEAS, DR!FI" VERTICAL [; ...... ., ....... ~:: l:- T H ¢i H{':~ E D E P T FI I,') l"t · '.:'~ U B DR I FT SEA D I RE(.:: [:', E G. 0 0 200 0 29 3 00 0 220 400 0 20 ,500 0 26 600 0 22 ?' 0 O O i :3 '8'0 0 0 :-,00 O 8 1000 0 14 'i 00 2 O0 299 399 ,499 599.99 699 98 799 98 899 98 999 98 0 O 96 ,, O O .6' 0 4,00 N O0 I 0,t.., O0 H49,7;:2l.:;~ 99 203,99 H37, 99 ' 303,99 N2 1 , 0St,; 99 403,99 503,99 603,98 S',.I. 8,67k~ 703,98 S 2 80.3,90 S'I 0,7Oki 903 , 98 S24 · 62E ilO0 0 27 i099 98 i003,98 SiO,63E 1200 0 45 1199 98 1i03,98 SI8,52E I300 0 2.5 !I 299 97' 1203,97 " S 2:43(~I 140.0 0 3i i399 97 I303,97 S73,i2i.,.t 1500 0 31 1499,96 1403,96 S77,921~ 1600 ~.0 46 1599 96 I70.0 J 22 1699 1800 1 51 1799 1900 2 5 1899 2000 2 8 1999 21 O0 2 9 2099 2200 2 I 0 2199 23 0 0 .~ 25 '-"-"~'~ 94 1603,94 NJ 4,95~.t 90 170,3,90 NI7, 84 1.803,84 HI 9,65rd 77 '!90.3,77 N20,48t,~ 70 2003,70 NJ 9,07t,i 63 2~ 03,6.3 N22,:37B 55 2203,55 N24,82L, J T 0 T F'~ L. C: 00 P [': :[ f..I ~'~ T E S CLOSURES [::, I S "f: J:~ H iS E R H C L f::: D H ':2 54 N 36 '"? :3 ':>r~ N '""~ ....... :3 'F'S' N 40 'i'-3 'i.. ":' ,S 89 H ..., 56 N 58 '?' '.'.":::i 3 i:i N 65 '~2 34 '? 60 N 8~ ''.' ...... ..... b-.J.S 3 :':':~:.:"l'~ 3 i9 S 65 !':;i ';.:: 4 08 S 67 '="" q~'~ ..~ ,'",.. 4 9i S 76 22:32 "::",.., A'i i'l84 't:::;'i :,t.i. 9 ;3.~'1 N 49 lei (:, i.,) 'i:3 1S-, N 41 ~4 50 I.,, 16 7.3 I-,i 36 :!;3 2i ;2a 3:3 N S3 42 S.q i.,.~ :2 4. , .'5 :!i H 32 5 4'.!; b; ARCO kLPRRUk Y-il SEC . 1 , T'I It,t, RgE,UH ~ R 0 o L, 0 f:' ]' C.: S U R V E ¥ S Ut, I- R u E L, 0 {:': ~ T I 0 RECORD uF StL)R'~"'"'.;E~ HERS, DRIFT DEPTH ANGLE D H 24.00 4 13 25..0'0 8 2 2{6'00 12 lls 2F,O0 I~ 27 ~,0'0 2:0 29:-0'0 24 30 ~00'0 2~ 24 31 O0 3'0 46 3200 33 20 .3~0.0 35 4~ 3500 40 ~60~ 42 54 3?00 43 29 3800 ,13 24 39O0 43 23 4000 4100 43 25 4200 42 46 4300 42 27 4400 41 4500 42 46OO 4~ 13 47OO 41 4800 4'1'52 4900 41 5000 41 5100 40 53 TRUE VERTICRL. DEPTH 2399.38 2498,74 2597.09 2693,95 28el.21 2970..73 3057.,G9 3142,44 3224.82 3304,76 3381.97 3456.47 3529.38 3601.99 3674.65 3747.44 3820,21 3893.23 3966,83 4040.93 4115.28 4189.44 4263,70 4338,'16 44i2.84 4487.90 4563.32 SUB SEA '2303,3,8 2402,74 2501 ,.09 2597,95 2?85,21 2874.73 2961,69 ' .3046,44 ';3128,82 3200.76 32@5.97 ,3360,47 3433,38 3505,99 357~. 65 3651 . 44. 3724,21 3797,23 3870,8~ 3944,93 4019.2S 4 093,44 4167,70 4242,16 4316,84 4391,90 4467,32 DRIFT D1REC DEG, N76,32W $86,80i.O $79.78W $74 S7 O, 07W S69,58W STO,50W S67. i 7W S69 , 0 868.52W 868,87 I..~ S68.77[d S68.38t,) 868.1 7W S68, OSkl S68, OOt,) S67,93W S68..75(d S68, O 2 {,.I S68', 231J S68 25W 968 22rd S68 23t,J S68 32 l,.t S68 23W S68 S68 32W S6@ 48W TO'TAL COORDINATES 24,16 25, i,7 J',l 23, 06 N 17,58 t,i 8.01 N 5,15 $ 20, S :38, 78. 100,3: 123,3 147,61 173..00 S 198,62 S 224. ;30 S 250,03 $ 275 34 S 300 51 S 350 ~ S 375 453~,"' 400 31 S 425 I 0 S 449 8 J S 47'4 43 S 498 84 S ,.3 Ol S i7 28 46 100 I36 178 224 3 630 694 821 lOlO 07 :.-.,~ i1:34 i259 38'*,. 44.3 37 5i 7'2 i .00 136 179 227 '2. 7 335 395 592 66i "".' 29 9:34 i O 02 I 069 i 1 '1203 i40:3 i 469 i 5S5 68 N ;35:3 i 3i N 48 54 id 63 24 4. 42 N 75 57 67 i'q 85 26 2;;' $ 8,7 t. 9 5 ..~83 ~:::':"¢ 4 '>9 S 80 19 ::i¢;" 5,'. 78 i i 4::< S 76 .... '"" ()3 S. 75 J7' ':'22S 74 23 2 ,Si S 73 .:..~9 ?' SiS ?'~ i 5 ;32 '" 72 ::;i o 83 S 72 6 2.4 SS 71 4,q- .I- ¢2 S 71 '-"-" ,-... ~ J ...~ 94 S 71 I.:: ....... S 7'f 2 2 44. S 7 0 4 2 3 45 S 70 ;3,* 38 S 70 '-'"-:':.., OS S 70 2 0 2: .54 S 70 14 ,.., 58 S 70 9 '2 23 S 70 4 5; ' '' O ARCO KUPRRUK Y.-'ll SEC.,'I , TI 'i.N, Rg'E, · GYROSCOPIC SURVEY SURFACE LOCAT'ION © 568 '.F N L dOB iqO 1380 1132' FWL RECORO OF' SURVEY MEAS. DRIFT DEPTH ANGLE D' 52.o.0 40 28 :.,,,S30,o.. 40 .54 0,0:39' 44 5500 39 28 5600 ,30 56 5?:0.0 38 23 59.00 37 , 2~0 6.0 O0 3 61 08 '36 .5 6200 35 63.0..0 34 640:0 33 55 :65.00 32 66'0'.0 32 ! 6700 31 44 68:0,0 3! '59 69.0'0 32 29 7000 32 ! ? 72'00 31 15 73'00 30 17 74'0.0 29 23 750'0'28 46 7725 28 46 BOTTOM HOLE TRUE .VERTICAL DEPTH 4639..16 4715,38 4792 ..01 4869.06 4946,56 5024.64 5103.42 5182,75 52.62,56 5343.,03 5424,,'00 5505,81 5588.55 5671,99 5756,32 5841,24 5926,18 6,01 O. 77 6095,22 6265.,25 6351,18 6437.92 6525,32 6722,55 CLOSURE SUB SEA 4543, 16 4619.38 4696,01 4773,06 485 O, 56 4928.64 5 007.42 S 086.75 5166,56 S247.03 5328. '00 5409.81 5492.55 5575.99 5660.32 5745.24 583 O, 18 5914.77 5999.::)2 6169.25 6255,18 6341 ,92 6429.32 6'626,5.."3 3012.74 DRIFT DIREC DEG. S69.05W S69.38W S69.73W S69.72W S?O.;OOW S?'O.53W $70o92W 871.,15W S71,'iSW 871.97W 873,88W 875,07W S76.95W S77.280 877.90W 877.98W S79,15W S78,I2W S77.95W $76.40W 876.67W 877,55W S78,20W 878,20W TOTAL COORDINATES 546,62 S 569,59 S 592,03 S 614,12 S 635,88 S 656,97 S C L 0 D I STANCE 1504.14 W 1600 1564,66 W 1665 1624,86 W 1729 1684,66 W 1793 1743.99 W 1856 1802,79 W 1918 1860,94 W 1980 677, ' 697" '~~ 1918.51 W 20,41,23 7'16, ,975 735. 767,~ ,l~',siltl,l'~{j 2276 78 ~51.58 ~ 2387",4.2 SURES ANGLE D Pi S 39 S 70 I 42 W I't S 69 ,59 4E: 36 S 69 58 49 1 O S 69 58 i7 30 8 .69' ~'" 77 S 69 58 38 ld S 70 O 2 W 793,83 S 805,37 S 816.,40 S 826,87 S 837,38 S 848,48 S 871.86 S 883,77 S 894,87 S 905.07, S 927.22 8 FEET AT S 7':2 4 31 W 2304,05 W 2440 2355,69 W 249;24 2407,43 W 2545 2459,71 td 2598 2512,1 1 W 265i 2614.77 W 2756 2664,52 W 28 07 2713,01 W 2856 2760,52 W 2905 2866,5.t td 3012 S S 75 S 15 S 47 S 35 S 53 S 29 S 26 S 78 S I0 S 7'4 S 71 .2 39 td 71 1i 58 W 71 20 13 W 71 33 35 W 71 39 1 W 71 44 42 W 71 50 51 W 72 4 31 D 0 G L E '5 F' ¢ E R I T D E G ,," i 0 0 i:':' T 2 67 :5 87 7.3 't 344 b :5 r' '740 72 i 9 .;3' 9 '") .'Z~ .,~, 4 12 58 ;-2 ..-' 06 55-* 969 635 000 AR~'O KUPRRUK Y-11 GYROSCOPIC SURVEY JOB t,lO 1380 SEC. 1 ,Ti IH.,R':~E,i. JM SURFRCE i...OCI~I'ION 568'FI,IL 1 i32 :FidL MEASURED DEPTH ~,~ND OTHER DATA FOR EVERY EVEN l'OO FEET OF SUB SEA DEP'rH. · i:(B ELEV 96,00 F'T, TRUE MEASURED VERTICAL SUB HD-TVD DEPTH DEPTH SEA DIFFERENCE VERTZ C. ORRECT'i ON TOT~.~L COORDINATES 0 0, -96 0 ! 96 196. ! 00 0 296 296. 200 0 496 496, 400 0 596 596, 500 0 696 696, 600 0 796 796. 700 0 896 896., 800 0 996 996, 900 0 1,096 1,096, 1,000 0 il96 1196, 1100 0 1296 1296. 1200 0 1396 1396, 130-0 0 14'96' 1496. 1400 0 1596 1596. 15'00 0 1696 1696, 1600 .0 1796 1796, I?O0 O' 1896 1896. 180,0 0 1996 1996. 1900 0 2096 2096, '2000 0 2196 2196, 2100 0 2296 2296, 2200 0 239? 2396. 2300 0 2497 2496, 2400 I 2599 2596. 2500 2 2702 2696. 2600 6 28.08 2796. 2700 1t 2916 2896, 2800 20 3029 2996. 2900 32 3145 3096, 3000 48 3265 3196. 3100 65 3389 3296, 3200 92 3519 3396, 3306 122 3654 3496, 3400 158 . ':0 ,, 0 0 0 .0 0 0 i 5 12 16 2O ,00 1,00 1 . 52 2,02 2,6.0 2 89 2 2 I 70 43 20 90 34 35 33 79 30 47 08 I? ,42 .09 ,53 09 08 07 197 72 ;50 6 9 13 16 20 24 25 23 17' 7 .7 25 47 71 97 127 i 61 S I-,I N N t,I N N N N N N S S S S N i,1 i'..I N I',l i',l N N N N S S S S S S 7 8 I1 12 17 27 .45 70 102 142 191 245 3,07 ;375 452 537 ,00 .7i I 50 1 82 2 42 2 90 3 04 .3 06 2 ~' 260 2 44 3,7'5 4 74 5 55 6 32 39 65 O~ ~5 06 70 67' ?' 2: ' i'" t' y- ' -.--' ' ..-~- ARCO KLP~4RLK 11 G~Ru~.~COPIC SUP, VE¥ JOB biO ~EC"' '.,1,1'11H,RgE,UH. 5LRFauE-' i ..... "" LOCATIOt~ 568'FN[. I12:2'FklL I'~IEASIJRED DEPTH AND OTHER DA'fA FOR EVERY EVEN 100 FEET OF ~,LB'" ~ SE~ DEPTH TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA D IFFEREt.4C.E CORRECTION TOTAL COORDINRTES 3,7'92 3596 3929 3696 ,t 067 ",3?96 42:04 3896 4339 $996 4474 4'096 ,1609 4196 ,I743 42.96 ,i877 4~96 '5.'011 4496 51 43 4596 5275 ,1696 5405 4,~96 5535 4896 5663 4996 579 t 5096 5917 5196 6 042 5296 6165 5B96 6288 5496 6409 5596 6529 5696 6647 5796 6?64 5896 688B 5996 7001 6096 7119 6196 ?236 6296 7352 6~96 7467 6,t96 758t 6596 7695 6696 77'25 - -o =500 195 3608 233 37'00 270 38 O 8 307 390.0 3474 ,t 000 378 4100 412 4200 447 4SOO 481 4400 514. ~500 5~7 4600 57'8 47'00 6 09 4800 638 4908 667 5000 694 5100 "'" 520 O ~' - 5300 '769 5400 792 55 ,_ 5600 83;2 · ,,, r 0 O 850 5800 868 5900 886 6000 904 61 O O 922 62 0 0 9 ;~; 9 6300 955 6,t 00 97 0 6500 984 6600 993 662? I 002 37 38 36 35 34 3,3 196,50 23 t , 85 267,01 301 , 47' 3..5 59 368,99 4'02,51 4:.45,81 468,90 501 ,,t5 33 533,30 ~ 31,. 563,79 ,7).(,,I (-,~t 't tS¢;?'.. ,';, .,..~.~ .. .. , ,, ..,.., .... ,.... 746,84 766., 22 .782,66 810,55 823 26 835,47 848,59 876 20 889 65 9 01 7'4 924 24 9.',? 7 , ,..'~ 2 24 23 20 20 18 18 18 18 18 17 t6 15 14 i4 4 625 54 800 54 887 70 9 ? 2 '~,q 1056 52 II 4 O ,i 1224 05 1307 OS 1~88 90 1469 65 1549 29 1627 97 1705 40 1781 34 1855 50 1928 03 1999 08 206~ 54 2136 84 2202 69 2266 70 2328 23 2388 9S 2450 55 2512 59 2573 54 2632,78 2689.77 2744,70 2852,24 2866,5i ARCO I,,tJP~RIjI, Y.-i i SEC, I,T1 IN,RgE.,.UN i( E L i::': ;,/ 96 , 00 F T , It,ITERP~JLHTED ',].¢~LUEt5 FO[C, E'./Et',~ 1000 FEET Of:::' i'iEP.':~URED DEPTH, TRUE i"IEAStJRED VERT I C F:d.. '3 t Jr3 DEPTH DEF'TH SE~ 0 0 100 O J 0 O O 2000 2000 3000 297i 40 00 374 '? 50;00 4408 6000 5263 7,00,0 6 '095 ?725 672:~ 904 2875 5999 6627 3 8 758 t 975 2866 70 il 5 'l ARCO KUPARUK Y-'ll GYRO':"'COP':[C 'SUR C'EC I , , , .... , TI 1H RgE UH SURFACE L. OCAT[OH 568"FNL ]HTERPOL~TED 'fRUE VERT~O~L DEPTHS.. COORDINATES AND CLOSLIRES FOR [.~ZVEN DEPTi'~S TRUE C:ODE MEASURED VERTICAL TOTAL N A PI E D E P T H D E P T H COORD!NATES CLOSURE DISTANCE ANGLE D i,i K B [".". L. [-:i~ ':~ ~i. 0 ) F'T SUB SIS A TOP U.SAND 6819 TOP L ,,SAND 7024 PBTD 7588 TD 7725 601'9 20 6238 77- '828 78 S 838 49 '~'' 85i i8 $ 868 I 0 S 913 73,.~' 927 22 S 24'I7,3'.2 2464.., ',)7 2524,62 2599, t 0 ,?~8 01,98 ~.2866,51 2555,45 2664., ~25 274 O, 24 2947 , 20 301 ;2,7 4 71 1 2 ,::t. 7i 31 50 71 56 724 HORIZONTAL ARGO ALASKA ~ KUPARUK Y-I! RADIUS OF CURVATURE GYROSCOPIC; SURVEY SCALE: !" = I000' MARCH 15,.1983 _ _ T. I i N., R.9E., U.M.- 400- 800- SURFACE LOCATION IS 568' SNL 11;52' EWL ~- SEC, ! 'r. I I N. ~ R,9E. ~ U.M. _ 1200- 1600- . . VERTICAL SECTION ARCO ALASKA~ INC. KUPARUK Y-II RADIUS OF CURVATURE. 2400- ALL DEPTHS SHOWN ARE'-TVD' -? · ,. ~ , i-----7 ........... i .... ::::_:_'.;-7:-'-::::.--'----i' :".::.'.7_: i':: .... _-"_ :__i::':. --%? ~, --. :.....~ ......... ,+-, - _ ......... --4- ................ ~ ......................... i ........... , i - I ; ' ' ~ ........ ?'':'~"i '' ; ............ f .... -- ...... Suggested form to be inserted in each "Active" well folder to check for timely-compliance with our regulations. · ' Ope~ator~ We~ N~ 'Reports and Materials~ to be received by: Date Required Date Received Remarks ., Completion Report Yes ~--'~ Well History Yes _S~es ~ _ pt Core Chips /~L.~/A~.~. ~' I lq'" Core Description ,~ .,.. Registered S~ey Plat ~e.~ Inclination S~ey /~ , . Drill St~ Test Re~s ~s R~. Yes .~ , , KUPARUK ENGINEERING TO: Wi l' 1 i a m V'~-n ~A 1 en TRANSMITTAL ,4 . FROM: D. W. Bose/Shelby J. Matthews DATE' · Transmitted herewith are the following- .. WEL..[ NAME- _'/y-/j :. . , R/. TECE~P ACKNOWLEDGED: , ._ __~,~A,~ ,~,~ ,~c~ ~o A,CO A~A,~A. ~,~. -~"./// - .' ATTN' SHELBY J. MATTHEWS -' AFA/311 P.O, BOX 360 ANCHORAGE, AK. 99510 Alaska Oil & Gas Cons, Oommission Anchorage KUPARUK ENGINEERING TRANSMITTAL TO: DATE' William Van Allen FROM' D.W. Bose/Shelby J. 'Matthews Transmitted herewith are the following- PLEASE NOTE~ S - SEPIA, F- FILM, T - TAPE, PC - PHOTOCOPY RECEIPT ACKNOWLEDGED' DATE' / PLEASE RETURN RECEIPT~O: ARCO ALASKA, INC. ATTN: SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 RECEIVED NilJ~ Oil & Gas l;ons. ~,emmisslon - /_ STATE OF ALASKA .. ,,"z,~ / MONTHLYALASKA ( ". AND GAS CONSERVATION CC'-'"~AISSION {~%,. "" °' ""' ° r O"' - · Drilling wellX~ ' 2. Name of operator . il . ARCO Alaska, Inc. 3. Address 8. APl Number ~ I .! P. O. Box 360, Anchorage, AK 029-20926 ] ~ 50- 4. Location of Well at surface 568 ' FNL, 1132' FWL, Sec. 1, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. PAD 67', 96' RKB ADL 25646 ALK 2577 99510 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 1Y-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool For the Month of. March ,19 83 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudde csg. tstd 7 3-1/2" 03/23/ d well @ 1200 hrs, 03/07/83. Drld 12-1/4" hole to 2242. Ran, cmtd. & tstd 9-5/8" Drlg 8-1/2" to 7398. Ran logs. Cont drlg 8-1/2" hole to 7725' TD. Ran, cmtd & " csg. Arctic pack 7" x 10-3/4" ann. Ran gyro. Ran logs. Squeezed csg. Ran completion assy. Perforated well. Secured well & released rig ~ 0200 hfs 83. SEE DRILLING HISTORY 13. Casing 9-5/8" 7" 26# or liner run and quantities of cement, results of pressure tests 40#/ft. J-55, BTC csg w/1000 sx AS 111/250 sx AS I cmt. /ft, J-55, BTC w/390 sx lead, 590 sx tail cmt. SEE DRILLING HISTORY 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/FDC/CNL/GR/SP/CAL Run #1 f/7262'-2218' Run #2 f/7262'-2218' CBL f/6000' to 7300' 6. DST data, perforating data, shows of H2S, miscellaneous data 6988'-6990.5' @ 4 spf 6760'-6762.5' ~ 4 spf for 7" squeeze job. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge· '~.,-'~_~ ~ Area Drilling Engineer SIGNED,~- ~"~~' ~" ~'~ TITLE .......... DATE NOTE--Report on this form is required for each calendar month, regardless of the status of oPerations, and must be filed iff duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 H I LL/HR3 Submit in duplicate 1Y-11 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1200 hrs, 03/07/83. Drld 12-1/4" hole to 2242'. Ran 55 jts 9-5/8" 40 #/ft, J-55, BTC csg w/shoe @ 2218'. Cmtd 9-5/8" csg w/lO00 sx AS II, 250 sx AS I. ND Hydril. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC & cmt. Tstd csg to 1500 psi - ok. Drld FS & 10' new form. Tstd form to 12.5 ppg EMW - ok. Drld 8-1/2" hole to 7398'. Ran logs DIL/SFL/FDC/CNL/GR/SP/Cal. Run #1 f/7262'-2218'. Run #2 f/7262'-2218' w/GR/BHC. Cont drlg 8-1/2" hole to 7725' TD. (03/14/83) Ran 195 jts 7", 26#/ft, J-55, BTC csg w/shoe @ 7669'. Cmtd 7" csg w/390 sx lead - 590 sx tail. NU BOPE tst to 3000 psi - ok. Arctic packed 7" x 10-3/4" annulus. Ran Gyro, ran CBL over Kuparuk f/6600' to 7300'. Ran 4" squeeze gun and shot from 6988'-6990.5' w/4 spf. Set cmt retainer @ 6950' and squeezed 250 sx Class "G" cmt. Ran 4" squeeze gun and shot 6760'-6762.5' w. 4 spf. Set cmt retainer @ 6720' and squeezed w/250 sx Class "G" cmt. Tst csg to 1500 psi - ok. Drl cmt to 6997' - all soft. 7588'.c/~st csg to 1500 psi - pressure bbl off. Pumped 100 sx Class "G" across squeeze perfs and drilled out - ok. Run GR/CBL. Run Geo Van gun~. (Ran 213 jts of 3-1/2", 9.2 #/ft, J-55, BTC tbg.) Tbg tail @ 6741' top of fish @ 7219'. Tst SSSV to 5000 psi - ok. ND BOPE. NU tree & tst to 2500 ps'i - ok. Disp well to diesel. Set pkr. Fire guns. Dropped ball & sheared off guns. Close SSSV. Rig released at 0200 hrs, 03/23/83. HILL/DH4 KUPARUK ENGINEERING TRANSMITTAL TO' William Van Allen FROM: D.W. Bose/Shelby J. Matthews Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM~, PC - PHOTOCOPY R~KNOWLEDGED' '~PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/311 P.O. BOX 360 Alaska Oil & Gas Cons. Commission ANCHORAGE, AKo 99510'- Anchorage ARCO Alaska, Inc. Post Office Bo.. ,:160 Anchorage, Alaska 99510 Telephone 907 277 5637 March 2, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 1Y-11 Dear Mr. Chatterton' Enclosed is a Sundry Notice for the subject well. We propose altering the casing in 1Y-11. Since we expect this well to spud March 4, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Area Drilling Engineer JBK/JG2L18' sm Enclosure ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCornpany '--" STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO~v, MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER I~X 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 83-41 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20926 4. Location of Well Surface: 568' FNL, 1132' FWL, Sec. 1, T11N, RgE, UM Target 0 6092' TVD: 1320' FNL, 1320' FEL, Sec. 2, T11N, R9E, UM 5. Elevationinfeet(indicate KB, DF, etc.) 96' RKB 67' PAD 12. I 6. Lease Designation and Serial No. ADL 25646 ALK 2577 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1Y-11 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [~X Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Pursuant to AOGCC's approval of 9-5/8", 36# & 40#, K-55 and 9-5/8", 36# & 40#, HF-ERW, Arctic Grade, J-55 casing for use as surface casing in the Kuparuk River Field, ARCO Alaska, Inc., submits the following changes to the casing design of well 1Y-11: The surface hole will be drilled with a 12-1/4" bit to 2200' MD (2200' TVD). Surface casing will be set using 9-5/8", 40# HF-ERW J-55 from 2200' to 70'. The casing string will then crossover to 10-3/4", 45.5#, K-55 for one remaining joint (±41' in length) and landed in the wellhead 29' below RKB elevation. The surface casing will be cemented with a lead slurry of 1000 sx Arctic Set Ill and a tail slurry of 250 sx Arctic Set I. The remaining wellbore mechanics (i.e.; hole size, casing size, etc.) will be as specified in the original permit application. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . ~ ~ / Title Area Dri 1 ling Engineer The space~elow for'Commission / Conditions of Approval, if any: Approved by Form 10-403 Rev. 7-1-80 Subsequent Work Re.~orted on Form No. iO-Y~YDated ///~K~ ApproveC (. - By Order of the Commission Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ~ h 1983 Marc_~ 2, }~. Jeffrey B. Kewin Senior Drilling Engineer ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Kuparuk River Unit 1Y-il ARCO Alaska, Inc. Permit ~o. 83-41 .. ~o Ft~ ,. . , , , · Sur. Loc. 56~'F~,, 11~,.~' ' gcc ! TI!I'? RgE U~..~ Btmhole Loc. !&45'~{L, 1729'FEL, Sec. 2, TllN, R9E, U}~. Dear Mr. Kewin: Enclosed is the aoprove~ application for permit to drill the re~e~enced well. above = ~ If corin~ is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a r~d lo~ are not required. A continuous directional survey is required am per 20 AAC 25.050(b)(5). If available, a tape containing the dizitized .log information shall be submitted on all logs for copying except experimental log~, velocity surveys a~ dip~eter survevs.~ . ~4any rivers in alaska and thezr drainage systems have ;~een classified as i~portant for the spawning or migration of ~ ~ .. fish. Operations in these areas are subject to AS 16.05 ~Tm and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing Operations you may be contacted by the Habitat Coordinator's ~ n ~ of Fish and Game. Office, ~,e~art,=ent Pollution of any waters of the State is prohibited by AS 4a, ~apter 3, Article 7 and the regulations promul~:ated thereunder (Title 18 Alaska Administrative Code, Chapter 70) and by the Federal Water Po!l~tion Control Act, as amended. Prior to co~.mencing operation~ you ~ay be contacted by a. representative oz t~e Department of Environnental Conservation ~. =~e~u~ng field ~-~ork, please notify this office hours prior to commencing installation of the blowout Mr. Jeffrey B. Kewin Kuparuk River Unit 1Y-11 -2- March 2, 1983 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. ~ere 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. In the event of suspension or abandonment, please give this offic-e.~adequate advance notification so that we may have a %fitness present. Very truly yours, ' ~''~_~ i ~. Vi c~tert~n Chairman of A!as~ Oil and Gas Conservation Co~ission Enc to sure CC, Depar~ent of Fish & Game, Habitat Section w/o encl. DePartment of Environmental Conservation w/o encl. be ARCO Alaska, Inc. Post Office i 360 Anchorage, Aiaska 99510 Telephone 907 277 5637 February 25, 1983 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1Y-11 Dear Mr. Chatterton: Enclosed are: o An application for Permit to Drill Kuparuk 1Y-11, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. Since we estimate spudding this well on March 6, 1983, your prompt approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~ Engineer JBK/JG2L13: sm Attachments ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA (JiL AND GAS CONSERVATION CO,,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~ DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE [~X MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 568' FNL, 1132' FWL, Sec. 1, T11N, R9E, UN At top of proposed producing interval ~ Target, 1320' FNL, 1320' FEL, Sec. 2, T11N, RgE, UM At total depth 1445' FNL, 1729' FEL, Sec. 2, T11N, RgE, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 1Y-11 11. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. PAD 67', RKB 96' I ADL 25646 ALK 2577 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 33 mi. NW of Deadhorse 1Y-12 well 60' ~ surface feet 16. Proposed depth (MD & TVD) 7633' MD, 6611' TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT2300 feet. 21 14. Distance to nearest property or lease line miles 3551' FWL ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 39.5° (see 20AAC25.035(c) (2) 18. Approximate spud date 03/06/83 2748 psig@ 80°F Surface 3130 psig@~t. TD (TVD) Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER Grade Coupling H-40 PEB K-55 BTC K-SS BTC Hole Casing Weight ! ;24" 16" 65.5# ~3-1/2" 10-3/4" 45.5# i8-3/4" 7" 26# 22. Describe proposed program: Length SETTING DEPTH MD TOP TVD 80~' 29' I 29' 2171 ' 29' I 29' I I 28' I I 28' 7605' M D BOTTOM TV D 109'I 109' 2200'12200' I 7633' I 6611 ' I I QUANTITY OF CEMENT (include stage data) ±200 c.f. 1200 sx AS III & 250 sx AS I 300 sx Class "G"extended 430 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 7633' MD, (6611' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 p~i, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Expected maximum surface pressure will be 2748 psig. Pressure calculations are based on virgin reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. Selected intervals will be logged. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon completion of the job. 1Y-11 will be 60' away from 1Y-12 (~ the surface. ~T~~re no closer wellbores anywhere downhole. Top of cement for the production string will be placed ~250' MD~ approximately 500' MD 23. I hereby certify that the foregoing is true and correct to the best of my knov~ledge Samples required [~YES ~'~N O Permit number APPROVED BY Form 10-401 _ above ~:op-of'~I//est Sak Sands. Area Drilling Engineer DATE / / CONDITIONS OF APPROVAL Mud log required II Directional Survey required I 50--APl numbero l., DYES [~NO I ~YES []NO I I i~~'~,~/u._/~ / ,,¢ ,~ SEE COVER LETTER FOR OTHER REQUIREMENTS ~~~~~'~,~ OM M I SS I ON E R DATE Submit in triplicate ALASKA,. -1 "T,/ELLJ j . _ i KOP, TVr. 2'DI~iO i . . _~ ......... ~. ]'OP- tjl- SAK- ! SAND~-- i -{ - ............ ;; ;'; :.'.; L i- -;:!:::-:!- :::-! -' ; J'- ' : ' ~ ................ t .....~ .....~ ............ { ]-' - - J ........ 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J! ]~[! i!ll ~liJ ,.J jilI [liJ lj]J jJj~ ~i:J ~ j [ J/~ : i ! ~T~{ i i i J i t ~ J ! i i j I i i ~ I t i I i i ~ i J I t i I I [ ~ i i I j,j [ [ [ I i [ : . , , ~ , : , ~: .::~ .~ : : i ~ !il i ! ~ [ i I i I i i I i i l.I J i I J i t [ I i [ i I i Jl : : ~ : : ~ j : : ~ i ~ ~UUiL :ill ii!! ii:i I~11 j!il I'i I JJ:J !Jil :t': , . , . .J - I Ij ., , i.. iii iii[ [JJJ :il:i:: I: JJJJ JJJJJ JJJ] [J l J J JJJJ jjj' ;,Iii [[ ][l~ ;ill jili ;iii ' ~ [ii llll ill 'i I 'i i[ij [ill ,i j ~ ~jJj ifil :ill j itl Ill ill I I Il Il IlJl IJJ[ [Iii ,... , :, , .- . ., jj ,iii ;[JJ iii! Jill [ i!i ii! !1 I [ il 'J Jill ill ~ij [jij ]ll~ Jill JJJ Il ~:J i~[11 Jji ! J JJ J JJJJ j[ , !: ~! !~ : : j !,l i{ji i, Ji ilil i!!l illl illi ,I, J iJil :~ ~UUI[ {:: ; ;i' 'jill,: i ' 1i ',''Jill ,iii! '[iiJ '.lJlJ [J[J ..... illL :';~ Surface Diverter System e 1. 16" - 2000 psi Tankco starting head. 2. Tankco quick connect assy. 3. 16" x 20" 2000 psi double studded adapter. 4. 20" 2000 psi. drilling spool w/lO" side outl ets. 5. 10" ball valves, hydraulically actuated, w/lO" lines to reserve pit. Valves to open automatically upon closure of annular preventer. 20" 2000 psi annul ar preventer. 20" bell nipple. Maintenance & Operation 2, Upon initial installation close annular preventer and verify that ball valves have opened properly. Close annular preventer and blow air through diverter lines'every 12 hours. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually override and close ball valve to upwind diverter line. Do not shut in well under any circumstances. 16" Conductor ! m ;) ) 7 · / DIAGRAM ~1 13-5/8" SO00 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. ll" - 3000 .psi casing head 3. 1I" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 13-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling s~ool 13-5/8" - 5000 psi pipe rams 6. 12-5/8" - 5000 psi drilling spool w/choke and kill lines 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi blind rams -g. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WiTH 1SO0 PSI DOWNSTRE~d~I OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON ~ADC REPORT. THE ACCEPTABLE LOWER LIblIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. 13-5/8" BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SE. AT AND SEAT IN WELLHEAD. RUN IN LOCK DOWN SCREWS iN HEJkD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS' VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR i0 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES° TEST REIVtAINING UNTESTED MANIFOLD VALVES, iF ANY, WIl~H 3000 PSI UPSTRE~qdVl OF VALVE AND ZERO PSI DOWNSTREJ~4. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PI PE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR !0 MINUTES BLEED TO ZERO PSI. 11. OPEN 80TTOM SET OF PIPE RAMS. BACK OFF ;qUNNiNG JOINT AND PULL OUT OF HOLE. CLOSE ~L~ND .qAMS AND TEST TO 3000 PSI FOR i0 MINUTES. BLEED TO ZERO PSI. 12. OPEN 8LIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET ,iN DRILLING POSiTiON. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND iNSIDE 80P TO 3000 PSI WiTH KOOMEY PUMP. 15. RECORD TEST [NFORMAT.TON ON BLOWOUT ?RE"iE:NTE~ TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. i6. PERFORM COMPLETE 5OPE TEST ONCE A WEEK AND ?JNC- TiONALLY OPERATE BOPE DAILY. C ") '! lo C c , L ) .9 f c , 1 TBG i HD 3. 2 __ · 0 IAGP~AM ~2 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tankco starting head 2. 11" - 3000 psi casing head 3. 11" - 3000 psi x 7-1/16" - 3000 psi tuDing head ¢. 7-1/16" - 3000 psi x 11" - 3000 psi doui)le studded adapter 5. 11" - 3000 psi x 13-5/8" - 5000 psi spacer spool 6. 12-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 7. 13-5/8" - 5000 psi pipe rams 8. 13-5/8" - 5000 psi drilling spool w/choke and kill lines 9. 13-5/8" - 5000 psi pipe rams 10. 13-5/8" - 5000 psi blind rams 11. 13-5/8" - 5000 psi annular ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3, OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IAPC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS'CLOSING TIME AND 1200 PSI REMAINING PRESSURE. !3-5/8" BOP STACK TEST 1. FILL 80P STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACT- ED. PREDETERMINE DEPTH THAT TEST PLUG WILL SE. AT AND SEAT tN WELLHEAD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI ANO HOLD FOR !0 MINUTES. 5. INCREASE PRESSURE TO 1800 PSI 'AND HOLE FOR 10 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNUl~AR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. - 7'. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTREAM OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED MANIFOLD VALYES, IF ANY, WITH 3000 PSI UPSTREAM OF VALVE AND ZERO PSI DOWNSTREAM, BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SET OF PIPE P~AMS AND CLOSE 80TTOM SET OF PIPE RAMS. 10. INCRF_ASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES BLEED TO ZERO PSI. ,- 11. OPEN BO1-FOM SET OF PIPE RAMS. BACK OFF RUNNING JOINT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RAMS AND RECOVER TEST PLUG. ,MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLING POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND iNSIDE BOP TO 3000 ~Si WITH KOOMEY PUMP. !5. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SiGN AND SEND TO OR[LLI}IG SUPE?/[SOR. 16. PERFORM COMPLETE BOPE TEST ONCE A 'NEE,'< AND FUNC- T! ONALL Y OPERATE BOPE 3A i LY. LOC ATE D ., IN PROTRACTED ,SEC IITWR lIN.I RGE.9 .E.IUMI,AT .MER,,IDIAN. . · . t . RESERVE PiT TY P..STAKEOUT PHASE II ~. Y=5974755.35 X= '530921.60 LAT. 70° 20'31.5157". LONG. 149° 44' 56,599" 568'FNL, 1252' FWL I0, Y= 5974755.37 X= 530861,81 LAT, 70°20' 31,5163" LONG, 149o44'58.345= 568' FN~, 119;)' FWL I I. Y.= 5974755. 40 X= 530801,57 LAT. 70°20'31, 5190" LONG, 149°45'00,105" · 568' FNL, 1132' F~VL RESERVE- PIT ' 380' , PHASE I LONG. 149°45'01.858" 568' FNL , 1072' FWL . 13. Y'- 5975115.63, X = 530741.64 LAT. 70 °20' 35.064~'" LONG. 149° 45'01.813" 207'FNL, 1074 FWL 14. Y=5975115. 61 X= 530801.96 LAT. 70 o 20' 35.0621" LO NG. 149° 45'00.050" 208'FNL, 1134' FWL 15. Y= 5975115.51' X-- 530861.37 ' LAT. '70° 20'$5.0587" LON~. 149°44' 58.315" 208 FNL~ 119:5' FWL 16. Y=5975115.36 · X" 530921.68 LAT. 70°20'35.0547" LONG. 149°44 '56. 552" 208' FNL~I254'FWL Cd ,'"' ~.. SURVEY I D.S..z 12 VICINITY MAP Scole': I"=lmi. NOTES' I. ALL Y E~ X COORDINATES ARE ALASKA .STATE PLANE, ZONE 4. 2, DISTANCES TO SECTION LINES ARE GEODETIC, 3. SEE REF. DWG, 22988, SHT, 7Y'I2-3OOI,REV. 72, 4. DRILL SITE AND Y E~ X COORDINATES ARE BASED ON MONUMENTS I'Y WEST AND I.Y MIDDLE BY L HD A~SOClATES, SURVEYOR'S CERTIFICATE I.HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF , ALASKA, AND THAT THIS PLAT REPRESENTS A SURVEY MADE UNDER MY DIRECT SUPERVISION, AND THAT ALL,DETAILS ARE e CORRECT AS OF JANUARY '50,1983. Kuparuk Project North Slope Drilling AS. BUILT LOCATION PHASE I drawn by'J.B./D.E dwg. no. NSK9.05 d 17 illllllll ..~ till I~IVlIlII [ ' CHECK LIST FOR NEW WELL PERMITS Company Lease & Wail No. ~~f -'~ ~'/( ....... ITEM APPROVE DATE (1) Fee (2) Loc. (2 thru 8) :(3) Admin (/<.c.~p %"~'~3 ~(9/ thru 11) (4) Casg ~.,~.~ 3-2-F3 (12 thru 20) (21 thru 24) e 10. 11. YE S NO REMARK S 1 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 well bo.re plat included ............... ~. 7. Is operator the .only affected party ................................. 8. Can permit be approved before ten-day wait .......................... Does operator have a bond in force ..... ~_~=_ Is a conservation order needed . Is administrative approval needed :iiiiiiiiiiiiiiiiiiiii{i{iiii![~ 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all' known prodUctive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked-off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 .......... ,. Is adequate well bore separation proposed ........................... Is a diverter system required ....................................... ,~ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~mo psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. ~ Geology: Engineering: · ~K LC S BEW ;CVA ~ JKT~HJH rev: 12/06/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. .o // bISTAPM VERIFICATION LISTING ~.,Vp OlO.H02 VERIFICATIOn? LISTING PAGE ~* TAPE HEADER ** D~TE 9~Y~IN :0000 rAPE MA~ :8096 ~ONTI~[IATION ~ PREVIOUS TAPE : ********** EOF ********** ** FILE HEADER ** SERVICE CW ~ aRCO ~bASKA I~C W~ : IY-11 F~ ~ ~UPAR~t~ RAN,,:. 9~ SECT: CiOUN~ STAT.: A,LA CTR¥~ :USA S'vm E UNIT TYPE CATE ~.~,. COD 000 000 016 065 000 000 006 065 000 OOO 008 :065 002 065 004 065 000 000 002 065 00:0 nO0 00~ 065 000 000 006 065 000 000 004 06~ ~VP 010,~02 VERIFIC;~T,IO~i !,,,ISTIbiG P~GE 2 ******************************************************************************** SC}{hUMBERCER * ******************************************************************************** 2O{~uA.~'y = ATLAS]TIC RIC~{F'I~LD CO~PA~]Y ~Et, L = 1Y-I, 1 ~IELD = ~{JD.AR{]~ ~?OUNTY = ~]ORT~ SLOPE BOROUGM JOB t~[l,~E~ AT ACC: 68096 ~UM #1., D~TE LOGGED: 13-~AR-83 [,DP: ~GH PH FI, U]D bOSS 5.650 M 64.0 DF 5,800 ~ 64.0 DW 4,000 ~. 64 0 OF 2,656 m ~.~,o .~ ******************************************************************************* ** DATa FORMAT ~ECORD ** EHTRY BLOCKS TYPE SIZE PEPR CODE 4 1 66 VP 0]..0 HO2 V ..... R.tF.I.,,ltTTr".~'~ S' I~'~'C,' * DATA ** MPT P I~HT CNL PHI ,~'~ 'CNT., 'PHI 'CNI, ? 7401. 5000 -24 5156 -1.744 000 3 4727 GR DRH~ 7400,0000 SFLU -?~.0156 3q.1113 -1,744,a000 3,~,727 730.0 0099 SFLU -21i5156 GR 33 691.4 DWHO 3-i 1!6,¢ 7200.01~6 -25.7500 46.240~ 465.2500 C~L! 3.9669 56,5313 GR 33,007~ DPUO 2 224,6 T~,M -265:5000 DT -3~'768.n000 RNOm 8,5000 GR -265.5000 OT -3~768,0000 PWO~ 7,3594 ~R 3,7617 98,9375 PT 0,1~65 R~OR 9.1406 ~,673R IL~ o9,5625 DT 8,9375 GR 10,2813 ~5,2500 0.0,327 7 3 A6 3.1016 999,2500 -3 7~,0000 NCNt, ~65,5000 NRAT 3. I 816 I L D 999 2500 GR, uccc.., -265,500,9 ~I~,AT 3,0801 !LO 93,1875 2.5339 NCNL 88,9375 ln4,1975 GR 2.201,0 NCNL 99.5625 !.0,5938 II.,D 91.3750 Ga ~.3730 hCNr, e p .PROCESS ,.:~A~ LW 1 68. 1 68 1, 68 1 68 ! 68 1 68 1 68 1 68 1. 68 !, '6~ 1 68 t. 6~ 2,4~05 -999,2500 '6060,0000 3.1,73~ 2 509~ -99g,2500 -6060,0000 3,173~ 2.g355 92 7500 3.007~ 2,414~ 90,7500 ~04.6,0000 3,6895 9,9141 86 8750 272410000 ~27,5000 3.291,0 7.000,0381 SFL[I 54, SO00 G~ NRA 3.2832 PEPT 6200,047932~006~ GpS~L! EPT 6800, P -1.5 C N L 4 q O 76 SFLU 34 DR~O 6016 ") 6100.06:74 SFLU P 16.5~25 PHI 44.2871 DRMO CNI_, 476,0000 NRA 4,t2~9 FPT 6600 P -~0 PHI -ggg CNL -999 NRA -999 , ! ,0762 SFLL .2500 P~NO ,2500 ~PT 6200,0859 SFLU PM'! -999,~500 DRHO CNI., -900,2500 CAI..,I NRA -0g9,~500 'EPT 6400,0057 8FI..~U .¢ '26,g125 G~ 'PHI '999,2500 DRY0 'CNI. -999,~500 CALT 'N~A -999,~500 ~EPT 6300.1055 SFLU ;P -~3.3125 Gm IPHI -999,2500 DRHO 'CNL -999.~500 !~g~ -999.~509 ,~PT 6~00.1152 SFLU ;P 2~.5625 ~R [PHI -099,2500 D~HO ,3516 ~a ,, 6 ~ 75 DT 10,~t. 09 I, .9023 I' 1113. 0000 DT 1719 · 4375 DT 10 ~:': 564 } I L, ,07.47 R H 0 B 1, , ~03 ~ 2,1543 -99~ 2500 3 0078 1~5,500~ BT -999.~500 ~0.?~91 3 3.496 It,~ -099 2500 PHOB "'!.015938 (_:~ 3 31,84 IL~ 04[9375 DT -999.2500 RHOR !!,.5469 G~ 2.3535 I.~ 11.5.31~5 D -999.2500 RHOP fl5.2500 N~AT 92 · 0000 2,4141 NCNb 12,9062 2,6.777 NCNb .... . o o o o , 3535 NCNL 1. !.~.0000 NRhT 1,2~, 1348 IbD ,562,~ 3 NC N 15 103, 2,3438 ILD -999.2500 NCNb 3.2R13 ILD 98.0n00 G~ -999,2500 NCNb !~5,5000 NRAT 2,9199 1~8,1R75 -999,2500 NCNb 159.2500 2,7930 IbD 105,1875 GR -999,2500 NCN[. 94,9375 N~aT 2.54B~ ILl) 114.7500 GR -999.2500 NCNb 2,976~ ,8516 2500 2310,0000 3.009~ 11.1719 69,1875 2336,0000 2.5996 ~, 8418 10..~ ,0000 17,91:0000 597? 2,0879 97 ' 5000 ~ 7'676 2 ~145 1,18 n75 -999 ~500 -999 2500 3 1270 239' ,1~5n '999.~500 -999.~500 2,84108 !65,00 0 '099 2500 -99922500 2 7305 -999 2500 2,621.1. !09,0625 -990,2500 --990.2500 CaLl PHI -999 ~ R a - 999 6000 -999 -999 ' T EP, O0 PHI :999 ~A -999 EPT 5800 PHI -999 CNL -999 ~A -gg9 EPT 5700 P -20 PHI .o 9 -999 1240 SFLU 2500 D R H 0 2500 CaLl 25 O0 1338 SFLU 4063 GR 2500 DRHO 2500 ¢~t,l 2500 1,0303 IL~ t06,4375 ~ D~ -999.2~00 FH.O~ 3.5078 ,.. 3672 14.36 :SFL:U 3,5176 r750.~ 123:,7~00 DT 2500 DRHO -999:,2500 ~500 C:.aLT ~2,0~59: ~~ 2500 ,1533 SFLU 2500 DR~O 2500 C~t:I 2500 1621 SFLU 3750 GP 2500 DRHO 2500 CAI..I 2500 EPT 5600,1719 SFT,,U PHI -999,2500 DRHO CNT., -990,2500 CALI NRA -999.2500 .FPT 5500 'PHI -999 'CNL -999 'NRA -999 ,F..PT 'CNI,,, -g 3,746.1 IBM 163:,6250 : DT -g99,2500RHOF 11.2422~ ;P [PHI I ,7100 Ib~ 1.7.9....,7500 DT -999 2500 RHDB .343~ 2979 IL~ 116,4~7.~ BT ~0,7734 f :2500 DRHO 2500 CALl ,2500 2,5664 I[,~ 1.41.0000 DT -999,2500 RHOB 1.1,0391 g~ 00 1914 SFLU 24i2813 GP 99 2500 DRHO 99.2500 C~t.,'I 99.~500 2.2891 93.5000 DT -999.2500 PHOn 10,3594 O0 2012 SFLU 99,2500 DRF!O 3.1. 406 I[.N 72,81.25 DT -999,2500 RttO~ 115.3125 11~.53.91, l,~I) . !, ~75 G -999,2500 .NCNL ~06.4175 NRAT 3,3496 II.,,D 11,0.0000 -999,2500 NCNL 1.17,8750 .. 3,4492 ILD 1!.0,3750 -999,2500 NCNL 173,750:0 3 3848 11:$ 5625 -99; 2500 ~6 6~50 '! l,,,, P N C N !., N~AT 1,6885 ILD 11a.3750 Gr -999,2500 NCNL !7~.7500 NR~T 1,3828 ILD 116.0000 GR -999.2500 NCNb 1,16.4375 NRAT 2 5859 ltd -999,2500 NCNL 141,0000 NRAT 2.3477 I[.~D 100,7500 GR' -999 2500 NCNL 93~5000 NRAT 3.2578 97,7500 GR -999,2500 NCNL -999.2500 1.394.5 1. 17,6250 ,,999,2500 909',2500 3,3203 129,2500 :999.2500 999.2500 11]'431'6 ,1,2!50 '999,2500 -ggg,250n 147, 00 -999 2500 -999' ,2500 1. 7002 172' ,6~50 -999,2500 -999,~500 1 3516 I1,4i0000 -999 2500 -999 2500 2 5664 126:5000 :999 2500 999:2500 2.3672 88 6~75 ,'999i2500 999 2500 3 2285 84:1250 -999.2500 VP 010.HO~ VMRIFIC~T,I'ON LISTING P~GE fi -999,2500 5200 -27 -999 -999 5100 -26 -999 -qg9 MPT 5~00 PHI -9og CML '999 MRA -ggg 2109 SFLU 593~ G~ 2500 D~t~ 2500 C:~L... 2500 ,, 5 $~LU !.250 G~' 2500 ~500 -999,2500 DRHO -999,250n MPT 4800 P PMl -999 CNL -999 wRA -999 10,2500 C~ 2,8789 ILN 0:8,437S DT -999 2500 ,9785 I L.M 7 .. 56~5 -999,2.~00 R O~ 2500 DRHO 9.500 C.~LI ,2500 -999,2500 R~iOB 10.0469G~ 4.700, -999, 4600, -999. 'CNL -999, '~PT 4500 ~['~T -999 'CNI., -999, )EPT 4400, iP -~4, fPHI -999. 258R SFI,U 2500 ~500 C~LI 2500 ~676 093~ ~500 C~T,T 2500 2773 SFLU 5625 2500 250O 2871 SFI, U 093~ 2500 2 ,40,$2 I,.bM 6 ~ · 7::500 D:? -999. ~500 RHO~ ~0.5,156 a~ ,~137 -999 ~§00 tO: 750 2,6563 76,7500 DT -909,~500 10,4688 2,7246 79.3~5 DT -ggg 2500 10:5000 ~,7~85 70.0000 DT -999 ~500 PHOB ]0:5078 2 6543 74:9375 DT' -999.2500 RHO~ 3,0977 102,37i50 '999,2500 N'CNb ~08.4375 ,76406 ~:~, 500 ,'999 ~500 NCNL 7S: 56?5' 7,51.95 06.7500.,R -999,2500 104,5625 ~T 2,4316 106,1875 -999,2500 MCNL ~8,7500 ,6719 ILD -999,~500 NCNI,,, 2.7168 104,3750 Gm -999,~500 NCNL 76. 500 N~AT ~,9824 104.0000 -999 ~500 NC~[., 2,9414 104,0000 -999,2500 ~CNL 79,0000 3,29~0 105,7500 -999.2500 -909.~500 1..06.3125 -999,2500 0000 -.999,2500 8,2187 117.8750 -999,~500 -q99...500 2,4609 94,1875 -999,2500 -999,250o 2 7285 81~:0000 -999,2500 -9g9,~50~ 2 7754 71.~3750 :999.2500 999.~50n 3 1523 70~6250 -999,2500 -999,~500 3,0332 77.6250 9n9,2500 3 552~ 71i500 -909 2500 L.I ..... TING PAGE 7 YP 0t0,H02 YERiFICATIO~ '~ S" ,-999, .9..500 CALl -999,9.500 10. 5547 F, PT 4300 P ,,33 PHI -999 29,6:9 SFLU 2,5664 1.569 GA' ; ~,,:6875 . DT ~500 DRH0 -999,2500 ~500 C~.LI i O, 5~34 2500 EPT PHI -999 CNL -999 NRA -999 ~ 0 0 0 2500 G~ : : '999,9.:50.0 DT 2500 2500 :ClI..~'l 2500 74,9375 I l.,, D 2',687~ -999,~500 ILO 72,1~75 -999,2500 NCN5-999,2500 NRAT 71,949~ ,1875 -999,2~00 -999,2500 -999. 2500 31,:' 51,56 ~999,2500 999 I'LE t,.~ A U E :SERVIC,001 ERSI. ON ~ ~XI~U~ LENGTH I 1024 !LE TYPE ERVICF NA~E :SERVIC ~IGI~! :0000 APE ~A~F !8096 ONTI~HATIC)N ~ :01 O~ENTS :LIBRIR¥' TAPE ~;RVI. CE NA~IK :SERVIC ATE :83/03/1.7 ~IG!N : ONTINUATI[]N ~ ~E~TS !LIRRARY TAPE; EOF ********** EOF ****.8,~8