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184-036
Originated: Delivered to:18-Jun-25Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # E SET#1 2B-02A 50-029-21154-01 910106459 Kuparuk River Multi Finger Caliper Field & Processed 14-Jun-25 0 12 2B-03B 50-029-21151-02 n/a Kuparuk River Radial Bond Record Field- Final 8-Mar-25 0 13 2F-09 50-029-21090-00 910080198 Kuparuk River Plug Setting Record Field- Final 23-May-25 0 14 2F-09 50-029-21090-00 910010602 Kuparuk River Radial Bond Record Field- Final 2-May-25 0 15 2G-17 50-029-23134-00 910106461 Kuparuk River Plug Setting Record Field- Final 9-Jun-25 0 16 2K-23 50-103-20125-00 910099510 Kuparuk River Multi Finger Caliper Field & Processed 2-Jun-25 0 17 2K-34 50-103-20688-00 910096425 Kuparuk River Multi Finger Caliper Field & Processed 15-Jun-25 0 18 2M-08 50-103-20184-00 910027001 Kuparuk River Multi Finger Caliper Field & Processed 9-May-25 0 19 2M-25 50-103-20152-00 910106929 Kuparuk River Plug Setting Record Field- Final 12-Jun-25 0 110 2M-25 50-103-20152-00 910106929 Kuparuk River Tubing Cut Record Field- Final 13-Jun-25 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:216-087223-080184-036202-243190-014214-026192-101191-021T40589T40590T40591T40591T40592T40593T40594T40595T40596T405966/20/2025Gavin GluyasDigitally signed by Gavin Gluyas Date: 2025.06.20 08:42:29 -08'00'184-0362F-0950-029-21090-00 910080198Kuparuk RiverPlug Setting RecordField- Final23-May-250142F-0950-029-21090-00 910010602Kuparuk RiverRadial Bond RecordField- Final2-May-2501 HClyC1 V Mi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 2 8 2019 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ 's n ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Cement Packer Repair ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development [D Stratigraphic❑ Exploraton,❑ ServicU 184-036 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-21090-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 2F-09 ADL 25657 9. Logs (List logs and submit electronic and printed data per 20AAC25.0717 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6,560 feet Plugs measured 6047 feet true vertical 6,250 feet Junk measured 6330 feel Effective Depth measured 6,467 feet Packer measured 6,073 feet true vertical 6,166 feet true vertical 5,815 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 16 109' MD 109' TVD SURFACE 2,831 feet 9 5/8 " 2,861' MD 2860' TVD PRODUCTION 6,521 feet 7 6,550' MD 6241' TVD Tubing (size, grade, measured and true vertical depth) 3.5" J-55 6,103' MD 5,842' TVD Packers and SSSV (type, measured and true vertical depth) PACKER- BAKER FHL RETRIEVABLE PACKER 6,073' MD 5,815' TVD SAFETY VLV - BAKER FVL SAFETY VALVE 1,828' MD 1,828' TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 62 58 960 1266 144 Subsequent to operation: 62 58 960 1266 144 14. Attachments (required per 20 AAc 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development[] Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil p 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: 318-172 Contact Name: Steve Drake Authorized Name: Steve Drake Contact Email: Steve.G.Drake@cop.com Authorized Title: Sr. Wells Engineer Authorized Signature: 3 2 g 5 Contact Phone: (907) 265-6471 Date: 1/71- 41-¢/) y Form 10-404 Revised 4/2017 A ///�� RBDMS�MAR 2 9 2019 Submit Original Only Well History 2F-09 API I UIM Legal W@IIName Field Name 5002921090 2F-09 KUPARUK RIVER UNIT Well TypeOriginal KB/RT Elevation (ft) Well Status Development 125.00 PROD Left START DATE is from Daily Ops and Right Start Date represents the Job Start Legal I Start Date WeliName Last 24hr Sum AFE/RFE Rg Supervisor Job Type Start Date 10/2/2018 217-09 MIT -T (PASSED), DDT -T (IN PROGRESS), MIT -IA (PASSED), 10408952 RICHWINE, ANNCOMM 5/4/2018 DDT -IA (IN PROGRESS), T -POT (PASSED), IC -POT 1 BRUCE,DHD (PASSED) Field Supervisor 9/28/2018 RIH, TAG CBP @ 5950' CTMD, 5960' RKB. PUMP 70 BBLS 10408952 APPLEHANS, ANNCOMM 5/4/2018 DIESEL INTO IA FOLLOWED WITH 75 BBLS 1% CRW SW. AARON,Wells 12F-09 PUMPED 7 BBLS WELL LOCK CEMENT INTO IA, LAID 3 Supervisor BBLS INTO TBG. CLEANED OUT DOWN TO 5906' CTMD 7/9/2018 2F-09 RUN 1: CBL. PERFORM MAIN AND REPEAT PASS OVER 10408952 FAMA, ANNCOMM 5/4/2018 INTERVAL 6100'- 5650'. FIELD EST. TOC @ 5950'. JAKE,Wells RUN 2: PLUG. SET 2.55" PLUG AT 5960', CCL TO MID Supervisor ELLEMENT = 12.3', CCL STOP DEPTH = 5947.7'. PERFORM MIT -T TO 2500 PSI PASS RUN 3: PUNCHER. PERFORATE TUBING INTERVAL: 5938' - 5940', CCL TO TOP SHOT = 13.7', CCL STOP DEPTH = 5924.3' PUMP DOWN TUBING THROUGH PUNCHER HOLES AT 2 BPM 1200 PSI TAKING RETURNS TO IA. READY FOR COIL. 5/14/2018 2F-09 BRUSH n' FLUSHED INTERVAL @ 5000'-6100' RKB; 10408952 ZEMBA, ANNCOMM 5/4/2018 TAGGED TO @ 6287' RKB (EST. 27' OF FILL, LEAVING 45' EDDIE,Welis OF OPEN PERFS); DRIFT W/ DMY COMPOSITE BRIDGE Supervisor PLUG DOWN TO 6122' RKB. JOB COMPLETE & READY FOR ELINE. 5/7/2018 2F-09 RIH WITH 2.70" 5 BLADE JUNK MILL, TAG AT 6265' CTMD, 10408952 APPLEHANS, ANNCOMM 5/4/2018 MILL DOWN TO 6350' CTMD. DRY DRIFTTWO TIMES AARON,Wells DOWN TO 6330' CTMD, 55 BBL'S DIESEL DOWN TUBING Supervisor TO CONFIRM TUBING FREEZE PROTECTED. READY FOR ELINE 5/4/2018 2F-09 TAGGED HYDRATES @ 432' RKB. ATTEMPT TO PUMP 10408952 ZEMBA, ANNCOMM 5/4/2018 (MEOH) & PRESSURED UP TBG TO 2500 PSI W/.5 BBL. EDDIE,Wells JOB SUSPENDED FOR PLAN FORWARD. Supervisor 5/30/2017 2F-09 (PRE SW) IA DDT (FAIL) 10258771 FREEBORN, ANNCOMM 5/30/2017 DUSTY- AES,DHD Field Supervisor 5/25/2017 2F-09 (PRE -SW) : DDT -IA (FAILED). 10258771 FREEBORN. ANNCOMM 5/25/2017 DUSTY- AES,DHD Field Supervisor 5/24/2017 2F-09 (PRE SW) DE -GAS IA(COMPLETE) MIT-IA(PASS) IA DDT 10258771 FREEBORN, ANNCOMM 5/24/2017 (IN PROGRESS) DUSTY- AES,DHD Field Supervisor 5/23/2017 2F-09 (PRE SW) DEGAS IA FOR PRE SW MITIA & IA DDT (IN 10258771 FREEBORN, ANNCOMM 5/23/2017 PROGRESS) DUSTY- AES,DHD Field Supervisor 5/22/2017 2F-09 RIH WITH WEATHERFORD MOTOR & 2.8" MILL, TAGAT 10394344 MCANELLY, ANNCOMM 5/22/2017 5092' CTMD, HIT MULTIPLE STRINGERS GETTING DOWN JIM - TO HARD TAG AT 5991' CTMD (EST. 6009' RKB), PERFORM SoIstenXRWel PASSING DRAWDOWN TEST ON THE IA TO CONFIRM Is Supervisor CEMENT INTEGRITY, MILL CEMENT DOWN TO HARD TAG ON CBP AT 6019' CTMD (EST 6037' RKB), BREAK THROUGH MILLING ON CBP AT 6021' CTMD AND PUSH DOWN TO 6039' CTMD (EST. 6057' RKB), F/P TBG TO 4000' RKB, JOB COMPLETE. Page 117 Report Printed: 4/4/2019 General Well Work Request Form Well: 2F-09 Date of Request: 4/12/2018 Request SPOC: CPF2 PE David/Stephanie x7519, p r 252 Well Type: Producer Req. Written by: Steve Drake, 263-4062 Job Scope: Ann Comm Shut -In Reason Code: 270 Tubing / Casing / Packer Leaks Well Shut in Date (if SI): 11116/2015 Prioritization Category: Opportunity/Rate Adding Budget Category: 1 Kupamk Base Expense Network: Job I SAP Comment: ❑Wall Work is not justified via increased prpducrion Current Well Data Current Oil Rate (BOPD) 0 Post -Job Oil Rate (BOPD) Risked NOB (BOPD) Last SBHP 3537 psi Last Tag 6,255'md SBHP Date 411812015 Tag Date 4/18/2015 SBHP Datum (TVD/SS?) 6000 SS Max Inclin. 29° Min. LD (atlabove work) 2.81" Max Incl. Depth 5,400'md 10408952 217-09 Diagnostics and Repair (PROD) Preventive Maintenance Program Request After Well Work Data 65 Enter Rates H2S (PPM): 70ppm 1114/14 Any Fluid Restriction on Well? No Max Dogleg 4" / 100' and Max Dogleg Depth 3,200'md Well Work Justification & Objectives (and date required if appropriate): 2F-09 is an A sand producer that was completed in March of 1984. In lune of 2016 a one way packer leak was discovered during well secure operations prior to a tree swap. In May of 2017, coiled tubing attempted to place a 3bbls cement plug in the IA, on top of the packer to fix the leak. A follow up state witnessed test proved a passing postive pressure test on the IA (MITIA to 2500 psi) but a failing IA DDT. The objective of this procedure is to place an additional amount of resin/cement blend on top of the packer to fix the packer leak. This procedure also includes steps to replace surface equipment (tree and THA) while well is secure with CBP and cement. Risk/Job Concerns: Partially milled up composite bridge plug @ 6047' RKB. Minimum ID 2.75" Camco D Nipple @ 6090' RKB. This well has a 3000psi rated wellhead with o failed SSV that cannot be replaced. The tree and tubing head adaptor need to be upgraded to 5000psi. Steps: SL- Drift and attempt to bush composite clue downhole 1. MIRU SL and associated support equipment. 2. MU and RIH with LIB to get impression of CBP fish @ 6057' RKB. 3. MU and RIH with assembly in an attempt to knock CBP downhole. 3a. CTU Contingency - If SL is unable to push CBP downhole. 1. MIRU CTU and associated equipment. 2. RIH with 2 1/8" motor and 2.70" mill to push CBP into the 7" casing and as deep as possible. 3. POOH leaving well freeze protected and hand back over to SL for drifts. 4. RDMO 4. Once able to push CBP into open hole obtain updated tag and brush & flush tubing from 5,000 to 6,100' RKB (below nipple). S. Drift for 28" x 2.55" composite bridge plug. 6. RDMO. Well ready for EL. EL - CBL. Set Composite Bridee Plue. tubine bunch 1. MIRU EL and associated support equipment. 2. MU and RIH with CBL. Log across packer starting at 6080' RKB to 5772' or 200' above top of cement. Estimated top of cement is 5972' RKB. 3. MU Baker CBP and RIH. Set CBP 10' below top of cement. Will be around 5982' RKB if TOC is 5972' RKB. 4. Perform MIT on the tubing to 2500 psi to ensure CBP is holding. 4. RIH with tubing punch (2' of 4SPF) and punch holes 30' above top of cement. If TOC is 5972'tubing punch should be from 5960-5962'. 5. Pump down tubing, taking returns off of IA to ensure good TxIA communication. 6. U-tube diesel between tubing and IA to ensure good FP on backside. 7. RDMO. Well ready for CTU PROCEDURE CONTINUES ON NEXT PAGE !!!! 2F-09 Cement Packer Repair M-12-185GD.xlsm Printed W2712019 Page 2 Well: 2F-09 Date of Request: 4/12/2018 Request SPDC: CPF2 PE David/Stephanie x7519, pgr 252 Steps Continued (list service type): CTU - Place cement -resin blend on packer Planned cement blend: 14.1 ppg WeIlLock cement with 4.5-5.5 hour working time. 1. Prior to pumping cement job, contact Karl Molvig, Halliburton Cement @ 435-219-2014, karl.molvig@halliburton.com to ensure product is available. 2. MIRU CTU and associated support equipment. RU hardline to take returns off of IA and TBG. 3. RIH, taking returns off of IA, pumping 70 bbis diesel followed by 118 bbls SW with 1%CRW through the tubing punch. This will clean up the backside, place enough diesel near surface for FP as well as place corrosion inhibited SW on the backside below the OV. 4. Once above volumes are pumped away close IA and take returns up TBG. S. Lightly tag CBP and correct depth, flag pipe. PU off bottom and place nozzle 5' above CBP. Continue to pump at minimum rates down coil taking returns off of the TBG. 6. Batch up 10 bbis. of 14.1 ppg WeIlLock cement resin blend. 7. Pump 5 bbis fresh water spacer (Note: Continue to take returns off of tubing until fresh water spacer gets to nozzle. When FW reaches nozzle shut in tubing and take returns off of IA.) 8. Follow FW spacer with 10 bbis. of 14.1 ppg WeIlLock cement. 9. Follow cement with 5 bbis. fresh water spacer. 10. Pump away 7 bbis. cement into IA. 12. Once 7 bbis have been pumped into IA, close IA, open tubing, lay in remainder of WeIlLock (3 bbis.) in tubing followed by 5 bbis of fresh water. 13. POOH with CT displacing voidage with diesel to maintain full wellbore while maintaining 100 psi WHIP. 14. Trap 100 psi on well. RDMO. Allow 72 hours for cement to cure. DHD-Pressure test and surface equipment change out 1. Perform a MITIA to 2,500 psi. as well as a DDT to 0 psi. on the IA to confirm that the cement packer repair is holding in both directions. 2. Perfom MITT on tubing to 2500 psi ensure downhole barriers are in place before surface work. 3. Follow SOP to swap tree to 5K equipment as well as change out tubing head adaptor. CTU- Mill cement/CBP 1. RIH with milling assembly and mill up cement, taking returns off tubing to tanks. Mill through composite plug @ 5982' RKB. 2. Push composite plug into 7" liner. 3. POOH. FPwell. RDMO. SL - GILD 1. MIRU SL and associated support equipment. 2. RIH and set CSV on nipple @ 6,089' RKB. 3. Pull DMY valves from GI -D. 4. Install following GLD 5. PT tubing to ensure valves are holding or DD IA. 6. Pull CSV. 7. RDMO. Turn well over to Ops to BOL. DHD-TIFL 1. Perform TIFL to ensure packer repair has worked. Open Close Press Press Press 60 Deg. F 1320 1255 1260 1290 1235 1292 ------ Orifice -------- 2F4)9 Cement Packer Rep ir04-12-18 SGD.xism Printed 3/272019 MD Valve Valve Port GLM (RKB) Size Name Size 1 1905 1" Camco_BK 5/32" 2 3472 1" Camco_BK 3/16" 3 4900 V. Camco_BKO-3 1/4" 5. PT tubing to ensure valves are holding or DD IA. 6. Pull CSV. 7. RDMO. Turn well over to Ops to BOL. DHD-TIFL 1. Perform TIFL to ensure packer repair has worked. Open Close Press Press Press 60 Deg. F 1320 1255 1260 1290 1235 1292 ------ Orifice -------- 2F4)9 Cement Packer Rep ir04-12-18 SGD.xism Printed 3/272019 KUP PROD WELLNAME 2F-09 WELLBORE 2F-09 Well Attributes Max Angle & MD TD ConoeoPh(lhps Fleltl Nama WaIRon APVOW WeI1Wre 9hda dpi MbIXKeI —an lXKB1 Alaska.hs. / KUPARUK RIVER UNIT 500292199000 PROD 853 SJW.00 65600 ISSSV'. LOCKED OUT ffm. YP/At93d'. Sa PM Last Tag vence Mint citeee9 Annotation appen Ve l Ene Date welakere ,set M1oe By ._................ ................................. ........_ _. Last Tag(Est . 7' of Fill, Leaving 4So pen Perls) 6,28]0 5/142018 2F-09 zembeel n"NDER; M cot4DucroR;a 1men SAEETYVLV, I CR.] GA6 uFT. y9]fi.i suRFAcem.mams— ,s Gas UrT', SAMA GM LIFT: erode cem.m eyeev; aeay.DXKe cementpoes.9%0flan CMTEaZ:5,4kUR. 0 PLULessa cAa LIFT', 60136 PBR.6C69.0 PACKER.0.ona NIPPLE. 6.099.6 606:6.1026 IPERF:8.261.06,all ,PERP,.D ll PLUG -Il 6, sa]0 Last Rev Reason Annob[ron End D. wellbart lent Moa By Rev Reason: WellLoch Cement in IA and TBG 912812018 2F-09 laampled Casing Strings (Losing description oolml Io Il Top mKill set Depen ml sn oeptn lrvol_ peal if_.cees. Top Thread CONDUCTOR 16 1506 31.0 1090 109.0 6250 H40 WELDED Cesllp Mwdopen I OD lin) ID lint TOPIXNBI Sat Dapih IXNB) Set Dell Irv01--vivi 0....e.. Ra Thread SURFACE 95M 8.92 30.0 2860.5 28fi02 3600 J-55 BTG Led,..non OD (int ID Dm TDP (XNBI Set Oepll PIKE) sat... In (T VOL.. WVLen g...Made Tap To. PRODUCTION 7 6.28 289 6550.0 6,2408 26.00 J-55 BTC Tubing Strings Role s De:cnpuDn seine ma... lO fel TOP DIK81 sa Dep pt..Sen Nom (DID) f wt0Not Dnde Top eonnentbn TUBING 3112 299 23] 6,103.5 5,842.9 9.30 J-55 EUE8RD Completion Details III lrvml I Topmd Nomilul Top XKel pm Eo f) seem Des eom to on, 237 237 0.01 HANGER FMC GEN II TUBING HANGER 2.992 1,8283 1,6282 0.64 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 313N7) 2.810 6,0590 5.8039 27.02 PER BAKER PBR wl 10' SEALS 3.060 6,On6 5,815.4 27.02 PACKER BAKER FHLRETRIEVABLE PACKER 3.000 6,0895 5,830.5 27,03 NIPPLE CAMCO D NIPPLE 2750 6.1028 5.842.3 9.03 SOS CAMCO SHEAR OUT SUB 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Mel I Top Incl TDP Me) Leads) fl Des d".Rupees ID gni . TOTAL' ...... 5,960.0 5,]15.1 27.11 PLUG Zfil BAKER Cl LENGTH 3.5 6,330.0 6,URRI 9.05PLUG-1I111 35'BAKER1B1. OAL=28'. lh.Il2.55".COIL 8262016 PUSHED DOWN TO 6330 ON SWAT 8, Perforations & Slots T.'remI lampoon) rpplrvdl IXKpI Wel asks) Unked Zen. Des she D.n I.I.. 1 Type cmn 5,938.0 5,940.0 5,695.5 5,697.3 7132018 4.0 CMTSOZ Tubing unc sp eg phasing 8,242.0 8,255.0 7988.3 5, T29 7752F-09 51611984 40 ,PERF W de9Pnasmg; SUllum. Casing 6,269.0 6,3140 5, .4 6,0305 A4 2F-09 5/611984 4.0 IPERF deg. eng; 4" S Idlum. Casing Cement Squeezes TpPlrvm eenlrvDl Top pXNB) BM IXKBI pflKs) IXKe) On Slap Das Com 5,684.0 5,950.0 5. 47. 5706.2 Gemem Plug 91282018 ]bbls Wall cement in lA 5, .0 5, 0. 5.88].1 5715.1 Gemem Plug liwi 3 Dols WellLOck Cement in TBG Mandrel Inserts at etl N Top SVD) Vs. Uph PMaiee, TRORun Tap("") IXKBI Make .Wel OODm eels Type Take and (pal) Run Oas Com 1 19052 1,905.2 MMH FMHO 1 GAS LIFT DMV 8TM 0.000 00 5,312016 2 3,4)24 3,4654 MMH F IED 1 GAS LIFT DMY eTM 0.000 00 5,312016 3 4,9003 I4.]]9.3 MMH -MHO 1 1 GAS LIFT IVvY BTM 0.000 00 5/312016 4 6013fi 5,]62.9 MMH FMHO 1 GAS LIFT DMY BTM 0.000 00 513112016 Notes: General & Safety Endma4 Anlwl . 12/2212002 NOTE'.WAIVERED WELL'. IA X OA COMMUNICATION 1011212010 NOTE: View Schematic wl Alaska 5chematic90 Loepp, Victoria T (DOA) From: Drake, Steve G <Steve.G.Drake@conocophillips.com> Sent: Thursday, April 4, 2019 11:18 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 2F-09(PTD Attachments: 2F-09 Well History.pdf Victoria, 184-036, Sundry 318-172) 10-404 Submission Attached is a PDF with the history of wellwork that we performed under the last 10-403 to complete the packer repair work. Cement was pumped and the ensuing draw down test on the IA failed. Please let me know if you have any questions. Thanks, Steve From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, April 03, 2019 9:44 AM To: Drake, Steve G <Steve.G.Drake@conocophillips.com> Subject: [EXTERNAL]KRU 2F-09(PTD 184-036, Sundry 318-172) 10-404 Submission Steve, Please provide the well service reports for this work. They should be included in the 10-404 submission. You may email them to me. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loei)pAalaska.aov CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loeipip@alaska.gov OF Tit w w��\ I/7 s9 THE STATE Alaska Oil and Gas 11 ]�� 1 1 sKA Conservation Commission u' x _ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ALASMain: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Steve Drake Sr. Wells Engineer SCANNEr) ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-09 Permit to Drill Number: 184-036 Sundry Number: 318-172 Dear Mr. Drake: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Hollis S. French Chair DATED this 2.' day of April, 2018. RBDMS��PR 2 b 1010 0 0 ., STATE OF ALASKA APR 1 8 013 ALASKA OIL AND GAS CONSERVATION COMMISSION 4-(Z3(/ g APPLICATION FOR SUNDRY APPROVALS v AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations El Fracture Stimulate El 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: Cement Packer Repair ID 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ` Exploratory ❑ Development p• 184-036 ' 3.Address: Stratigraphic CIService ❑ 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21090-00 ' 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A • Will planned perforations require a spacing exception? Yes CINo 0 / KRU 2F-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25657 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,560' ' 6,250' ' 6467 ' 6166 ' 2500psi 6047 none Casing Length Size MD TVD Burst Collapse Conductor 78' 16" 109' 109' Surface 2,831' 12" 2,861' 2,860' Production 6,521' 7" 6,550' 6,241' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6242-6255 ' 5966-5978 3.500" J-55 6,103' 6269-6314 • 5990-6030 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL RETRIEVABLE PACKER MD=6073 TVD=5815 ' SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 3/3/97) MD=1828 TVD=1828 • 12.Attachments: Proposal Summary 2 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 2- Service ❑ 14.Estimated Date for 4/25/2018 15.Well Status after proposed work: Commencing Operations: OIL 2• WINJ ❑ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Steve Drake Contact Name: Steve Drake Authorized Title: Sr.Wells Engineer Contact Email: Steve.G.Drake@cop.com Authorized Signature: /g/ yS s/ Contact Phone: (907)263-4062 _,.,/�. Date: 4/ O U COMMISSION U E ONLY Conditions of approval: Notify Commission so that a representative may witness • Sundry Number: Plug Integrity El BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Et" 2 %8 Spacing Exception Required? Yes ❑ No Ii Subsequent Form Required: /0 -- 1 d RBDMs 1; APPROVED BY q i_z_31:::: Approved by: COMMISSIONER THE COMMISSION Date: -44.21 41 q, A 0(4 rL 4/3,3/16 O R I G I N A L Submit Form and Form 10-403 Revised 4/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate Gen,Well Work Request Form Well: 2F-09 Date of Request: 4/12/2018 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Well Type: Producer Req.Written by: Steve Drake,263-4062 Job Scope: Ann Comm Shut-In Reason Code: 270 Tubing/Casing/Packer Leaks Well Shut in Date(if SI): 11/16/2015 Prioritization Category: Opportunity/Rate Adding Budget Category: Kuparuk Base Expense Network: Job/SAP Comment: ❑Well Work is not justified via increased production F-7PreventiveMaintenance Program Request After Well Work Data Current Oil Rate(BOPD) 0 Post-Job Oil Rate(BOPD) 65 Risked NOB(BOPD) Enter Rates Last SBHP 3537 psi Last Tag 6,255'md H2S(PPM): 70ppm 1/14/14 SBHP Date 4/18/2015 Tag Date 4/18/2015 Any Fluid Restriction on Well? No SBHP Datum(TVD/SS?) 6000 SS Max Inclin. 29° Max Dogleg 4°/100'and Min. I.D(at/above work) 2.81" Max Incl. Depth 5,400'md Max Dogleg Depth 3,200'md Well Work Justification & Objectives(and date required if appropriate): 2F-09 is an A sand producer that was completed in March of 1984. In June of 2016 a one way packer leak was discovered during well secure operations prior to a tree swap. In May of 2017,coiled tubing attempted to place a 3bbls cement plug in the IA,on top of the packer to fix the leak. A follow up state witnessed test proved a passing postive pressure test on the IA(MITIA to 2500 psi)but a failing IA DDT. The objective of this procedure is to place an additional amount of resin/cement blend on top of the packer to fix the packer leak. This procedure also includes steps to replace surface equipment(tree and THA)while well is secure with CBP and cement. RiskiJouConcerns: Partially milled up composite bridge plug @ 6047'RKB. Minimum ID 2.75"Camco D Nipple @ 6090'RKB. This well has a 3000psi rated wellhead with a failed SSV that cannot be replaced. The tree and tubing head adaptor need to be upgraded to 50DDpsi. Steps: SL-Drift and attempt to push composite plug downhole 1. MIRU SL and associated support equipment. 2. MU and RIH with LIB to get impression of CBP fish @ 6057'RKB. 3. MU and RIH with assembly in an attempt to knock CBP downhole. 3a. CTU Contingency-If SL is unable to push CBP downhole. 1. MIRU CTU and associated equipment. 2. RIH with 2 1/8"motor and 2.70"mill to push CBP into the 7"casing and as deep as possible. 3. POOH leaving well freeze protected and hand back over to SL for drifts. 4. RDMO 4. Once able to push CBP into open hole obtain updated tag and brush&flush tubing from 5,000 to 6,100'RKB(below nipple). 5. Drift for 28"x 2.55"composite bridge plug. 6. RDMO. Well ready for EL. EL-CBL,Set Composite Bridge Plug,tubing punch 1. MIRU EL and associated support equipment. 2. MU and RIH with CBL. Log across packer starting at 6080'RKB to 5772'or 200'above top of cement. Estimated top of cement is 5972'RKB. 3. MU Baker CBP and RIH. Set CBP 10'below top of cement. Will be around 5982'RKB if TOC is 5972' RKB. 4. Perform MIT on the tubing to 2500 psi to ensure CBP is holding. 4. RIH with tubing punch(2'of 4SPF)and punch holes 10'above top of cement. If TOC is 5972'tubing punch should be from 5960-5962'. 5. Pump down tubing,taking returns off of IA to ensure good TxIA communication. 6. U-tube diesel between tubing and IA to ensure good FP on backside. 7. RDMO. Well ready for CTU PROCEDURE CONTINUES ON NEXT PAGE WI 2F-09 Cement Packer Repair 04-12-18 SGD.xlsrn Printed 4/16/2018 ` • Page 2 Well: 2F-0 Date of Request: 4/12/2018 Request SPOC: CPF2 PE David/Stephanie x7519,pgr 252 Steps Continued (list service type): CTU-Place cement-resin blend on packer Planned cement blend: 14.1 ppg WeIlLock cement with 4.5-5.5 hour working time. 1. Prior to pumping cement job,contact Karl Molvig,Halliburton Cement @ 435-219-2014,karl.molvig@halliburton.com to ensure product is available. 2. MIRU CTU and associated support equipment. RU hardline to take returns off of IA and TBG. 3. RIH,taking returns off of IA, pumping 70 bbls diesel followed by 118 bbls SW with 1%CRW through the tubing punch. This will clean up the backside,place enough diesel near surface for FP as well as place corrosion inhibited SW on the backside below the OV. 4. Once above volumes are pumped away close IA and take returns up TBG. 5. Lightly tag CBP and correct depth,flag pipe. PU off bottom and place nozzle 5'above CBP. Continue to pump at minimum rates down coil taking returns off of the TBG. 6. Batch up 10 bbls.of 14.1 ppg WeIlLock cement resin blend. 7. Pump 5 bbls fresh water spacer(Note: Continue to take returns off of tubing until fresh water spacer gets to nozzle. When FW reaches nozzle shut in tubing and take returns off of IA.) 8. Follow FW spacer with 10 bbls.of 14.1 ppg WeIlLock cement. 9. Follow cement with 5 bbls.fresh water spacer. 10.Pump away 7 bbls.cement into IA. 12. Once 7 bbls have been pumped into IA,close IA,open tubing,lay in remainder of WeIlLock(3 bbls.)in tubing followed by 5 bbls of fresh water. 13. POOH with CT displacing voidage with diesel to maintain full wellbore while maintaining 100 psi WHP. 14. Trap 100 psi on well. RDMO. Allow 72 hours for cement to cure. DHD-Pressure test and surface equipment change out 1. Perform a MITIA to 2,500 psi. as well as a DDT to 0 psi.on the IA to confirm that the cement packer repair is holding in both directions. 2. Perfom MITT on tubing to 2500 psi ensure downhole barriers are in place before surface work. 3. Follow SOP to swap tree to 5K equipment as well as change out tubing head adaptor. CTU-Mill cement/CBP 1. RIH with milling assembly and mill up cement,taking returns off tubing to tanks. Mill through composite plug @ 5982'RKB. 2. Push composite plug into 7"liner. 3. POOH. FP well. RDMO. SL-GLD 1. MIRU SL and associated support equipment. 2. RIH and set CSV on nipple @ 6,089'RKB. 3. Pull DMY valves from GLD. 4. Install following GLD MD Valve Valve Port Open Close Press GLM (RKB) Size Name Size Press Press 60 Deg.F 1 1905 1" Camco_BK 5/32" 1320 1255 1260 2 3472 1" Camco_BK 3/16" 1290 1235 1292 3 4900 1" Camco_BKO-3 1/4" Orifice 5. PT tubing to ensure valves are holding or DD IA. 6. Pull CSV. 7. RDMO. Turn well over to Ops to BOL. DHD-TIFL 1. Perform TIFL to ensure packer repair has worked. 2F-09 Cement Packer Repair 04-12-18 SGD.xlsm Printed 4/16/2018 KUP PROD 2F-09 a ConocoPhillips �g Well Attributes Max Angle&• TD Wellbore API/UWI Name Wellbore Status ncl 0) MD(ftKB) Act Btm(ftKB) Alaska,It1C. ^ 500292109000 ARUK RIVER UNIT PROD 28.53 5.400.00 6,560.0 CAnOCAPM�Np6 Comment H2S(ppm) Date Annotation End Date I KB-Grd(ft) "Rig Release Date ^• SSSV:LOCKED OUT 70 1/14/2014 Last WO: 33.01 3/22/1984 2F-09,4/17/2018 3.5349 PM Last Tag Vertical schematic(acNaQ Annotation Depth(ftKB) End Date Last Mod By Last Tag:SLM 6,255.0 4/18/2015 lehallf Last Rev Reason MANGER;237 Annotation77=7-1r End Date Last Mod By Rev Reason: PULL EVO-TRIEVE PLUGS,SET COMPOSITE PLUG(BAKER CBP) 8/29/2016 pproven Casing Strings Casing Description OD(in) ID(in) Top(NAB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 109.0 109.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 30.0 2,860.5 2,860.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 28.9 6,550.0 6,240.8 26.00 J-55 BTC Tubing Strings ,,,,,,,,,,,,,,,,,,,,,,,,, ,,.,,,,,., i ,Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 23.7 6,103.5 5,842.9 9.30 J-55 EUE8RD Completion Details -es".CONDUCTOR;31.0-109.0 b.-4- . _/ MiVr..... Top(ND) Top Incl Nominal Top(ftKB) (ftKB) (°) Item Des Com ID(in) 23.7 23.7 0.01 HANGER FMC GEN II TUBING HANGER 2.992 1,828.3 1,828.2 0.64 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 3/3/97) 2.810 III 6,059.0 5,803.3 27.02 PBR BAKER PER w/10'SEALS 3.000 SAFETY VLV;1,828.3 6,072.6 5,815.4 27.02 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 6,089.5 5,830.5 27.03 NIPPLE CAMCO D NIPPLE 2.750 6,102.8 5,842.3 27.03 SOS CAMCO SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) 0) Des Corn Run Date ID(in) GAS LIFT;1,9052 6,047.0 5,792.6 27.01 PLUG-CBL 3.5'BAKER CBP. OAL=28'. MAX OD=2.55". 8/26/2016 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ft Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ) Type Com ' 6,242.0 6,255.0 5,966.3 5,977.9 A-5,2F-09 5/6/1984 4.0 (PERF 90 deg.Phasing;4" Schlum.Casing 6,269.0 6.314.0 5,990.4 6,030.5 A-4,2F-09 5/6/1984 4.0 IPERF 90 deg.Phasing;4" SURFACE;30.0-2,860.5. Schlum.Casing Mandrel Inserts st GAS LIFT;3,472.4 ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com 1 1,905.2 1,905.2 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 2 3,472.4 3,465.4 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 GAS LIFT;4,900.3 3 4.900.3 4,779.3 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 } i 4 6,013 6 5,762.9 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 .'(fie cill Notes:General&Safety GAS LIFT;8,013.6 End Date Annotation 777ffffffJJJ)��f� 12/22/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION ' 10/12/2010 NOTE:View Schematic w/Alaska Schematic9.0 ff PLUG-CBLA.)O J PBR;6,058.0 _ Ati 0 .. PACKER;6,072.8 NIPPLE,6,089 5 SOS,6.102.8ii IPERF;8,242.08,255.0. IPERF;8,269.0-6,314.0�� PRODUCTION;28.9-6,550.0 • • 0 L.9 oa 0 1 I r X• N , > 2 3 7:1 ,(3,5) LYha ° Y +' rC1 > ra no 9- -0 (a O a) E , Y ca 0 O C Q - u. C 2 w.CI w +-ra c a - 0 � 0 0 - O a1 >, � Q 1 W U` NZ L E 0 6 0] p w D Y o J Q"Q) W OO O O O t0 t0 t0 O tD t0 O t0 J ❑ Q C Y ..- �' LL -6 O to m o) o) z� a) 6) m o) a s y Lo a -_ a� O 7 7 . . 3 . . . 7 7 y y 4- C LL tF- g a a a a a a a Q a a y y a C vi W 1y a In t0 1- 00 0) 0) O N N - CD v U N N N N N N N N M M co Z QL- v . o O U cU it J J W W J J J W W J J Yvv v, . i. ' - F- LL LL LL LL LL LL LL N O 1- J J J J J J J J J J J ? > N u N c O a a a a a a a a a 0 to Z Z Z z Z Z Z Z Z Z Z Z Z a) t +-' > QM O LL LL LL LL LL LL LL LL LL LL LL Ct r-. C u CU CU O u • CrZ t - ' iO " ..o - CO + >a Z O V - a o oZ o Q Ca MS V IS: 0 0LL L.I. LL p 0) J J 0_ JO Q QCr) O• y a a an V a a "C Go a a U g E.. 0 a d a, 0 a Zi a ro 1 o 0 ai 0 OS a 13 ° 0A 3 W a et 2 wfer)...Virf E MCrCCCLCL CrIICCW W W E ILI W W W W W W W W W W W > > > > > > > > > > > u /XCY W rtee CL CY CLCLCL CY • Y Y Y Y Y Y Y s Y Y Y Y o 0 •• 7 > > > > > > > > > > < < < < < < Ct [Y < < 2"_ >- W a a a a a a a a a a a 4?.,® LL as a as as aLLaCL c • > > > > > > > > > > > 0 Y YYYYYYYYYY no la L. X N K Y. f0 C W` 1p CD CO O) O N N O �•- •7 E CV �,,.,;:; N e 00 10 h 00 00 00 00 In N 1(1 ,... p p M 0 0 0 M O O O O O a, O O O O O O 0 0 0 0 0 0 �C ,� O p 0 0 0 0 0 0 0 0 0 0 0 . U U Y 0 0 0 Y U U LL 0 ui .-4l vi LL co cow 0 co co co 0 co cow 1- H H co 0 O > ` (9 C9 LL C7 C9 C7 LL C9 C9 ❑ ❑ C) C W W pop () cocoa 0 an u C ,�/tl . 't O O O O O O O 0 O O O O C aR■ tD 00 ° 000 O O O O O O 'y1 �) a r N O A C') NO h 1Z. M 00 ('') co O 0) NA N O COt0 et 0) C O U N M O M C') M '� N NI- 0 O 0 4 0 0 N 0.. N N NNNN NNNNNN. 411111111 a.) v1 Q ( O M 0) 0) 0) 0) 0) 0) 0) 0) 0) 0) a G'O 01 N O N N N N N N N N N N O O r' 0 0 0 0 0 0 0 0 0 0 O a) o O O 0 O O O O O O O O O 1n 1[') 1n 1A N in N 1A 1n N N N Co v wIND S .� C.. Z 3 a a� a s E � . F.. y - � 1n CO O 0) v v p 1n p tO N. v d Z m • Z p 0 O O O O N O tr GI E H a ‹ [� J' C' 2L O N C') Co N M M m W in Z U (a ICL➢ a N W N N C +' CO 1n o 0a OF T • • y_.\\�yy�.cs THE STATE Alaska Oil and Gas *,..4? .":„ ...416.._400. 9a O F:7,01041.7, �f T LASc Conservation Commission iA� � tx �� 333 West Seventh Avenue " �'r. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OF.G ,; Main: 907.279.1433 ALAS‘14- Fax: 907.276.7542 www.aogcc.alaska.gov Robert Blakney Sr. Wells Engineer s1#NNED JAN 12fjl ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-09 Permit to Drill Number: 184-036 Sundry Number: 316-403 Dear Mr. Blakney: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Plz,,oste- - Cathy P Foerster Chair DATED this fv day of August, 2016. RBDMS L.L AUG 1 2 2016 RECEIVED • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 9KG� /00 '1 b APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon I— Plug Perforations E Fracture Stimulate 1— Repair Well I', Operations Shutdown Suspend I— Perforate 1— Other Stimulate I— Pull Tubing I— Change Approved Program Plug for Redrill Perforate New Pool 1— Re-enter Susp Well I- Alter Casing r Other: Reaaediaf Cem/e�nt Sze-f ' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ` �kc,� ConocoPhillips Alaska,Inc. Exploratory fl Development F - 184-036' 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21090-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a Will planned perforations require a spacing exception? Yes r No F i KRU 2F-09 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25657 ' Kuparuk River Field/Kuparuk River Oil Pool ` 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 6,560' 6,250' . 6467 ' 6166 . 7,c O d 1895,6037 none Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 16" 109' 109' Surface 2,831' 9 5/8 2,861' 2,860' Production 6,521' 7" 6,550' 6,241' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6242-6255 - 5966-5978 3.500" J-55 6,103' 6269-6314 " 5990-6030 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER FHL RETRIEVABLE PACKER ` MD=6073 TVD=5815 SAFETY VLV-BAKER FVL SAFETY VALVE(LOCKED OUT 3/3/97) - MD=1828 TVD=1828 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch D Exploratory 1— Stratigraphic E Development F' Service 14.Estimated Date for 8/5/2016 15.Well Status after proposed work: Commencing Operations: OIL F• WINJ 1— WDSPL Suspended I- 16. 16.Verbal Approval: Date: GAS 1— WAG I— GSTOR I— SPLUG I'' Commission Representative: GINJ 1— Op Shutdown Abandoned 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Robert Blakney @ 265-6417 Email Robert.G.Blakney(a)conocophillips.cor Printed Name Robert Bla, ney, „..7 Title Sr.Wells Engineer r "C.------ -' t / 1 / /6 Signature Phone 265-6417 ate COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '3\LQ- L[ 63 Plug Integrity D BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: RBDMS 1,v AUG 1 2 2016 .. Post Initial Injection MIT Req'd? Yes ❑ No f 6 - At IA% alt-. Spacing Exception Required? Yes ❑ No Lb Subsequent Form Required: ` 1 7 APPROVED BY • ACU-46 I/ Approved by: P 6. R4rG444EA COMMISSIONER THE COMMISSION /� Date: Cl !(� Form -40B ''ed�1117 5valid �months fr9m the date of approval. �� Attachments in Duplicate zKUP D 2F-09 ConocoPhillips 4 Well Attribute Max AngleTD Afaska,inc. ''' ,,, _,,,, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Bile(ftKB) wc GOrirhigtps 500292109000 KUPARUK RIVER UNIT PROD 28.53 5,400.00 6,560.0 ,,, Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2F-09,7/28/20167:09:30 AM SSSV:LOCKED OUT 70 1/14/2014 Last WO: 33.01 3/22/1984 Vertical schemaPc(auua0 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,255.0 4/18/2015 Rev Reason:GLV CIO,SET EVO-TRIEVE pproven 6/4/2016 PLUGS HANGER;23.7ttill:' Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 31.0 109.0 109.0 62.50(1-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 30.0 2,860.5 2,860.2 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 28.9 6,550.0 6,240.8 26.00 J-55 BTC Tubing Strings ` Tubing Description 'String Ma...IID(in) I Top (ftKB) I Set Depth(ft..JSeDepth(TVD)I...IWt( Ib/ft) I Grade I Top Connection II I TUBING 31/2 2.992 237 6,103.511 5,842.9 9.30 J-55 EUE8RD IICompletion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl r) Item Des Com (in) 23.7 23.7 0.01 HANGER FMC GEN II TUBING HANGER 2.992 • _/...A CONDUCTOR;31.0-109.0...-4-A., :..A`M^ 1,828.3 1,828.2 0.64 SAFETY VLV BAKER FVL SAFETY VALVE(LOCKED OUT 3/3/97) 2.810 6,059.0 5,803.3 27.02 PBR BAKER PBR w/10'SEALS 3.000 6,072.6 5,815.4 27.02 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 SAFETY VLV;1,828.3 ' III .4 6,089.5 5,830.5 27.03 NIPPLE CAMCO O NIPPLE 2.750 6,102.8 5,842.3 27.03 SOS CAMCO SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl I Top(ftKB) (ftKB) (*) Des Com Run Date ID(in) 1,895.0 1,895.0 0.82 PLUG 3.5"EVO TRIEVE PLUG @ 1895'RKB 6/1/2016 PLUG;1,895.0 I 6,037.0 5,783.7 27.01 PLUG 3.5"EVO TRIEVE PLUG @ 6037'RKB 6/1/2016 Perforations&Slots Shot GAS LIFT,1,905.2 Dens ToP(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ttK6) (MB) Zone Date ft) Type Com 6,242.0 6,255.0 5,966.3 5,977.9 A-5,2F-09 5/6/1984 4.0 IPERF 90 deg.Phasing;4" Schlum.Casing 6,269.0 6,314.0 5,990.4 6,030.5 A-4,2F-09 5/6/1984 4.0 (PERF 90 deg.Phasing;4" Schlum.Casing Mandrel Inserts St ati SURFACE;30.0-2,880.5 ' N Top(TVD) Valve Latch Port Size TRO Run Top)ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 1,905.2 1,905.2 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 GAS LIFT;3,472.4 2 3,472.4 3,465.4 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 3 4,900.3 4,779.3 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 4 6,013.6 5,762.9 MMH FMHO 1 GAS LIFT DMY BTM 0.000 0.0 5/31/2016 Notes:General&Safety GAS LIFT;4,900.3 End Date Annotation 12/22/2002 NOTE:WAIVERED WELL:IA X OA COMMUNICATION 10/12/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6,013.6 j I PLUG,6,037.0 1.. PBR,6,0590 MP PACKER;6,0726 NIPPLE;6,089.5 II SOS;8,102.8 A80: (PERF;6,242.0-8,255.0-1 I IPERF;8,289.0-6,314.S----. PRODUCTION;28.96,550.0 • • Loepp, Victoria T (DOA) From: Blakney, Robert G <Robert.G.Blakney@conocophillips.com> Sent: Wednesday,August 10,2016 11:26 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2F-09(PTD 184-036, Sundry 316-403) Remedial Cement Squeeze Victoria, Is the information below sufficent?Or would you like more details? 2F-09 is an A sand producer that was completed in 1984. In June of this year a one way packer leak was discovered during well secure operations prior to a tree swap. The goal of this procedure is to remedy the packer leak using a cement packer squeeze. The NOB if successful is 65 BOPD. Cement packers have been very successful in Prudhoe(spe paper 106651),and in GKA we successfully pumped 1F-08 in 2013. The general procedure outline is as follows: SL(or DSL): Pull the 2 current plugs in the tubing. EL(or DSL): Set a composite plug just above the packer. PT tubing and plug SL(or DSL): Pull DV out of bottom GLM Coil: RIH to plug depth Pump 3bbls of 15.8#class G cement into the tubing and IA='x100' plug Mill out soft cement and plug DHD: Obtain a state witnessed passing MITIA&DDT SL: Install GLD Thanks, -Robbie From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 10,2016 10:58 AM To: Blakney, Robert G<Robert.G.Blakney@conocophillips.com> Subject: [EXTERNAL]KRU 2F-09(PTD 184-036,Sundry 316-403) Remedial Cement Squeeze Robert, Please provide some well history, background information,job scope and purpose. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 1 • • 2F-09—Cement packer squeeze procedure Slick line: 1. RIH and pull evo trieve plugs @ 1,890' RKB&6,037' RKB Eline: 1. Set composite plug @ 6,050' MD. 5' into full tubing jt above packer 2. Pressure test plug and tubing to 3,000psi. Slick line: 2. RIH and set a catcher sub on top of composite plug @ 6,050' MD. Pull DV @ 6,014' MD. Leave pocket open for cement job. 3. Pull catcher sub Coil tubing: 1. RU to take retuns from both the ia and the tubing x ct annulus 2. RU and pump corrosion inhibited seawater down the tubing thru the open pocket and up the ia to tanks. Circulate until clean seawater is seen at the return tanks then swap to pumpping 100 bbls of diesel down the tubing to FP the tubing and IA to"2,850'tvd. Immediately shut in IA& tubing. 3. Jumper the tubing and ia together at the wellhead and allow U-tube ("'45mins)enough time for the diesel level to equalize between tubing and IA. 4. Note due of the packer leak and the last SBHPS (4/18/15—11.3 ppg KWF), it is possible that the finalized IA pressure could be— 1,100 psi. This is a worst case scernario, as the packer leak is a one wayonly and is seen thru failed DDT's. 5. With well bore fluid packed, RIH with cement nozzle on CT to place cement packer on IA. Gently tag plug @ 6,050' MD. Flag the coil. 6. PU and park nozzle @ 5,750' MD,to prepare to pump down coil until cement reaches nozzle. 7. Mix 5 bbls of 15.8 ppg class G cement(wIl pump 3.0 bbls down CT). a. 3 bbls of cement equates to a TOC of— 5,970' MD(''100' above packer) 8. When cement is ready to pump,verify that the IA is Shut in and tbg x CT annulus is open and ready to take returns to tanks. 9. Pump 5bbls of clean freshwater spacer down coil, followed by a foam ball (pig spacer), followed by 3.0bbls of 15.8 ppg class g cement,followed by a foam ball,followed by 5 bbls freshwater spacer,followed by 1 ct volume of diesel displacement. 10. When cement approaches the nozzle, slow the pump rate to the minimum rate and RIH to park the nozzle @ 6,040' MD (10' above plug) as cement exits the nozzle. Pump 100' of cement above the nozzle,then slowly PU nozzle, while spotting the remaining cement. a. 3 bbls of cement fills up 350' of 3.5" tubing, so have the nozzle @ 5700' MD as the last cement exits the nozzle. Then shutdown pumping and PU nozzle and park @ 5400' MD. • • 11. Shut in the tbg x CT annulus. Open IA to take returns to tanks,then pump minimum rate down coil to displace 2.3 bbls of cement into IA. Shut-in the IA. 12. TOC will be at"'5970'MD(assuming 100%fluid displacement). TOC will be—100'above packer and 44' above GLM (top). a. Do not apply any queeze pressure on the tubing or IA after displacing cement to the IA. 13. POOH with CT while replacing voidage with diesel pumped down coil to maintain a full wellbore. 14. RIH with milling BHA to TOC @ ^'5970' MD. Mill thru soft cement, while taking returns from the tubing to tanks. Mill thru composite plug @ 6050'MD. a. Do not mill past 6070' MD- D nipple is @ 6089'MD 15. POOH with milling BHA and RDMO CTU. DHD 1. Perform a state witnessed MITIA(2,500psi) and perform a IA-DDT to confirm cement/packer are holding. • • Loepp, Victoria T (DOA) From: Blakney, Robert G <Robert.G.Blakney@conocophillips.com> Sent Wednesday,August 10,2016 11:26 AM To: Loepp,Victoria T(DOA) Subject: RE: KRU 2F-09(PTD 184-036, Sundry 316-403) Remedial Cement Squeeze Victoria, Is the information below sufficent?Or would you like more details? 2F-09 is an A sand producer that was completed in 1984. In June of this year a one way packer leak was discovered during well secure operations prior to a tree swap. The goal of this procedure is to remedy the packer leak using a cement packer squeeze. The NOB if successful is 65 BOPD. Cement packers have been very successful in Prudhoe(spe paper 106651),and in GKA we successfully pumped 1F-08 in 2013. The general procedure outline is as follows: SL(or DSL): Pull the 2 current plugs in the tubing. EL(or DSL): Set a composite plug just above the packer. PT tubing and plug SL(or DSL): Pull DV out of bottom GLM Coil: RIH to plug depth Pump 3bbls of 15.8#class G cement into the tubing and IA=^'100' plug Mill out soft cement and plug DHD: Obtain a state witnessed passing MITIA&DDT SL: Install GLD Thanks, -Robbie From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday,August 10,2016 10:58 AM To: Blakney, Robert G<Robert.G.Blakney@conocophillips.com> Subject: [EXTERNAL]KRU 2F-09(PTD 184-036,Sundry 316-403) Remedial Cement Squeeze Robert, Please provide some well history, background information,job scope and purpose. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 1 ~ge Project Well History File 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. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] 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 BREN VINCENT SHERYL MARIA LOWELL DATE; /S/ Project Proofing BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELl_ DATE: /'SI Scanning Preparation BY: ~ X 30 : . + = TOTAL PAGES BEVERLY BRE, VINCENT SHERYL~I~LOWELL Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~ YES NO BY: ~ BREN VINCENT SHERYL MARIA LOWELL DATE; II, I~.0~'/S/ ~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY; BEVERLY BREN VINcE~MARIA LOWELL '! ~: RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: lsl General Notes or Comments about this file: Quality Checked (done) 10125/02Rev3NOTScenned.wpd 2F-09 (PTD1840360} Report of failed TIFL Page 1 of 1 • • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, November 03, 2008 2:32 PM '~~ 7_` «~Z~~zt~~ To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2F-09 (PTD1840360) Report of failed TIFL Attachments: 2F-09 schematic.pdf; 2F-09 90 day TIO plot.jpg Tom, Jim Kuparuk gas lifted producer 2F-09 (PTD 1840360) failed a diagnostic TIFL on 11/02/08 and has been added to the weekly SCP report. The TIO prior to the test was 225/930/920. A leaking GLV is suspected. Slick line will troubleshoot the leak and repair if possible. Attached is a 90 day TIO plot and a schematic. "~ Please let me know if you have any questions. «2F-09 schematic.pdf» «2F-09 90 day TIO piot.jpg» Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~a~~~~~,~~~qq n~y t~~ 11/28/2008 r r~ ~ 1 ~ N ~ ~~ ~~ M ~y~1 \ . ICc~noc~Phi1lips ~-lasica, inc.. ........ . _- __ 2F-09 I API: 500292109000 V SSSV T e: Locked Out Ori Cc SSSV _. _ Annular Fluid: I (1826-1829 _ ' ~ Reference L Ref -- Last Ta : 6242 OD:3.500 ) i ~~r r~~ n~ro~ z~~i~ooo nn~„ u, Gas Lift MandreWafve 1 (1905-1906, OD:5.313) Gas Lift MandreWalve 2 (3472-3473, OD:5.313) Gas lift IandreVDummy Valve 3 (4900-4901, OD:5.313) Gas Lift MandreVVaNe 4 (6014-6015, OD:5.313) PBR (6056-6057, OD:3.500) TUBING (0-6100, OD:3.500, ID:2.992) NIP (6087-6088, OD:3.500) SOS (6099-6100, OD:3.500) TTL (6100-6101, OD:3.500) Perf (6242-6255) • KRU 2F-09 - - Casing String -ALL STRINGS - _ - - _ __ Descri tion Size To Bottom TVD Wt Grade Thread PROD. CASING 7.000 0 6550 6241 26.00 J-55 SUR. CASING 9.625 0 2861 2861 36.00 J-55 rnNDUCT~R 1~ nn0 0 1n9 Inca F2 5n H-4n '°. Tubing String -TUBING ~ " Size Top Bottom- TVD _ Wt Gracie Thread ~ j ' " ~ 1 ,~~ .gib i -ii i-~ EuE .RD 'Perforations Summary Interval TVD Zone Status Ft SPF Date T e Comment ~ 6242 - 6255 5966 - 5978 A-5 13 4 5/6/1984 IPERF 90 deg. Phasing; 4" Schlum. f Casin 1 6269 - 6314 5990 - 6030 A-4 45 4 5/6/1984 IPERF 90 deg. Phasing; 4" Schlum. ~~ - - -- Cacin~ € ; Gas Lift MandrelsNalves - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 1905 1905 MMH FMHO GLV 1.0 BK 0.156 1254 11/26/2006 2 3472 3465 MMH FMHO GLV 1.0 BK 0.188 1301 11/26/2006 3 4900 4779 MMH FMHO DMY 1.0 BK 0.000 0 11/25/2006 4 6014 5763 MMH FMHO OV 1.0 BTM 0.250 0 11/2Rl200R Other (plugs, equip., etc.) -JEWELRY De th TVD T e Descn tion ID 1828 1828 SSSV Baker'FVL' Locked Out 3/3/97 2.810 6056 5801 PBR Baker w/ 10' Seals 3.000 6070 5813 PKR Baker'FHL' Retr. 3.000 6087 5828 NIP Camco'D' Ni le NO GO 2.750 6099 5839 SOS Camco 2.992 6100 5840 TTL 2.992 General Notes _ Date I Note Perf (6269-6314) • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 3, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: a~ oq f,~r ~,L,L ~~' Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL)). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped October 27 and October 30, 2008. The corrosion inhibitor/sealant was pumped November 2, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any quesfioiis."~"~ Sincerely, Perry In ConocoPhillips Well Integrity Projects Supervisor -- • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off a Report of Sundry Operations (10-404) Kuparuk Field Date 11 /3/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top ofF date Corrosion inhibitor. Corrosion inhibitor/ sealant date ft bbls ft al 2F-01 183-183 88' 13.10 21" 10/30/2008 4.68 11/2/2008 2F-04 183-190 48" NA 48" NA 25.5 11/2/2008 2F-07 184-020 10' 3.00 22" 10/27/2008 4.25 11/2/2008 2F-08 184-021 SF NA 20" NA 2.55 11/2/2008 2F-09 184-036 18" NA 18" NA 1.7 11/2/2008 2F-10 184-040 22" NA 22" NA 1.28 11/2/2008 2F-12 184-043 20" NA 20" NA 2.12 11/2/2008 2F-15 183-172 93' 10.10 10" 10/30/2008 3.82 11/2/2008 2F-16 183-177 42' 5.90 9" 10/27/2008 1.28 11/2/2008 STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMIt~',~,,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate X Plugging Perforate Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 37' FNL, 1470' FEL, Sec. 33, T11N, RgE, UM At top of productive interval 1242' FNL, 1294' FEL, Sec. 33, T10N, At effective depth 1373' FNL, 1287' FEL, Sec. 33, T10N, At total depth 1415' FNL, 1285' FEL, Sec. 33, T10N, R9E, UM R9E, UM R9E, UM 12. Present well condition summary Total Depth: measured 6560 true vertical 6249 Effective depth: measured 6 4 6 7 true vertical 6 1 6 6 feet Plugs (measured) feet feet Junk (measured) feet 6. Datum elevation (DF or KB) RKB 125 7. Unit or prOperty name Kuparuk River Unit 8. Well number 2F-09 9. Permit number/approval number 84-36 10. APl number 50-029-21090-00 feet 1 1. Field/Pool Kuparuk River Field/Oil Pool None NoneORIGINAL 13. 14. Casing Length Size Structural Conductor 8 0' Surface 2 8 31 ' Intermediate Production 6521' Liner Perforation depth: measured Cemented Measured depth True vertical depth 225 Sx CS II 109' 109' 800 Sx AS III & 2861' 2861' 650 Sx Class G 250 Sx Class G & 6 5 5 0' 6 2 41 ' 250 Sx AS I 1 6" 9-5/8" 7" 6242'-6255',6269'-6314' true vertical 5966'-5978',5990'-6030' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., J-55 @ 6100' Packers and SSSV (type and measured depth) Packer: Baker FHL @ 6070'; SSSV: Baker FVL @ 1828' (Locked out) Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 10/4/97. Intervals treated (measured) 6242'-6255',6269'-631 4' Treatment description including volumes used and final pressure Pumped 238.9 Mlbs of 16/20 and 12/18 ceramic proppant into formation, fp was 2971 psi. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 297 191 885 1135 149 Subsequent to operation 631 558 1428 1146 157 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby?~y that the foregoing is true and correct to the best of my knowledge. / / Signed _.,~.,,,~ ~,2 Title Wells Superintendent Form 10~'0~ ~ ~/~ 0'~'~1~ Date /----.,,,/...~"----- f<~ SUBMIf IN DUPLIC,~TE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~, '~ '~WELL SERVICE REPORT '~' K1(2F-09(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-09 FRAC, FRAC SUPPORT 0925970636.1 10/04/97 PUMP "A" SANDS REFRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 2 (~) Yes O NoI (~ Yes O No DS-YOKUM JOHNS ESTIMATE KD1665 230DS28FL $1 50,520 $162,797 Initial Tb.q Press Final Tb.(:l Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Finai~uter Ann 800 PSI 1 300 PSI 740 PSI 500 PSII 1 50 PSII 200 PSI DALLY SUMMARY PUMP "A" SANDS REFRAC , WITH 238,900# OF UP TO 12.3 PPA 12/18 TO PERFS. LEFT 700# 12/18 PROPPANT IN PIPE. TIME 07:00 08:09 08:34 08:36 08:42 08:52 09:36 10:46 11:44 11:54 12:30 12:55 13:02 LOG ENTRY MIRU DOWELL FRAC EQUIP., LI'I-I'LE RED PUMP AND APC VAC TRUCK. HELD JOB SITE SAFETY MEETING. PRESSURE TEST TREATING LINE. INITIAL WELL 800 PSI. PUMP BREAKDOWN AT 25 BPM , 5234 PSI. PUMP I AND 2 PPA SCOUR STAGES WITH 5870# 16/20 PROPPANT. PUMi' i:;.iJSH AT 'i5 BPM AND 3278 PSI. SHUT DOWN FOR ISIP 1313 PSI. PUMP DATA FRAC AND FLUSH 5 TO 15 BPM AND 2929 PSI. SHUT DOWN FOR CLOSURE CALCULATIONS. PUMP 750 BBLS PAD , 5 TO 15 BPM AND 2951 PSI. PUMP 2PPA STAGE OF 11,559# OF 16/20 PROPPANT. 15 BPM AND 2916 PSI. PUMP 2 TO 10 PPA 12/18 PROPPANT AT 15 BPM AND 2165 PSI. PUMP 10 PPA FLAT STAGE OF 12/18 PROPPANT, 15 BPM AND 2165 PSI. PUMP RAMP UP OF 12/18 PROPPANT TO 12.3 PPA. GO TO FLUSH AND CLEAR TO PERFS. SHUTDOWN AND RDMO. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $819.00 APC $7,400.00 $7,400.00 ARCO $350.00 '$350.00 DOWELL $141,060.00 $141,060.00 HALLIBURTON $0.00 $6,208.00 LI'I-I'LE RED $1,710.00 $6,960.00 TOTAL FIELD ESTIMATE $150,520.00 $162,797.00 STATE OF ALASKA ALAS,_., OIL AND GAS CONSERVATION COrw_.,,SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate t Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage~ Alaska 99510 4. Location of well at surface 37' FNL, 1470' FEL, Sec. 33, T11N, R9E, 5. Datum elevation (DF or KB) RKR ]25' 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-9 Feet At top of productive interval 1242' FNL, 1294' FEL, Sec. 33, T11N, R9E, At effective depth 1320' FNL, 1290' FEL, Sec. 33, T11N, RgE, At total depth 1415' FNL, 1285' FEL, Sec. 33, T11N~ RgE~ 11. Present well condition summary 6560' Total depth: measured 6250' feet true vertical feet Plugs (measured) 8. Approval number 9. APl number 50-- 029-21090-00 10. Pool Kuparuk River Oil Pool Effective depth: measured 6467' feet true vertical 6167' feet Junk (measured) Casing Length Size Structural Conductor Surface 109' 16" Intermediate 2861' 9-5/8" Production 6550 ' 7" Liner Perforation depth: measured true vertical Tubing (size, grade and measured depth) Cemented Measured depth True Vertical dePth 800 Sx A.S. III 250 Sx Class "G" 109' 109' 2861' 2861' 6550' 6241' 6242'-6255' kid 6269'-6314' MD 5966' -5.978' TVB 5990 -6030' TYB .... ~- ..... , ~. ~' ......... 3-1/2", ,]-55, 9.3 #/ft., EUE Packers and SSSV (type and measured depth) SSSV' Baker FVL 1828' Packer' Baker FHL 6070' 12. Stimulation or cement squeeze summary Intervals treated (measured) 6242'-6255' (MD) 6269'-6314' (MD) Treatment description including volumes used and final pressure See Attached 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 662 306 0 1300 115 2500 2300 0 1300 322 14. Attachments Daily Report of Well Operations J~ Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ Zl~---- / (~- ~ ~ Form 10-4;0,~' l~I'ev.-12-~5 ' Title ~' ~'~' Submit in Duplicate PERF-INTERVAL COMF'ANY ,S'O._S TYF'E D~N$ITY PHAS'£NG DRT Y "L..'j J] D ¥OL. RATE F-'REYS .... -'" T'/'M T .f) (~'U :'"-..i. 27.:.~_. ~Z~ :m ~o / 222 o ,., ST_.` PROF' LC 0 N C :.4 COM.~iENTS' EFF.2LURR'r" /3/,,~ 10O MS: ~--00 EFF.F'ROF" ,~$,~ EFC) Fi;:,':'.,(:.: ;]RD. · G ~ -r 'r; f',_- .~., 'r . : .:,., S 10~7 F' El R' F-' FR ]'_C · L --Z :.t,'-;< - 0 F' ::.' · 5 HiN, ':.. '5 '-'.. :: N. _/o? 7 FL. UT:'-vC)i_/c''* ''':':'.. :-,, ,:. ;q.'2 V 0 L /;;: A '-.E ?; C: '" ':'::. $ ' ..~ roi -r ,.,,',, ~ G INA TOR ' RE'Vi£EI) BY · DATE' DATE · I::zNAL STATE OF ALASKA ALAS-~_, OIL AND GAS CONSERVATION COM'.,._.JSION 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 t Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator ARCO Alaska, ]:nc, 3. Address P.0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 37' FNL, 1470' FEL, Sec. 33, TllN, RgE, At top of productive interval 1242' FNL, 1294' FEL, Sec. 33, T11N, R9E 5. Datum elevation (DF or KB) RKB 6. Unit or Property name Kuparuk River Unit 7. Well number 2F-9 feet 8. Permit number At effective depth 1320' FNL, 1290' FEL, Sec. 33, TllN, RgE, At total depth 1415' FNL, 1285' FEL, Sec. 33, TllN, RgE, 11. Present well condition summary 6560' Total depth: measured true vertical 6250' feet feet 9. APl number 50-- 029-21090-00 10. 'P°°lKuparuk River 0il Pool Plugs (measured) Effective depth: measured 6467' feet true vertical 6167' feet Junk (measured) Casing Length Size Structural Conductor Surface 109 ' 16" Intermediate 2861' 9-5/8" Production 6550' 7" Liner Perforation depth: measured Cemented 800 Sx A.S. III 250 Sx Class "G" 6242'-6255' MD 6269'-6314' MD Measured depth True Vertical depth true vertical 5966' 5990' 109' 109' 2861' 2861' 655 Tubing (size, grade and measured depth) APR 2 I -5978' TVD Alaska 0il & Gas Cons. Commission -6030' TVD Anchorage _ 3-1/2", J-55, 9.3 #/ft., EUE 8rd IPC, 6100' Packers and SSSV (type and measured depth) SSSV' Baker FVL i828', Packer: Baker FHL 6070' 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] Hydraulically fracture A Sand with 25000# 20/40 mesh proppant and Gelled Diesel 13. Estimated date for commencing operation Apri 1 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Form 10-403 Rev 12-1-85 '~ioner JApproval 7 -¢,~Z ¢ NO. by order of g/// / / the commission Date ~~~ / Sdbmi~m tr~pli' ' '~ate P~ETURN TO: ARCO Alaska, inc. Post Of' Box 100360 Anchor~,~',~.e, Alaska 99510-0363 Telephone 907 276 1215 ARCO ALASKA, INC. KU PAi~U K OPE I~TI ONe3 RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 DATE: 08-16-85 TRANSMITTAL NO: 5254 ENGINEERING TRANSMITTED R~ECEIPT AND RETU~ ONE PRESSURE FINALS CAMCO lB-3 1D-8 1E-5 1H-6 1L-2 1L-5 lQ-6 lQ-9 2A-5 2A-5 2C-4 2F-7 2F-8 2F-9 2G-1 2G-1 2U-5 2U-6 2U-7 2U-8 2X-'l 0 OTIS 2A-2 'i 2U-14 ~ 2V-2 2V-5 ~ 2V-13 2V-14 '" 2W-7 ~ 3B-3 . 3B-8 i~EREWITH ARE THE FOLLOWING ITEHS. PLEASE ACKNOWLEDGE THIS TRANSMITTAL. PBU STATIC PBU S TAT IC PBU PBU PRESSURE FALL OFF PBU PRESSURE FALL OFF STATIC PBU PBU PBU PBU STATIC PBU STATIC STATIC STATIC STATIC PBU SIGNED COPY OF 04-21/22-85 04-29-85 04-26-28-85 04-29-85 04-24/25-85 04-28/29/85 05-07-85 05-12/13-85 04-21/22-85 05-05-85 04-24/25-85 04-14-85 04-19/20-85 04-13/14-85 04-17-85 04-29-85 05-02-85 '05-03-85 05-04-85 05-04-85 04-25/26-85 07-04-85 06-30-85 07-27-85 06-25-85 06-22-85 06-22-85 07-26-85 06-28-85 06-28-85 STATIC 'PBU PBU PBU STATIC STATIC PBU STATIC. STATIC RECEIPT ACKNOWLEDGED: DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON 'HOBI L* PHILLIPS OIL* NSK CLERK J. RATHMELL* ~pAE*- B. CURRIER Ci~EVRON* D & M* Anct~ora~e . STATE OF ALASKA* SOHIO* UNION* K. TULIN/VAULT ARCO Alaska, inc- Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-2 9-8 5 TiIANSMImm~r _ ~.-, NO:5~03 RETURN TO: ARCO ALASKA, INC. KUPARUK OPERATIONS ENGINEERING RECORDS CLERK ATO-1115B P.O. BOX 100360 AI~HORACE, ilk 99510 T RANSM ITTED RECEIPT AND SEQUENCE OF I-IEREWIT}[ ARE TIlE FOLLOWING ITE,qS. PLEASE A~.n~.~OWLEDGE RETURN ONE SIGNED COPY OF TItIS TRANSMITTAL. -2A-3 PBU- 2A-5 SBfIP -2B-1 PBU ~2B-2 PBU 2B-15 PBU- POST FRAC ~2B-16 PBU 2F-7 PBU- STATE 2-F-2~-.! PBU- 'n' SAND EVENTS PR ES SUI['~' '~ ' SAND 2F~-'3=~/PB U- STATE ic- PSU 2G-!2 PBU- 'A' SAND POST FP~\C 2H-15 ISBHP 2W-13 PBU- 'C' SAND 2X-13 PBU DATA 03-16-85 11-21-84 04-01-85 04-02-85 04-09-85 04-10-85 04-14-85 04-20-85 04-13-85 04-11-85 03-23-85 04-10-85 04-21-85 03-30-85 BAKER/ LYNES PRESc RE ,~ URE PORTS (ON.". COPY OF EACH) lA-1 PDU 04-23-85 lA-2 PBU 04-23-85 lA-2 PBU 04 -23-85 lA-5 BUILD-UP 04-23--3 5 lA-6 PBU 04 -23-85 lA-6 BUiLD-UP 04-23-85 IA-10 BUILD-UP 04-23-85 iA-10 BUILD-UP 04-23-85 SET DEPTH 7187' 7476' 7476' 6957' 8300' 8300' 8415' 8415 ' RECEIPT ACKNOWLEDGED: 3 PAE * 3. CURRIER* 2!IEVRO:~* D & M* DRILLING L. O'O[INSTON MOBIL * NSK CLERK DISTRIBUTION: W. PASItER EXXON PHILLIPS OIL* J. RATtlMELL* T OOL NO. 1722 1302 1512 1734 1719 2062 1508 1299 DP-.Ji[J-~;a uu ~ L~s Cor, s. Commission Anchorage STATE OF ALASKA* SOHIO* UNION * ~ T ~' n.TU~N/VAULT ARCO Alaska, Inc. Post Office,_ x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 f'."AI'E' AI':'RII:. t ''-~ I · '° ! ,s · ,...~.... TRAN;?H;r. TTAI_. NO- '"71 4"7. P A (:; F:- i F;F' ., ..... 'r.- F;I,', .......... . R,:. I.. ,::. T. F" T A .. f'! 0 t..,t L I""] I) c I.-.' n · ............ 5.Z i~, =~ ii T.)] Fj y..-Z ~ ~ ........... D I:1: I !.. 1.. T. i~ [.i '.L,..I , F'A.? HIEI;: ! ......IOHNSTON EXXON HOB;IL. F'H I I_ L. Z F';.'.-', OIL. HSI< C.'L. IERK ,J, RAI'HHE:L.L. ARCO Al~lk~,, In¢, i~ -~ Subsidiary ~t All~rllicFIichliel~Cornpari¥ ,,," AI:.A.SI< ,.:. 0 I--I l; r.j UN l ON I( .,~!j t.. I N/VAUL. T ARCO Alaska, Inc. Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 March 11, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 2F-9 Dear Mr. Chatterton' Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU5/L01 Enclosure If ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Pos! Offic~ ~x 360 Anchorage,?~,,laska 99510 Telephone 907 277 5637 Date: 2/05/85 Transmittal No: 4824 RETURN TO: -. ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P~O. Box 100360 ~. ~~horage, AK 99510 Transmitted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt PBU SURVEYS & SEQUENCE OF EVENTS --2X-7/ 8/16/84 . Gearhart ---~2Z-6/ 9/03/84 Otis 2X-6/ 8/16/84 Gearhart .... 2X-4/ 8/16/84 Camco ---2X-lv'~ 8/16,19/84 Camco --2V-5~'" 8/16,19/84 Dresser ~2V-2~ 9/07/84 Otis ~2F-9~° 8/28/84 Otis ~--2F-SW~ 10/08/84 Camco --2F-7/ 10/07/84 Otis ---2B-l~-'" 9/03/84 Otis ~-2C-5 ~' 8/17/84 Otis --1Y-13/ 8/16/84 Dresser ~lY-9/ 9/07/84 Camco ~lY-5z 9/14/84 Camco 1Y-5~ 9/06/84 Otis ~lG-6o' '8/25/84 Otis ~lH-4~ 9/04/84 Otis ~iF-12Z 9/09/84 Otis -~iF-9M 8/17,18/84 Camco <-lF-8z· 8/16,17/84 Camco ~lE-8/' 10/12/84 Otis ~lD-5~ 10/07/84 Camco '~lA-4/ 9/02/84 Otis ~--1A-3~ 9/02/84 Otis Receipt Acknowledged: B. Currier Drilling "HP 232" "KP 233" 9/06/'84 "SBHP" 9/05/84 8/17/84 8/16/84 10/1.3/84 lo/o7/84 "Static BHP" "PBU"" "PBU" "SBHP" "E Line" "Pressure Ealloff" DISTRIBUTION W. Pasher State of AK BPAE Geology G. Phillips Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION C¥_.~IlSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~x GAS [] SUSPENDED [] ABANDONED [] SERVICE [] . . 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-36 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21090 4. Location of well at surface 9. Unit or Lease Name 37' FNL, 1470' FEL, Sec.33, T11N, RgE, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1242' FNL, 1294' FEL, Sec.33, T11N, RgE, UM 2F-9 At Total Depth 11. Field and Pool 1415' FNL, 1285' FEL, Sec.33, T11N, RgE, UH Kuparuk River Field ., 5. Elevation in feet (indicate KB, DF, etc.) [ 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 125' RKB[ ADL 25657, ALK 2583 12. DateSpudde(J 13. DateT.D. Reached 14. Date Comp., Susp. orAband. 115. Water Depth, ifoffshore 116. No. of Completions 03/15/84 03/21/84 05/06/84I IN/A feet MS L 1 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 6560'MD,G249'TVD 6467'MD,6166'TVD YES [] NO [] 1828 feet MD 1400' (approx) .. 22. Type Electric or Other Logs Run D I L/FDC/CNL/GR/SFL/SP/Ca], CBL/GR/CCL, Gyro, Temp. Log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE iTOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED '16" 62.5# ~1-40 Surf 109' 24" 225 sx Cold Set II 9-5/8" 36.0# J..-55 Surf 2861' 12-1/4" 800 Sx AS III & 650 sx ~lass G 7" 26.0# J-55 Surf 6550' 8-1/2" 250 sx Class "G" & 250 ;x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25; TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6294' - 6314' 3-1/2" 6100' 6070' 6269' - 6294' w/4 spf, 90° phasing 6242' - 6255' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED See AddendUm for :racture Stimulation Summary, 27. N/A PRODUCTION TEST .. Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OI L-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ , Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED iv , R 1 2 1985 Alaska 0ii & Gas Cons, Commission Anch0raqe Form 10-407 GRU4/WC61 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE · , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, an.d time of each phase. Top Upper Sand 6179' 5910' N/A Base Upper Sand 6185! 5915' Top Lower Sand 6230' 5955' Base Lower Sand 6369' 6079' 31. LIST O'F ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge · Associate Engi neet 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". Form 10-407 ADDENDUM WELL: 3/26/84 4/21/84 4/22/84 9/10/84 9/17/84 2F-9 Arctic Pak w/250 sx AS I, followed by 55 bbls Arctic Pak. Rn 6.125" gage ring/JB/CCL/GR/CCL f/6450'-5300'. Rn gyro f/surf-2100' WLM. Re-run gyro f/surf-6400' WLM. 6467' PBTD Rn temp log f/6430'-6000'. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 0829 Hrs, 9/17/84. Dowell frac'd "A" zone Kuparuk perforations 6242'-6255' & 6269'-6314' in six stages per 9/10/84 procedure using 120° diesel w/5% P-20, H~0/gel w/50#/1000 gal silica flour. Pressured annulus to 1250 ps w/diesel. Test lines to 5600 psi; OK. Pmp'd 40 bbls 120° diesel @ 15 BPM w/3400#; 20 bbls H20/gel @ 15 BPM w/3220 psi; 25 bbls Ho0/gel w/1 ppg 100 mesh (1000#) @ 15 BPM w/3300 psi; 50 H~0/gel @ 15 BPM w/2400 psi; 25 bbls H?0/gel w/2 ppg of 12-20 sand (2000#) @ 9 BPM w/1920 psi;-57 bbls H?0/gel w/ 6 ppg 12-20 sand (11,400#) @ 9 BPM w/1620 psi. Flushed to 2600' w/22 bbl diesel/gel @ 9 BPM. Screen out @ 8:50 a.m., 9/17/84. Pmp'd 1000# of 100 mesh & ±6000# 12-20 in formation leaving ±8500# of 12-20 sand in casing. Load to recover 75 bbls of diesel & 177 bbls of H20. Job complete @ 0850 hrs, 9/18/84. 9/21/84 Ck sand fill inside tubing Perf's: 6242'-6255' and 6269'-6314' RIH w/sinker bars, tag fill @ 5484', POOH, RD. Well SI. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ADDENDUM WELL: 10/03/84 2F-9 RU CTU, N_ & surf equip, tst to 5000 psi. GIH w/CT while circ gel/~iesel @ .2 bbls and holding 250 psi back press @ 6000'. Begin pmp'g 350 scf of N~ & inc gel/diesel rate to 2.0 BPM. Injection press = 390~ psi & inc back press to 550 psi. Cont in hole to 6300' & pull back in tbg tail. Cont taking 50' increments of sand fill to PBTD of 6467', CBU w/gel/diesel. Shut dn N_ & chg to cln diesel while POH @ 1BPM w/3800 psi. Tota~ fluid pmp'd = 285 bbls. Total fluid returned = 345 bbls. RD CTU. SI f/sand to settle. Drillin~ Superintendent Alaska Oil & Gas Cons. Commission Anchorao~e Date ARCO Alaska, Inc Post Offic o~ 360 Anchorag~,~laska 99510 Telephone 907 277 5637 Date: 1/17/85 Trans~mittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.0.~'100360 y orage, AK 99510 ' . ~ /T/~nsmitted herewith are the following items. Please acknowledge receipt '"and return one signed copy of this transmittal. OTIS PBU SURVEYS 2W-8'''~' 1 / 08 / 8 5 lB-7 ' 12/14/84 2F-12 1/06/85 2F-5" 1/02/85 2W-§ ~'~' 1/07/85 . 1/07/85 1A-i" 12/31/84 lA-1 iii,~ 12/15/84 IA-i' 12/23/84 lG-5..-- 12/25/84 2F-3 ~ '12/31/84 2V-SA~ 12/16/84 2B-10 ~ 12/17/84 1Y-9-' 12/20/84 -~iC~ 12/10/84 2F-2 ~ 12/29/84 2F-15 ...... 1/05/85 2F-14- 1/04/85 2F-9" 1/02/85 2F-8- 1/01/85 API 029-21228 '029-2D616 029-21097 029-21073 029-21220' 02 9-05900 -- : 029-20908 029-21178~ 029-21084 ' 029-20564--Rf',~/~4~. ~-~-~ 029-21 O63 029-21048 029-21.090 029-21077 CAMCO PBU SURVEYS 1E-12 -' 12 /cat /14, 16/84 Receipt Acknowledged: Anchoraoo DISTRIBUTION B. Currier Drilling W. ~ashe= State of AK BPAE Chevron Geology Mobil G. Phillips Phillips Oil Sohio Union D&M NSK Ops. J. Ratkmell Well Files ARCO Alaska. Inc. ~ a subsidiary o! AtlanllcRichfieldCompany KUPARUK ENGINEERING Well Name: .~,~ ~D~. _ Transmittal # . ~[~ DISTRIBUTION NSK Operation Blueline Dr ill ing Bluel ine Geology/L. J. Bi/Se R&D Bluel ine D&M Bluel ine State B1/SE F.G. Baker Blueline ~ - - I '"[ G eology/Ken Film ECEIVE sign & return the attache copy as receipt ~~t~ ~':~'~,~ ~as Cons ' · ' - ncnorage / Return to: ARCO ALASKA, INC. ATTN: ?aoum m. w~vW ~ ATO-1115B P.O. Box 100360 Anchorage, AK 99510 OH F ina 1 KUPARUK ENGINEERING Date: Well Name: ~__ b~lD~ T:rau~mittal i~ ~/~ &? Date Run ~ DISTRIBUTION D~ B. A~ _ ~arns Union (Lamber~) Sohio (~s~) ~n P~l~ps / z/Sign & return the attached copy as receipt of data. Return to: ARCO ALASKA, INC. ATTN: P,q~,z.a m-W~-Tr~ ~3 ATO-1115B P.0. Box 100360 Anchorage, AK 99510 PBU ARCO Alaska, I~ · Post Offic~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 'V May 25, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT' 2F-9 Dear Mr. Chatterton' Enclosed are the well completion report and gyroscopic survey for the subject well. If you have any questions, please call me at 263-4944. Sincerely, O. Gruber Associate Engineer JG' tw GRU7/L71 Enclosure RECEIVED W/AY 1 ]984 AJaska Oil & Gas Cons. Commission Ar~horage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · , STATE OF ALASKA - WELL ALASK,~.~ .3IL AND GAS CONSERVATION (~_~.:MMISSION ~~~- COMPLETION OR RECOMPLETION"REPORT AND LO 1. Status of Well Classification of Service Well OIL [~(X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 84-36 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21090 4. Location of well at surface 9. Unit or Lease Name 37' FNL, 1470' FEL, Sec.33, T11N, RDE, UM tLOC.AT;~T Kuparuk River Unit At Top Producing Interval t VERiFhgP i 10. Well Number 1242' FNL, 1294' FEL, Sec.:3:3, TllN, RDE, UM tSurf._~_~! . 2F-9 At Total Depth ~ B. H. __~____~..~.i 11. Field and Pool 1415' FNL, 1285' FEL, Sec.:3:3, T11N, RDE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i ] Pool 125' RKBI ADL 25657, ALK 258:3 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 0:3/15/84 0:3/21/84 05/06/84I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 6560'MD,6249'TVD 6467'MD,6166'TVD YES [] NO [] 1828 feetMD 1400' (approx) 22. Type Electric or Other Logs Run DI L/FDC/CNL/GR/SFL/SP/Cal, CBL/GR/CCL, 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 109' 24" 225 sx Cold Set II 9-5/8" :36.0# J-55 Surf 2861' 12-1/4" 800 sx AS Ill & 650 sx (~lass G 7" 26.0# J-55 Surf 6550' 8-1/2" 250 sx Class "G" & 250 ,,,x AS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6294' - 6:314' :3-1/2" 6100' 6070' 6269' - 6294' w/4 spf, 90° phasing 6242' - 6255' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST , Date First Production I Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OI L-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 OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED UAY 1 ]984 Alaska Oil & Gas Cons. Commissio~ Ar, chorag~ Form 10-407 GRUT/WC21 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE : .., . .' , :.- '.' ', , ~-- ~.,..= . : .. G'EoI'.'0GiCMAF~KERS :" .. :~ '.:.':: ,: : ::;: FOi~'M~,Ti~N -i~ES~:s ,'.. -: . :~ ¥.'...:~: . NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. . Top Upper Sand 6179' - 5910' N/A Base Upper Sand 6~185' 5915' Top Lower Sand 6230' 5955' Base Lower Sand 6369' 6079' · 31. LIST OF ATTACHMENTS Drilling Hi.qtnry~ Comple~inn S~jrnmary~ Cvrnscopic Survey (2 eopies~ 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title P, rca D,"~ ~, ~, ~ n~ ~"~" Date .... ~.. /_/ / f' 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 pkoduction 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". F(~rm 113-4r)7 2F-9 DRILLING HISTORY . . NU 20" hydril and diverter. Spudded well @ 1445 hrs on 3/15/84. Drld 12¼ _ hole to 2881. Ran 40 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @2861'. Cmtd 9-5/8" csg w/800 sxs Artic Set III and 650 sxs class "G". Bumped plug w/1500 psi. ND 20" hydril & diverter. Instld 9-5/8 packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok witnessed by Doug Amos of AOGCC. Tst csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8~" hole to 6500'. Ran logs DtL/SFL/GR/SP/CAL/FDC/CN~ f/6462' to 2861'. Cont drig 8½" hole to 6560' TD as of 3/21/84. Ran 163 its 7", 26#, J-55 HFERW BTC csg w/shoe · @6550'. Cmtd 7" csg w/250 sxs class "G". Bumped plug to 3000 psi, floats held ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. Displ brine from top of well for freeze protection. Secured well and released rig @1800 hfs on 3/22/84. Performed arctic pack w/250 sxs Arctic Set I and 55 bbls of arctic pack on 3/26/84. DH128 4/16/84 ih RECEIVED MAY3 Alaska Oil &,Gas Cons. Commission .anChorage 2F-9 COMPLETION SUMMARY RU Dresser-Atl as/Sperry-Sun. ND 1 ower tree assy. Ran gauge ring/JB/CBL/GR/CCL to 6450'; good bond. Ran Gyro f/surface to 6400'. RD Dresser-Atlas/Sperry-Sun. NU lower tree assy & closed all valves. Secured wel 1. Accepted rig @ 0530 hrs, 05/05/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Perforated the following intervals w/4 spf, 90° phasing: 6294' - 6314' 6269' - 6294' 6242' - 6255' Ran 3-1/2" completion assy w/tail @ 6100', pkr @ 6070' & SSSV @ 1828'. ND BOPE. NU tree & tstd to 3000 psi - ok. Disp well w/diesel & Kuparuk crude. Dropped ball & set pkr w/2250 psi; held for 15 min. to test tbg. Bled to 850 psi. Tstd 3-1/2" x 7" ann to 2500 psi - ok. Bled to 1000 psi. Pressured tbg to 3500 psi & sheared out. Bled tbg to 750 psi; closed SSSV & bled tbg to 2000 psi - held f/15 min. Opened SSSV. Bled ann to 0 psi. Set BPV. Secured well & released rig @ 0900 hrs, 05/06/84. GRU7/CS21:tw RECEIVED M/I 984 ,~.~a_~? Co~s. ' 'nChorage AL. ASI<A ~ o ~ KEI....L.Y BI.ISH ING ELE~ ::= 1~. O0 F'"I" ' ~ ~ , , " .... ~ ~~:: ' · · :: :::: ,~:~:~:~:~::~:~:~i~:::,::: ::: ..... ':'~ :':. :: · : ~::;:: TRUE ~ COL!RSE COURSE: DOG-LEG :. · : · . ' ~ .;, .,'.,:.:.',:,:,:v,....,., ,,.., ..... . ':.;: : · ,. ,:, :.: : .:.:::::::::::::::::::::::::::::::::::::::::::::: ::::: :::::::::::::::::::::::::::::::::::::::::: ~~ g[7~f~[... VERT I L:~L. =.l~t..:[:~e~ I .I. uN [~ .I. R~:.L. F .I.t.)N ::::,1:::. V El..( .I. I Y REL. ~,Lil....AF(L. UUFd..~ .I. I~::::, VERT I _.AL ............. _,E _. [ I ON DEF'Tla DEF'"I'H DEPI'H DEG P'I I N DE'GRE:E:i~; DEG/'1 (")(') NF IRT'H/'.:;F I.I'T'FI EAS'T' / WE'.B"F ~' '~ .... 1300 .1. 29?. 99 1174.99 0 8 1400 1399.99 i274.99 0 .... ~.) (_) '.'[-4 '.:,' y. v'-~ T:~~ ............... 160 C) 15'? 9. ? 9 14 '74.99 () :I. ,:::, :1. 700 J. 6'? 9.99 1574.9'? 0 ::::: ~::, ......... :'i'8'~ .... :7'":'.:IT'.~'F/f":~8 .... 167:': 9'8 ' 0 :34 1. 900 189t~, 97 1774.97 0 50 2000 1999, 96 1874, 96 0 43 22 C) C) :219' 9.92 2 (')'74.92 :1. 4 :"-.': ';::' : --': C) (") :::_"2'.::;"? ::',/-, "':' .1. '2'4 :::',,f:, 2 J. % · ..................... -, , ' ........... ~--i;'i ...... · ~ ........ "24'00 '2~'~i~- 7'9'"' ..- 27z~. '~y I 5::: ..... z ,. 2374.75 2600 269"7;. 72 2474.72 ............ ':~0 ........... ~'/.-;'9 '.-:,q 'TT ........... ~:~ 7q~ ...... 2 80 0 27'? 9. '70 2 6, 7 4.7 () :290 C) 289'F'. 69 2'7'74.6 '::;' ~, 41.89 E 0.07 N 75 'q':, E c) t3 · .............. N--"-~-:7:::F"E- ................. 1.69 N 1.62 N :.,,,. ~,.'~ ~"'"'~w' ~;' . /(::, 1\1 (_). C)>::J~" :L. 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C):B ":21 42 ::~; 18, :t '~ E 4100 4 () 58.83 3 '5' :3 :3 . 8 :3 22 11 S ]. 5.8'F' E 4,~.C 0 4z:4.-'. ~/=., 4 ! 17. o6 ,~-4 10 '.-:; 1 .Z. :30 E 1. ~.:, o40, 1 ,:, 4400 4:33:_:: '76, 4208.76 ".:'.~=, 4 ::.:; 9 i'ir/ E 1.57 :381 1 1 "' ...... · :, 152, !::!.i::,!:::::; ::::::::::::::::::::::::::: :'::i::" :': :': '.: :' --'-4q-.~.~. 0.1:. ~. LFI .,:: ......... ~=, .:::,4...:,t)-E= :-:, 2,']:_'i ,: '-.=," '"~=~,: ~"=v' "~:=, .... ,'T..' ,:,, ,:: .... 'S 'P:-' 441 ~ ~,_-. .I. ,J: 4600 4. 51:3.54 .4:2: 4 7 0 () 4,S 0:2.2 7 4 4 7 7 .. 2 7 :-2'7 ................ q.:;~ 0~ ........... -46'90 .'5 z~ ..........,-,;=,o;-.~..'"=-'~'=' '~-.~,,. ,:, ............... -.. ,:,~ '" 4~:) 477:3.73 4653.73 28' ._,o0 .) 4:_.366 8,'4 4741 84 2:.--.: ........... ~ ......... ,~--"-'='=".:, ._, ...., ,-'~'.~ 1 ......... ~TS::,~f_T:-I. :" 1 - ......... ~=,'-"-' ._,=' ..-'-' O" ~_') ~-::; ....... C) zl. '::: 4 :}: /I-S.? :/F..:. 4 ::ii: :.Z ...... :::', 5:2:00 5; 12:1. 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(:~l<::-..Ed"~-Zl.~-~('~'?9~:~'":'~'~J:':'~:': .............................................. 0 F:' E: I::~ ~:~ "t" 13 F:~ -'.E~ h H I:Y C ====================== :::::::::::::::::::::::::::: .~ ,, ................. ~ :: ::. : :::~.:~'~..~....~:..~- :::::::::::::::::::::::::::::::::::::::::::::: KdE:I="i'H DI:F'"I'H DEF'TH DEG H I N DIFZ EiF:~IE:E:::~; DIE:G/1 O0 IqOF~"I"H / ::;C~U'T'H IFZ(.~:E;'I" / NE:E;"r E;EC:'i' I ON :iii;I:::'EI::;~F;~Y."'-SI...IN WEI._L. E;UI::;~VEYII',IG C()MI:::'AI'..IY PAGE 4 :::¥~?' ARCO ~LASI"::~, INC:. ~"' ALA:.::;I<A KEL. I....Y BUSHII',.IG I.':ilLIEV, -'= :l. 2j. OO F:'"I", .............................................. "~ 'i:~'!!?i~i;i?:::i:;::i?!:.ii:i?:?:i~i?: ............. . .......................... ,- , ........ 2, ' ?,iiiiiiiiii::!ii::!iii!?:::??:!i;:i::i!i?'?'~i!!:.:~::'~i:, 1 NT ERB~i~E'.~'.:; VAL. UEt.-:, I:- UR EVEN :1. 'L)¢J,O F I.:.:.E. I uF I'"IEA~LIRED ,KIEl "t H ::.::,¥.~,...,¥::,,..,:..':'~:~...~';;~'~>"~;~'~'~;:~""" '~'. :~.:. · .: :::: ·' M E]~'..'.'i;I_IRI.'~i; I3 V_ERT I CAL. VERT 'r CAL R E C ]"t::~I',I(:il...IL. AR C O (:} F;; );;I I NA'I"IE :iii; MD-'T'V i3 k..-'[< F~ T 'r (;:Al._ I]E F"TH D[ii:F' T H DE F"I"H 0 () ,, 00 - t 2!5. O0 O. 0() , 1000 999 · '?,'9 874,. '?.,"~ .1.. 41 Iq ........... .'2. GO C) ............. 'f ",-,,:z ~'""",..-, ¢.'. ........ ...... :, :: ::. : ::,' ................ 'I"~4 ,-,:Z..7 ........................ O-,'"'"?I- lq ::ii,'() 0 () 2999.6'7 28'74,6'7 13.26 S 4 ()() 0 :36:? 66.08 ' :384:1.. c-~ :i:: 22',ii!', ,. 42 ....... ,.. _ '" ....................... '-" ::,,D... ,:.'~ Z~ ................... ~0'00 4:~q'A~, ,=,z) z)7Z~.l.' ,_-,4 .............. ¢"='~" ~' .....S ..... 6 ~ 5 4:3 112:3 L::'7 :""!; 6000 ..,7.~,~, 4:3 .=~ .... ' -. . :,,..,60 6:249 34 ,::, 1 '24, 34 1:37'7, '.'-.'? 1 S N 0 R "r' H/' E; 0 LI 'T' I-'-I '1"FIE CAL..('.':LII_.ATI('_'d",I F:'F:!OCEDLIRE:_:i; ARE B(.',:.~!:E:D Oi',l "I"HE-' 1!-':: A :i~; ]" / W E :iii; 'T' (). O0 O. 0() 1. 11 W 0.01 4' <.!:.7 "E ............. 0. ©'~.'l:' :;ii:() ,, 64 E 0. :iii', :iii', :1. 15 ,, :24 E :3:3~ ? 2 177. 185. D ]: I:::' I:::' E R ii::. Iq CIE :30 R R E C'T i F)N INC, :2F-~ ( SEC: :Z-:3 T 1 1 N RgE );~iiii!~ili~::?.!i;:::;:.~.~:.::~i:.'>: COMF'LrTA'I"I ON I]A TEl ....... ~ ................ ~, .......... &~...~ ...... ~ .............................. ============================================================= ........................................... I<I...IF'AF;,,:UK F' I ELD AF:'R II .... A L. A :.:_'; K A ,.JOB NUMBER AK--BO-4C)029 K E L L Y B U:3 H I N (3 E L.. E~ V. =: ] 25.00 F:: ]". 0 F:' E R A 'T' 0 R'-:E; A M E C M ][: - 'T'V D I F: f::' I.E R E N C 0,00 0.00 .:: : :::: :.~ (). () 0 0.0() 1225 1225. O0 1100. O0 .1. 325 :1. 325. O0 ' 1200. O0 .............. I~._, ....... t-4.7..:~'70'0- ...... y37:i.]iO-i:i':'0d- .......... "'-""" .~l 2.=~ ......... .1 ..:,~ .: 1 _ ._ 0 () 1. 40 16'.7-: 5 1625.00 :1. 500. () .......... '.=, 725 .... . :t 7.:._ J. . O0 .1. 600. 1825 1825. O0 1700, O0 1.8() N 0..56 W 0.01 0.00 I./_-,4 N C:.41 W ().0I 0.00 "i":-;.'!:, ::?Ei ............... 0 22 1. ',.:i: 1 N (). 14- E (). () 1 () ,. ()() 1. '70 N (). f::;,/-, .1.. 62 N 1.45 E .................. 0']' ~-'I ........................... O';'OL1 ....................................... .' · 1.65 N :2.4'7 E 0.02 0.01 MIL-EASUREF~ VERT I CAL VERT I CAI._ RECT'AIq(':~I...IL. AR CF)OF:~'.I] I NA'I"ES MI:I.---'T'Vi] D I.:::: F' "1' H .l[.':l E P T H D E P T H N Cl F:;.: 'T' H / :i::; L')I..I 'T' H Ii!!: A !~ ]' / l.,,J I~i' iii 'T' Ii I i:::' i:::' I!i: R E N C E :3.7'7 E 4,'P5 E 5' L.'.,,'.'-: E 7. I 0 'ii:' ,, 44 E II. 60 E 1:..:.:. 58 E '1.5 .... ~; E · . .., (). 0:::3 0 ,, 01 0.04 0.0 I ......... 0% 05 .................................. 0 ,, C:,'::.;' (). ()4 C,. 1 ,':.!:, () ,. ()7 ....... ,n"....,....." ,":,.'o. ........................................... 0?0'8' 0..2.-" 6 0, 04. 0 '-'"' O.C.,. V E:R T' T (': A I .... C (:)F.< I::< E C 'T' I 0 I",i 28.'25 2825, ()0 27()() ,, ()0 :1. 2 ,, 84 :ii!; .i. 7 ,, 86 '2'?:25 2'::.>25. ()0 "28C)('), ()0 :l ':ii:, 72 S :1. i?, ::ii: .l ............. · "'30~'25 ................ :30~':'0'0 ............ .~,'~. 0'0", 0'0 ................... I3': 7.6 :_-'3. .... 21', '18 3125 3125.00 3000.00 :1 '.~). 17 S 24. 12 E .................... 0'-.-2..":: CT2t.T.T-- E (). ::::0 () ,, 01 E O. :3:1. 0 ,, 0:1. 'E ..... : 0". 3z~' O':"03' ..................... E 0.55 0.21 3226 :3225.00 3100. O0 31. ()'.:~ 34:_--:0 ::-::4::::.'5. ()() ::.:.': :_--: 0 () . ()() '71.4:3 35:34 :35; 2. 5.00 :34. (") 0.0 () 7; 5.9:1 :3~;3~ ..... 3625. O0 ........ 350'0 :' 0'0 120, 99 :374:3 ~72._=, · 00 :--:6(:)0, O0 148. ,1. 0 S 79.51 E , ~ .. '.!!i;F'I;SF:;:RY--SLIN WI"'i]....L. :ii;;LIF:;:VF2Y I N(} C(3MF:'ANY PAGE 7 ..... .... :" ........ 'i!'?::"?: '"'[':!i" ....... ....... "' ....... ':?'" :;'~ ......... : ANC]ii-:ii]IRA(3E ALP~Si-:::~4 : .:.:¥:.. .... : . ...................................................................... ~..::¥.¥... ARCO:' :A:Eii~Sg:A,:. ]:NC, : · : : : .:..,,:: ,' :::::::::::::::::::::::::::::::::::::: :: .:,:1:: :i,ir::::i: ::: : :::'. : .... T'":i[]i'F'A~i]'i:i!i-'i--']~'E[~''''':~: ......... '"~"":=~-": ................................... ~:?'"':::¥ ...................... ' ................................. ;!.~P'i~:~'E'"').;:':3 ,, !119:34 ....... dOB I',ILIMBFL'F~ AK-BO-4()():2'.-.-~ AI....ASI<A I<EL.,I....Y BI...I:!ii;H I N(3 E/...I.:.'ilV. = 12.5.00 I-'T, (] P E R A 'T' ...,~ ............ :.....-.??....~ ............. ~.~:?,..,?::.:. : : ::,: .::..!i~..~i~i....-..{~i::!.:,~-~',- ......................................................................................................................... ........................................... INTER~~i~?VALLE.{..S; FOR EVEN 100 FEET' OF SLIB-SEA DEF'TH 'l ~]_IE '._qUB-:=';EA TOTAL M [ii: A S I_1R E [) V E R "r I (i: A I._ Ii E F' "1' H D ii: P T H ..,;.~...,~ ,~ ........ :,,.,, ..?..~ ......... ~.~.,,.~.~?~ ........................ ~.~.~,,..~,.~. :3849 3825. O0 · ....'. ,,,._ ,~ ,-, -.' o. 00 zFL'Ej-,..:, -4:U...:..:_,, 41 '7 .1. 4 .1. 25. ()0 · "'~ .'"1 I-,:; # .. 428 () 4...'-.c. .... F) 0 VERT I CAL REC TANF:iL.IL. AF~ DEPTH IxlCIR T H / :::;O LI"I" H .:..' ~'t~'?'~' ::F':':!?:?~': ' ........ 3700.00 178.76 S 96.04 ::~:800 , O0 ~,"" 1 '""~. 96 :.'_-3 .1. 1() . :1.0 , :~':-~'~ .................................. '-'-="' ...... ~"' "'";' ......... :22":"q: .-:, .: ¢2 (.}. C) (..) ......]) (..I. ,.-.,,:::, .::, ]. 4 () ()() ,, ()0 2S;'0 ,, 48 ::i; ,1. :3 ::ii: ,, :31 41 ()0 ,, (")() :3:.3':.~, :34 :iii; 14:3. ():':i COOREI I I'q A'T' E fi; MI"-'l"V [) '.3 T /W E ~i!i; '1" l) I F' F E Iq: E I',1C E 4,S. 57 ~gt.]' :~.~',~5,]:..~.' :~0, O0 ~7'7, ,.:~.Z~ ..~ '"='- ....... '-'" :,._,, '~ " 157 4.501 : 44.~,.,, O0 4~00. O0 4:2.'.:4 '--'-'-"' ':' · _ 6 E 76 i () 4612 4525.0 0 4.400.00 474.14 S 159.21 Ii.:.'. 87.8 · '=' ~ ' ~' ( .-,' 'T-, . ' ~ :.'...i .1. !:::,',:~. (::,',:::: '"E.'.'-. ..................... !i:i.~i]T,"V ::ii: 47..-' ..., L-T. ~::,,.- .... (..~ <..) -q:..., (..)L), (.) 9 .... ..'..:,, --'F :: ' ...................... ' ........... ~ ..... " · ,'-~ 1'7 I"- '"'",' ~- 4839 4 7.c. .... () 0 46 (') 0, 0 (-) .'", / .:~ ,, 7:3 :::; :1. 6 (-), 1 ',.'3 E 1 ~ 4,05', 495 ":. :: '-"-'=; .................. 4,..-:,.... .... 0('~ 4'7()0 0c~ ,'-, ::: :':: . :'::~':> '.:i; ,1./,C~ '.:)7 E ~2'7 ..=.;2 517,,-:' ~'"'-'= .. '" . :...:... ,~ v .- ._,. O0 4900, 00 739.9¢] .?; ,1. 61.96 E 154.11 529'2 ...?;1''''.=;.~ ..... 00 5000 00 793 17 '._:; 1,'_-,2 ,:,:Z'-'" E t67, 42 '.:" =' lq::',2 F'~, Oc) r-'q:2 c~(] ..... ,1 ? .................. '.:.'~0 ,1.. 2'7 S ,1. 65. :3 () E `1. '.-} 4.7':i'-". D/:, :--; :3 54:25.00 5 :}.", 00, ~"~('-~ '? !!54. ',i.:.: :3 '.:.'-i; 166.9 :l E :.2 ()::. 2:3 ..... '-- ......... ~,:~"~ ........'5525, O0 ............... ~D"~'OL'T .................. ~0".:~7:4 ~ $ ~'Z:i:~: -'.:..' :' -.:'-.::::::. · . :: ii: '- '".. : :. :. ': .. :, . . . . ii .... . ....... · -,-.~o .~,o..'~. ~,.5.)0 00 105~.}.51 S 170 05 E :!ii; F:' l.'C f:~: I::;,' Y .... :ii;l.. 2F'-~ ( SEC: ...... '.:.'"'" _": ...... "~':'i'~.':~": ............ 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'~ ~ . ~,,, # :::': :: ~ : ::i:: :': ::. : '~:: · .~ . ~-,I~ .......... ........... :~:': :~=','~",~.~ ......_,; 00' ' ........ :~;~"S:~iii:.x:~': :i:'iO:' 'r'~-.'-'~'-' .':"-,,=rn-' ..................... ~=' ............................ .t 7'./..: ....... ~ .................................. .~. E ...:.'-~'~ (..~. ...... '~ .T.~ ,.S :2:0 :i~.: /: 025.00 5'P 00, 00 ~. 2 ./:, :3.7 '.::~ S.'; .t 7 :ii', ,, 'P !5 IS ':2 :i.':: ::ii',, 2 :.:: :1. :2: ,, 2 '7 /=, 4.'2'..(3 /-, 1 ~'""':' c)0 /... 0 ("~ ~"~ 0 (") 12:1 '"'""'~ ......... ~"'~'"' ~'~,~.,~ '~?~'t- ~"~1' '"~ ...... ~""'~ ~"~'¥~'~ ~' ' .... ............... '~"'!1:~*%~'"' ~ ~F'l'?"~'~'-~'~-"~'~:'~'"'"~'~'~4'?~'~''' ~ "'~'~"?~"~'~"':~""~'*~'",~ ........... ~"~'~': ....... , .. /:,5~.0 /:,24~, 34 ~. 1.~:4 , .'.'_::~:t 1:37'7 , '.-.-~ 1 S :..:. , THE I',I[:_"'~:~F~E::i'_::'T' :::::('-~ I='KI 3"1" P'I][::I ( F:'I::~:Cd¥1 [:~:~:~0:1.' I...l'.i!i: _"IF:' I::::I...II::;~Vi'-'.~"I'I_.IF~I.'!i: ) F:'L) :1: Ixl"l":S :.BF:'I;::-.RI::;:Y.....SI...IN t,,JE:'l_l .... :_";JI::;,'VI::'YII",IG COMF'ANY ARL. U ~LA;:.K.A, INC, ;-.-,, _¢.,, :~ -. ,::,.,., ~F , (,.Et., ,~,¢ T11N RgE) A I_ ~ S K ~ MARI'::;EF~ TOP OF UF'F:'ER S~NI] BASE OF LIF'PER SAND I~{A'.E;E OF I...ONE:I::;: :¢~;t...11::~ E Y 0 E I::' T I'"I ... , ,,, :.:.. . I"Y"FRO'M" LINEAR EXTRAPOLATION 'BELOW DEEPEST STA'TION. ' ....................................................................... ...... '-:'- ) C:FI~PI ITER I:'RFuZiRAN - :DF'ERRY SI I1',1 THREE D I MENS I CiN~L RAD I 1_1'.3 I"'lF F:i IRVATLIRE ' .... ::::::::::::::::::::::" .: DATA C:ALCLILATIL')N AND INTERF'OLATIOI',I BY RAI]II...I:E: CIF' CLIF:VATI_IRI.::' ~ "CI_"II~TP'~JTATI ON 'DATE APR I L ~,:,, ]. '.;'84 DATE: Cd : ._lOB NUhlBER. KELLY ~D~Hi~NG~?EL..E~, = 12~, O0 FT, :::: .::::::::::.::::: . ,.:::;:: ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40029 Well: ~2F-9(SEC 33 TllN R9E) Kuparuk Field North Slope, Alaska Survey Date: April 20, 1984 Operator: Samec Scale: 1" = 500' TRUE -50~3. O0 N IRTH Surface Location 37 FN~ 1470 FEL ~ 50$.00 1390.31 @ S 7° 39'E . - 000. O0 l~ 656o -15~, O0 HORIZONTfiL PROJECTION ARCO Alaska, Inc. Our Boss Gyroscopic Survey Job No. AK-BO-40029 Well: ~2F-9 (SEC 33 TllN RgE) I4up~rn~k Field North Slope, Alaska Survey Date: April 20, 1984 Operator: Samec Scale: 1" = 1500' 0.00 500, O0 3000. O0 4500. O0 6000. O0 7FOO. oo ~ 1390.31 @ S 7° 39'E 15~30. O0 VEBTICGL PFIOJECT!ON Suggested form to be inserted in each "Active" well folder to d~,eck for timely compliance with our regulations. Operator, ~ell Name and Number Reports and Materials to be received by: /~-~ d~.~.~ Date Required Date Received Remarks -- · Ccmpletion Re~ort Yes '. We11 History Yes -. Sarr~les .Core Chips - ~/~ ~ ~- .., ~/< Core D~_~scription Incl±na~ion Survey Dire~ional ~ey 7~. ~ ~ Drill St~ Test Re~s ~ -- , , Digitiz~ ~ta ~~ , , ARCO Alaska, I~ Post Offi~"~"Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Hay 15, 1984 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-9 Dear Mr. Chatterton' Enclosed is a Subsequent Sundry Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, . Gruber Associate Engineer GRU7/L46'tw Enclosure If RECE!V D MAY 1 7 i9 4 At~,.a Oil ~ G~-3 Cons. Commission ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK,~._.,~I L AND GAS CONSERVATION ,._.,.MM ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 37" FNL, 1470' FEL, Sec.33, TllN, RgE, UN COMPLETED WELL 5. Elevation in feet (indicate KB, DF, etc.) 125' RKB 12. 7.'Permit No. 84-36 8. APl Number 50-- 029-21090 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-9 11. Field and Pool Kuparuk River Field I6. Lease Designation and Serial No. Kuparuk River 0il Pool ADL 25657 ALK 2583 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 Abandonmentsee20 AAC 25.105-170). RU Dresser-Atlas/Sperry-Sun. ND lower tree assembly. Gyro f/surface to 6400'. RD Dresser-Atlas/Sperry-Sun. Ran gauge ring/JB/CBL/GR/CCL to 6450'; good bond. 'Ran NU lower tree assy & closed all valves. Secured well Accepted rig @ 0530 hfs, 05/05/84. ND tree. NU BOPE & tstd to 3000 psi - ok. Perforated the following intervals w/4 spf, 90° phasing: 6294' - 6314' 6269' - 6294' 6242' - 6255' I Ran 3-1/2" completion assy w/tail ~ 6100', pkr ~ 6070' & SSSV @ 1828'. ND BOPE. NU tree & tstd to 3000 psii ok. Disp well w/diesel & Kuparuk crude. Dropped ball & set pkr w/2250 psi; held for 15 min. to test tbg. · Bled to 850 psi. Tstd 3-1/2" x 7" ann to 2500 psi - ok. Bled to 1000 psi. Pressured tbg to 3500 psi & sheared out. Bled tbg to 750 psi; closed SSSV & bled tbg to 20~0 psi - held f/15 min. Opened SSSV.' Bled a~n to 0 psi. Set BPV. Secured well & released rig @ 0900 hfs, 05/06/84. MAY i ? 1984 14. I hereby certj.f~//that the foregoing is true and correct to the best of my knowledge. ~,/~ ,~r. lm~o~a~~,~, ~:~ /~~~ ~- A~ea D~,,,,ng Engineer ~' Date Signed Title The spac. b/~4~,ssion use Conditions of Appr~ if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 GRU7/SN19 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING Well Name: Transmittal .Log DISTRIBUTION NSK Operat ions Dr il 1 lng --~ate of gl{" Blueline Blueline Film ~ Blueline & Sep~ ARCO Alask.~, Inc,_ Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 April 15, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Enclosed are the Monthly State Reports for the following wells: 2B-9 2F-7 WSP #3 2B-10 2F-8 WSP #9 2B-11 2F-9 WSP #12 2B-12 2F-10 Hemi Springs State #1 2A-1 ~SP #1S Thank you. Sincerely, / Actin~District Drilling Engineer JBK/SH1: ih ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany - . STATE OF ALASKA ALASK~,~IL AND GAS CONSERVATION (~..~vlMISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well [~ Workover operation [] 4. Location of Well at surface 2. Na~dp~_t~ka' Inc. 7. Per~_N~6 3. Amir.esso. Box 100360, Anchorage, AK 99510 8. APl N~r~r21090 50-- 37' FNL,1470' FEL, Sec.33, TllN, R9E, UM 9. Uni,t, or Lease~Na~e. muparuK ~lver Unit 5. Ele~a~n ~g~e~ (i~c~e ~:~F, etc.) I 6. L~Oe~_i~i~n and Serial ALK ~§'83 11. Find and Pool KPK River Field KPK River Oil Pool March ' 84 For the Month of ,19 '12. Depth at end of month, footag~ drilled, fishinq ~b6,d~ctional drilling probl~m~spud date, remarks Spudded well @ 144b hrs, 0~/15/84. Drld 12~" hole to 2881'. Ran, cmtd & tstd 9-5~8" csg. Drld 8½" hole to 6500. Ran logs. Cont drlg 8½" hole to 6560'TD. Ran, cmtd & tstd 7" csg. Displ brine from top of well. Secured well and released rig @1800 hrs on 3/22/84. Performed arctic pack w/250 sxs Arctic Set I and 55 bbls arctic pack on 3/26/84. 13. Casin~ or liner run and quantities of cement, results of pressur9 tests 9-5/8" 36¢~ J-55 HFERW BTC csg w/shoe @ 2861'. Cmtd w/800 sxs Arctic Set III and 650 sxs class "G". 7" 26~f J-55 HFERW BTC csg w/shoe @ 6550'. Cmtd w/250 sxs class "G". 14. C. oring resume and brief description N/A 15. Logs run and depth where run DIL/FDC/CNL/GR/SFL/SP/CAL f/6462' to 2861'. .1 6. DST data, perforating data, shows of H2S, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 'SIGNED--- --~///~~~'Y~- TITLE Area Drilling Engineer DATE ~/~~ NOTE--Rep ~5~r~' on~/hi~/zf~r/ iSrequired for each calendar month, regardless of the status of operations, and must b~/'led/in d~plicat, with the AlaSka Oil and Gas ~;onservati~'~ommission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 HILL/MR133 Submit in duplicate STATE OF ALASKA ALASK,,..31L AND GAS CONSERVATION,.~.~, M MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL E~X OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 84-21 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21077 4. Location of Well Surface: 506' FSL, 1561' FEL, Sec.28, T11N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 127' RKB 12. I 6. Lease Designation and Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-8 11. Field and Pool Kuparuk River Fie]d Kuparuk River 0il 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 Casin. g [] 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, inGluding estimated date of starting any proposed work, for Abandonment see 20 AA(: 25.105-170). RU Gearhart/Eastman-Whipstock. Ran GR/CBL/CCL. Ran Gyro, RD Gearhart/Eastman-Whipstock. Secured well. Accepted rig ~ 2200 hfs, 04/01/84. ND tree. NU BOPE & tstd to 3000 psi- ok. Perforated the following intervals w/4 spf, 90° phasing: 6103' ~ 6105' 6093' - 6103' 6083' - 6093' 6073' - 6083' 6050' - 6060' Ran 3-1/2" completion assy w/tail ~ 5896', pkr ~ 5864' & SSSV @ 1797' , · ok. Disp well w/30 bb]s diesel and crude oil. Dropped ball & set pkr. & released rig 8 2130 hfs, 04/02/84. ND BOPE. NU tree & tstd to 3000 psii- Opened SSSV. Set BPV. Secured welll 14. I hereby c~that the foregoi%ue and correct to the bes' of my kn°wledge./ Area Dri]ling Engineer Signed / ~/~./. ~~ Title . Da~e. Condition~of AOpro~if any: By Order of Approved by_ COMMISSIONER the Commission Date Form 10-403 GRU6/SN42 Rev, 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ( REV. I RENUMBER ALL WELL:--._.~PER NSK DRILLING. (180° ROTATION OF NUMBERING ) REV. 2 CHANGE ALL ELEV.; CHANGE BASIS OF ELEV. NOTE 05 4O O6 92.0 28 27 BASIS OF PAD ELEV. I$ 'I".B.M. 8 3 - 2~ -,4, 9. O.G. ELEV.-tNTERPOLATED FROM DWt S R" 8 F'- 12-3030,~ '- PHASE II A~-BUILT ~ .- CONDUCTORS 9-[6 DRIL~ .,.IT E AS '-"BUILT WELL 9 WELL I0 3O :;'.F CONDUCTO LOCATIONS.' Y-- 5,948,8'~6.91 X= 517,761 37' FN L Y= 5,948~787.73 X= §17,771.51 96' FNL WELL i'1 Y--5,948,72B.56 X'- 517,781.64. ,_.~__~-;_15 5' FNL {' ~.2~-X-;' 517,791 81 k.__.~- 214' FNL ' WELL 13 Y =5,948,e22.3i X= 517,516.04 261'FNL WELL 14 Y= 5, g48,681.51 X= 517,505.83 202'FNL ·ELL 15 Y=5,948~740. 50 X= 517,495.75 143'FNL Y = 5,9~8,799.60 X z 517,4~85.54 83'FNL Wm L 16 '! ,t RS Lat. 70° 16'17.10 15" Long, 149° 51'?_2.870" 1470' FEL L~CATED IN PROTRACTED SECTION 33 TOWNSHIP II N., RAI~GE 9 E~ UMIAT MER. ~: ,BASIS OF LOCA~ON IS ~NUME~S C~F-Z N.E.~ MIDDLE PER LHD ASS~IATES. Lot. 70° 16'1~. 5197." Long. 149°5l' 22.58C) 1460' FEL l_~t. 70° 16'15.9 370" Long. 149°51' 22.289" 1450' FEL 22 DAVID FILUCCI 5276 I.~t. 70°16' 15.35 44'' Long. 149°51 '2 [.997" 1440' FEE L~t.70° 16'14.89 80" l_~ng. 149° 51 '30.07-9" 1716' FEL , Lat., 70 Lo ng. 149° 5l' 3 0.322."I 172 6' FEL Lat. 70°16'1,6.0610" i Long. 149051 30.611' { 1736' FEL Lot.TO° 16'l 6.64?.6" Long. 149°5 i'30.905" 174'6' FEL 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~ h¢l' DIRECT SUPERVISION ANI::) THAT ALL DETAILS ARE CORRECT AS OF NOV. 5,1983. ARCO Alaska, Inc. Kuparuk Project ....... -~North..S!oDe Orillln9 '--_._.__D~_RI LL SITE 2.F 'P 'C 0 N D UCTOR--AS"-B tJl-~T LOCATIONS date' 11.9'83 scale' I": 400' 2F-9 DRILLING HISTORY NU 20" hydril and diverter. Spudded well @ 1445 hrs on 3/15/84. Drld 12¼ hole to 2881. Ran 40 jts 9-5/8" 36# J-55 HFERW BTC csg w/shoe @2861'. Cmtd 9-5/8" csg w/800 sxs Artic Set III and 650 sxs class "G". Bumped plug w/1500 psi. ND 20" hydril & diverter. Instld 9-5/8 packoff & tstd to 3000 psi - ok. NU BOPE & tstd to 3000 psi - ok witnessed by Doug Amos of AOGCC. Tst csg to 1500 psi - ok. Drld FC & cmt, tstd csg to 1500 psi - ok. Drld FS and 10' new form. Tstd form to 12.5 ppg - EMW - ok. Drld 8½" hole to 6500'. Ran logs DIL/SFL/GR/SP/CAL/FDC/CNL f/6462' to 2861'. Cont drlg 8½" hole to 6560' TD as of 3/21/84. Ran 163 jts 7", 26#, J-55 HFERW BTC csg w/shoe @6550'. Cmtd 7" csg w/250 sxs class "G". Bumped plug to 3000 psi, flOats held ok. ND BOPE. Instld 7" packoff & tstd to 3000 psi - ok. Displ brine from top of well for freeze protection. Secured well and released rig @1800 hrs on 3/22/84. Performed arctic pack w/250 sxs Arctic Set I and 55 bbls of arctic pack on 3/26/84. DH128 4/16/84 ih RECEIVE!) APR ! 9 198~ Alaska 0~1 & Gas Cons. ~ummisslo~t Anchorage KUPARUK ENGINEERING · D. Fay Allison 'z7/-/'~,-~$ WELL NAME' DATE' see below Transmitted herewith are the following- PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Description Date .?E I PT ACKNOWLEDGED: PLEASE RETURN RECEIPT TO' . .~ 0~ ~ Gas C.~Ds. Cam~m~oD_ DATE· ARCO ALASKA, INC. ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. -99510 KUPARUK ENGINEERING Well Name Transmittal ~/ ~'? / Date Run ~ DISTRIBUTION - NSK Operat ion Drilling Geology/L. J. R&D D&M State F.G. Baker D.B. Schafer G eology/Ken Blueline Blueline B1/Se Blueline Bluel ine Blueline Bluel ine Film Alaska Oi! & ~as ,"~ uua8, " ' ~Off)lDI8$[Or, & retum the ~tt.ched copy ~e receipt of Return to: ARCO ALASKA, INC. ATTN: D. Fay ALLISON ATO-1115B P.O. Box 100360 Anchorage, AK 99510 OHFinal MEMORANDUM State of Alaska ALASKA ~IL AND GAS CONSERVATION COMMISSION . /'~ti ~ TO: C.V./C~~rton .DATE: April 9, Chai~w' - v~"°~ ~g. ~i ~/' FILE NO: D.4I. 13 THRU: Lonnie C. Smith .' ,~- Commis s loner TELEPHONE NO: FROM: Doug Amos ~ Petroleum Inspector 1984 SUBJECT: Witness BOP Test at ARCO's Kup. 2F-9 Well, Sec. 33, TllN,RgE,UM, Permit No. 84-36 on Parker Rig No. 141. Saturday, March 17~ 1984: i traveled this date from Doyon Rig No. 9 to Parker Rig 141 toT~itness the BOP test on ARCO Kuparuk 2F-9 well. The BOP test commenced at 12:00 am and was concluded at 3:30 am. The Upper pipe rams failed, but were replaced and retested during the course of this test. I filled out an AOGCC BOP test report which is attached. In summary, I witnessed the BOP test at ARCO's Kuparuk 2F-9 Well. Attachment 02-00IA(Rev. 10t79) ARCO Alaska, In Post OffiC'[~"'~ox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 13, 1984 Mr. C. V. Chatterton Commi s si oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 2F-9 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to complete this well with our workover rig. Since we expect to start this work on April 20, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, ~~e aB~~~?~ rea l'ng Engine JBK/GRU6L29: tw Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASK-~.OIL AND GAS CONSERVATION -~,~'MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER FXIX 2. Nameof Operator 7. Permit No. ARCO Alaska, Inc. 84-36 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21090 4. Location of Well Surface: 2253' FSL, 166' FEL, Sec. 7, T11N, RgE, UM 5. Elevationinfeet(indicate KB, DF, etc.) 125' RKB 6. Lease Designationand Serial No. ADL 25657 ALK 2583 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 2F-9 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (~u.bmit in Triplicate) (Submit in Duplicate) Perforate i~]~-J Alter Casing [~ Perforations [] Altering Casing [] Stim u late [] 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 Abandonmentsee 20 AAC 25.105-!70). ARCO Alaska, Inc., proposes to complete this well with the Westward Well Service Rig #1. The procedure will be as follows: 1) A mast truck will be utilized to run the CBL/VDL/GR and Gyro. 2) The rig will be moved on location; the BOPE will be nippled up and tested. 3) Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. 4) The well will be completed with 3-1/2", 9.2#/ft, J-55, BTC tubing. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemehted annuli withinI the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. Th~ subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: April 20, 1984 S,~;Bseouent Worlc ~epo~ecl o~ ~o:~ No. ~ I)~tcd ..... 4. I hereby c~'t~y that the foregoing is true and correct to the best of my knowledge. , ,/~ // .. ,///~' Area Drilling Engineer Signed(///~ ~ ~-~'- ~ _~ Title The sp~ bel~t~v~/jr//~mmission use Conofftions of Al¥1~t'oval, if any: BY I?AI~tlY W. KUGLER By Order of Approved by COMMISSIONER the Commission ~:proved Copy Returned .. Date Form 10-403 Rev. 7-1-80 GRU6/SN11 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate O&G #4 4/80 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspector ~~ Ope rater ~ ~ ~ Well ~U~\' ! Location: Sec Drilling Contracto r~~ Well ~k/f, ,r~,~ ~ Representative Permit # ~ ~.~asing Set Rig ~ ~ + ~ Representativfl Location, General Well Sign General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve ~ Kill Line Valves Check Valve u,~" I Test Pres sure ACCUMULATOR SYSTEM Full Charge Pressure ~-~,OOO psig Pressure After Closure I ~00 psig 200 psig Above Precharge Attained: min~ sec. Full Charge Pressure Attained: ~W mit ~ ~ sec Controls: Master ~)~ Remote O~[ Blinds switch cover ~ Upper Kelly Lower Kelly Bal 1 Type Ins ide BOP Kelly and Floor Safety Valves I ~V/Test Pressure I ~ Tee t Pres sure . I ~Test Pressure I Test Pressure Choke Manifold I ~Test Pressure No. Valves 6~ No. flanges ~ Adjustable Chokes I Hydrauically operated choke I Test Results: Failures j Test Time _~ hrs. ~_WQ Repair or Replacement of failed equipment to be made within., days and · Inspector/Commission office notified. I Dis tribut ion orig. - AO&GCC cc-Operator cc - Supervisor Inspector ~reh 19_, 1984 Mr. Jeffrey B. Kewin Area Drilling Engineer ARCO Alaska, Inc, P. O. Box 100360 Anehorag,, Alaska 99510 Re: Kuparuk River Unit 2F-9 ARCO Alaska, !ne. Permit No. 84-36 Sur. Loc. 37'FNL, 1470'FEL, See. 33, TllN, R9E, UM. Btt~hole Loc. 1451'FNL, 1305'FEL, Sec. 33, TllN, RgE, Dear Mr. Kewin: Enclosed is the approved application for pemit to drill the above referenced well. If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings and a mud log are not required. A continuous directional survey ~s required as per 20 AAC 25.050(b)(5). If available, a tape contaTning the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dlpmeter surveys. 5~ny rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Po!l~%tion of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code. Chapter 70) and by the ~ederal ~&ter Polluti°n Control Act, ~s amended. Prior to com~encing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in ~cheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention Jeffrey B. Ko. in~ KUparuk R~ver Unit 2F-9 -2- March 17, !984 equipment ~o that a repreaentative of the Co~ssion may be present to witness testing of the equipment before the surfac. casing shoe is drilled. ~%ere a diverter syst.m is required, please also notify this office 24 hours prior to commencing ~qulp~ment installation so that the Commission may witness te~ting before drilling b~low the ~hoe of the conductor In thee~-e~+ of ~uspension or abandonment, please give this of~e_=~ e adequate advance_ notification ~o that we may have a witness present. Very truly yours. -. .: Alaoka Oil and Oa~ Consorvatlon Comic,ion Enclosure cc: Department of Fish & Game, Habitat Section w/o enel. ~partr~nt of Environmental Conservation w/o eno!. ARCO Alaska, Inc. Post Office Bo-~. 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 March 7, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Kuparuk 2F-9 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 2F-9, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plat A diagram and description of the surface hole diverter system ° A diagram and description of the BOP equipment Since we estimate spudding this well on March 17, 1984, your earliest approval will be appreciated. If you have any questions, erely, /A~~ Engineer JBK/JG6/L14:tw Attachments please call me at 263-4970. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA i::yrL AND GAS CONSERVATION cO,,'~nVIISSION :RMIT 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 [] MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc. 9. Unit or lease name ~ Kuparuk River Unit 10. Well number 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 37' FNL, 1470' FEL, Sec.33, T11N, R9E, UM At top of proposed producing interval 1280' FNL, 1325' FEL, Sec. 33, TllN, R9E, UM At total depth 1451' FNL, 1305' FEL, Sec. 33, TllN, R9E, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 125' , PAD 96' 6. Lease designation and serial no. ADL 25657 ALK 2583 11. Field and pool Kuparuk River Field ~.~ Kuparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewi de Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 30 mi, NW of Deadhorse miles 16. Proposed depth (MD & TVD) 6573' MD, 6248' TVD 14. Distance to nearest property or lease line 3829' @ TD feet 17. Number of acres in lease 2560 tl 5. Distance to nearest drilling or completed F-16 Well 360' @ surface feet 18. Approximate spud date 03/17/84 feet 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures 2737 psig@~ Surface KICK OFF POINT 3000 feet. MAXIMUM HOLE ANGLE 27 oI (see 20 AAC 25.035 (c) (2) 3071 psig@ ~1~70 ft. TD (TVD) 21 SIZE Weight 65.5// Hole I Casing ~24" 16" 2-1/4" 9-5/8" ~-1/2" 7" 36. O# 26# 22. Describe proposed program: Proposed Casinq, Liner and Cementing Program CASING AND LINER Grade Coupling Length H-40 Weld 80 J-55 BTC 2826 HF-ERW J-55 BTC / 6545 I HF-ERW SETTING DEPTH QUANTITY OF CEMENT MD TOP TVD 29' I 29' 29' I 29' I I 28' I 28' MD BOTTOM TVD 109' 109' 2855 ' I 2855 ' I 6573'16248' I I (include stage data) ± 200 cf 805 sx AS III & 650 sx Class G 420 sx Class G neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 6573' MD (6248' TVD). A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 9-5/8" casing will be set through the West Sak Sands at approximately 2855' MD(2855' TVD). A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 9-5/8" 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 is 2737 psi. Pressure calculations are based on latest reservoir pressure. Surface pressure is calculated with an 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, 8rd 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 (see attached sheet) 23. I hereby ce~at the foregoing is true and correct to the best of my knowledge SIGNED TITLE Area Drilling Engineer The space be(L~/~r~C_~~~s~~-- - CONDITIONS OF APPROVAL Samples required [[]YES ~[~O Permit number APPROVED BY Form 10401 GRU6/PD07 Mud log required I Directional Survey required []YES J~O I /~YES i--I N O Approval date DATE IAPI number 50-o Z.?-~_-i~ SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE_ ~_rch :[2, ~98h by order of the Commission Submit in triplicate PERMIT TO DRILL 2F-9 installed and tested upon completion of the job. 2F-9 will be 360' away from 2F-16 at the surface. There are no other close wellbores anywhere downhole. Top of cement for the production string will be placed at 7394'MD, approximately 800'MD above the top of the Kuparuk Sands. Reserve pit fluids will be disposed of down the 9-5/8" x 7" annulus. The 9-5/8" x 7" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. ....................... ~'-'- t : : ! · : !,' : , : i i '; i ! i i i i .... ! J i i ! i i I i ~ : ~ !ii! ~ i i ..... :-,---?--~ ................... ',"'"'' '"'~.' ~ !Il i,ri ! i i i i I J ~ ~ I , -- ...... :-:-------'-~- '------:-:--i ' !:~jl ;i'i ~jii i!;i i",LII/ i i , J I , ! i ! J ' , i --:--: : · '~ ..... ~,,~',"~, ,-~"'~ i ; j i i ! ] i i . : : . . , : : . i , :. : ~ ~ I Ii ~ j , '~ J J : i i , , , i ~ --: ; ' "; ~ ..... i-:- ., ! '~ I J~' :,il ill J.lIi-'-' ! ~_ ~ i i J i~ ~ : t~ 1. 2. 3. 4. $. 6, Surface Diverter System 16"-2000 psi Tankco s_tarting head. Tankco quick connect assy. 16" X 20" 2000 psi double studded adapter. 20" 2000 psi drilling spool w/lO" side outlets, 10" ball valves, hydraulically actuated, w/10" linesty~ to reserve pit. Valves to open automatically upon x.. closure of annular preventer. .,. 20" 2000 psi annular preventer. 20" bell nipple. Maintenance & 0Deration 1. Upon initial installation close annular preventer and verify 6hat ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. 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 ANNUL.AR PR£VENTl~ 9 PIPE BLIND 6 I-ID DIAGRAM fl 13-5/8" 5000 PSI RSRRA BOP STACK 1. 16" - 2000 psi Tanked starting head 2. 11" - 3000 psi casing head 3. I1" - 3000 psi x 13-5/8" - 5000 psi spacer spool 4. 12-5/8" - 5000 psi x 13-5/8" - 5000 psi drilling spool 5. 12-5/8" - 5000 psi pipe rams 6. 13-5/8" - 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 9. 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 WITlq 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 NADC REPORT. THE ACCEPTABLE LOWER LIMIT 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 SEAT AND SEAT IN WELLHEJkD. RUN IN LOCK DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND V~a~g¥-~S UPS~ O~ CI-IC)~S. DON~T TBST AGAINST CLOSED CHOKES 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD 'FOR 10 MINUTES. ~ 5. INCREASE PRESSURE TO~ AND HOLE FOR 10 MINUTES. BLEED TO ZER 6. OPEN ANNULAR PREVENTER AND C~E TOP SET OF PIPE RAMS. - ~ 7. INCREASE PRESSURE TO . ND HOLD FOR i0 B. ~~'PR~SSUR~ DOWN~ OF CHOK~ ISOLATION VAL.V~S. TO ZERO PSI TO TEST VALVES. TEST REMAINING UNTESTED .MANIFOLD .VALVES, IF ANY, WITH 3000 PSI UPSTRF.9,M OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. 9. OPEN TOP SE')' OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE RAMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES BLEED TO ZERO PSi. 11. OPEN BOt-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 PSi WITH KOOMEY PUMP. 15.RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 16. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNC- TIONALLY OPERATE BOPE DAILY. ITEM (1) Fee (2) Loc · CHECK LIST FOR NEW WELL PERMITS APPROVE' DATE qthru (8) (3) Admi_n ~~ ~- ~f~ (ff .~th~ru 11 ) (10 and 11) ~('12 thru 20) (21 thru 24) (6) Add :~.~ .~. ,~' ~-~ 9/ Company Lease & Well No. YES NO Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line ................. 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included .............. 7. Is operator the only affected party ................................. 8. Can permit be approved before ten-day wait .......................... __ . 10. 11. Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ............................... .~... 12. 13. 14. 15. 16. 17. 18. 19. 20. 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 ........................... 21. 22. 23. 24. Is a diverter system required .................................. ~ Are necessary diagrams of diverte~ and';;; equipment attached Does BOPE have sufficient pressure rating - Test to ,~D~ psig .. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. 25 Additional requirements ............................................. REMARKS Additional Remarks: Geology: Engipe&ring: HW~ ~. LCSSI~EW WVA ~ JK~JH JAL rev: 12/08/83 INITIAL GEO. UNIT ON/oFF POOL CLASS STATUS AREA NO. SHORE Well His'tow 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. -: · ,. ~VTC~ ~A~E : RS~OW ~ : XI~U~ ~,E~G?H : ln24 I,E TYPF ~VTOItS' F~L~ I~F~RMA?I~N RFC~RD$ ** 9F-9 qB 33 ALASWA ~YZ CO~E~TS ** 000 000 0~6 065 000 000 004 065 OeO 000 008 065 000 000 002 065 OeO 000 004 065 000 000 002 065 0~0 0~0 008 065 OeO 000 006 065 000 OeO 004 065 P 010.[;07 VEPI~'ICA~'I~N LTSTIM¢~ PAGE 2 *************************************************************************************** ~P~NY = ~L~MTiC ~ICMWIMLD ~O~P~NY Lb = UNTY = NORTH ST,OPE 80ROi)CH ~ MI.J~BFR ~ ~CC: 60066 PE FLUTD = X'C POLYmeR , Uln LOSS ~ 9,0 ~C : 2 9~ ~ ~0'0 DF 6.9 C] P~ AT ~}4T = 1,70 m 144 Dw T~TX S~ NDs'~O~E ******** ********************************************************************* , * 8CWLUN~E~GEN L~GS IM~bUDED WTTH THT$ M~GNE?IC ~A~E~ * * rO~M~TIO~ ~EMS~TY. COMPMNR~TE~ bO~ ~FDN) * * COMPFMSATE~ WEUT~ON LO~ (F~N~ , D~T~ FOR~T REC~RB ~YPE SIZE ~EPR CODF ENTRY 4 1 66 8 ¢ 7~ 60 9 4 65 0 1 66 0 · []~ SP~C?FTC~TTOM ~LOCKS FM SFRVICE SFRVICE UNTT ~PI ~pT APl aP! 7IZ, E SI~M PROCFSS SA~Pt,£ REPR p cIO.HO') VE~Ilr.ICA"'IhN I_,ISTI~TG PA~,,E 4 HI HO NL NI., FT 0 niT., nil ~H~!~ LIT, ~V 7 BIT, ~API', 7 31 ~2 o 0 ~DN PU 42 6P 2 o ~DN ~D~ ~/~3 42 35 I 0 FD~ CPS 4~ 34 92 0 O ~DN ~PS 4,~ 34 93 0 0 FD~I TN 42 2~ 3 0 0 ~DN ~D~ WD~ ~A~I 42 31, ~2 0 n D~.Th PT PT IT -3416 Ia71, .~449 .6250 .o000 .~41,8 ,.6378 ,.~500 .~348 .6641 .o000 .0000 .9902 26. 1952. 2n38. 4. 260. -q9q. ~,750 9375 0000 50~g t875 0000 ~734 ~500 t250 oono 1.816 0000 ~500 ?500 ~L~ ~PHI ~R TL~ NPHI FC~L .P~! .PHI ~PHI 000 54.~ 0o0 t4.~5i6 31.2500 1090,.~000 4~o0000 , 34.3497 3.76gl 94.93?5 1.~568 51.5625 456.7500 It5.!875 45.6055 ~09o~000 136.1250 2,1.348 -ggg.2500 -999.2500 76~.0000 IbM D~NO CALl IL. ~0 CALl DRHO CALl DRHO CALl DRHO CHt, I DRHO CALl -3276810000 6.$000 9"4219 4.~994 0,0264 9,6172 0659 0352 q,9511 2 q.3438 PT 5~00.0000 ,,,64.. 62~0 .ago. ~500 ~IC~L -qgq. ~5~0 PT 5?00. 0000 ~FLtJ -6! .4375 -qgq. ~500 -qgo. ~5o0 PT 5600'. no00 -58.1562 -g90.~500 ~C~L -~90.~500 PT 5~0~.. 0000 ~FLU nB -~90.~5o0 ~,T -o9q. 9500 nN~A PT 5400.n000 ~FLLi 0 RN~A PT 5300.0000 ~FT,U AT -q9q.~500 PT 5~00.0000 SFT, U PT 51On, nO00 -8~..~875 nB -~90.25n0 NCNL ' -6~.,4.375 CR :PT 4~On'.nOnO SFLU ' -77.7500 -qgq.~SnO ~NRA ~.4844 4.42J, 9 !1~.~000 -090.2500 4.~00~ 116.0625 3.3594 125,.n750 -090.7500 -090 ~500 R?.~625 . ~.~5no 3.486] ~35,0000 -090.~500 14~.m7~o -a9q..2500 -agO.2500 , 1.1650 -q9~.2500 -gga.?5nO 4.2656 90.7500 -99q.2500 -aga.25~O 2.5808 157.,750 -090.2500 -o90.2500 ~1~.5000 2.59{8 -990.2500 1,16.0625 J25.8750 -099 o 0 -ugu.~500 -~99,~500 8~,56m5 ~16.2500 -999.~500 ~o99.~500 115.0000 -090..~500 .o90.2500 -990.~500 1.42~7 -999..~500 -99U.~SnO -ago.2500 ].281.3 -099.~5n0 -qgq.25nO '990.2500 '099.2500 :10'0918 ~999..~500 g,96~7 4'~0~0 10.~?]4 -999, O0 ~.0,1m6 'ggg.~500 10.,~094 ~ 4150 -q9q.2500 1.4102 -ggg.~500 -99g.~500 -~9~.~500 ~T ~T PT PT PT 4"I00. t~ 0~0 -999. ,9,500 4600.0000 -~9~,.~500 -'o~q. ~500 4~0o.0000 -76.1875 -999.5500 44001. O000 -q9Oi~500 -~9Q.9500 4300 0000 -990.9500 -8~., 43'/5 -,q~q. ~5no · , q9o. ,9.500 4100.0000 -84.0000 -~99.~500 4000.o000 -999.9500 3.qO0.O000 2'7.~344 -q90.~500 ,-q99.~500 3800.0000 -29.f~750 -~9~,.~5no mq9o.~500 3700'.0000 -e~~C~. 7500 S F L U ~FLU ~N~A ~F[,U ~R NCNb ~N~A SF{,,,U ~N~A ~R ~FLU ~CNL ~N~A ~FLU ~N~A ~ F L U NCt~L 4.91~8 -~90.2500 ~R -qgg.?5~O ~ 4805 ,I,,~ ~.. ~67~ 8 ~3195 ~PMI -099, 50 -Q99.~500 ~R -~99.9500 ~,9199 87.8195 ~lPHI -999 ~§00 -99~,.9500 FC~L -~9~~500 -o9~.~500 GR -~99.~500 ~.~109 -09q.~500 ~C~L ~.~836 ~h~ 9.~'578 ~.~152 ~[,O 9.6992 113,.1875 -n99 ?500 WC~L -090.~500 -090:~5oo ~ -090.~$oo I1~.9875 ~P~I -q99.9500 -e99.~500 FCML -09q.~500 -n~Q.~500 ~R -o99.~500 . g~ 4102 ~LD 3.5430 4:S750 -09q ~500 WCNL -999,~500 -O90~500 ~.~9R8 ~LD ~..4766 93.0000 ~P~! -099.~500 ,~99.9500 FC~L ~.0469 T~n ~.5703 97.31~5 ~P~! -q99,~500 -099.~500 CR -~99.~500 94.1250 ~'PgI .Q90,~500 -099.9500 DR~O DR~O ~ALI CALI DRHO CAL! CA I DRHO CALI ! [,M .. DRHO CAtI CALl DR~O CAt, I ORHO ~RHO CALl ].86~2 -~9q,~500 -999,~500 · ~.3242 .qgg.~500 ~ ~,769:5 .gOg.~LoO m,.28.13 .999,2500 .09o.2900 2.3535 -~99 2500 .~5~0 ,6641 ,099,~500 -099.2500 3,i0~6 -099.2500 3.89n6 .090.~500 -99q. 500 -99 ,~500 -q~q,2500 P f~l.O.WO~ VEPIWICATION ,t~TSTIN(; PAGE 7 -o9o.9500 PT 36O0.00O0 -999.~5~0 350~.0000 ~31.671,9 -99~.~500 340n'00o0 -34.~0~2 -999.~500 -~99.9:5~0 ~00..00~0 ~38~.a~5 hB -999.~5~0 PT 3200,.~000 -999.~500 ]loo~oooo -4~.~938 aT -999.~500 3000.0000 -47,1562 2900.0000 -41.56~5 -~9~.~500 2e4~.nOOO -67.4375 -q9~.~5o0 -~9o.9500 ~PA -o99.~500 ~P'"Y,U 9.5059 ILD ~R 9R.~500 ~N~A -~99.~5~0 CR SF~U P.. ! 7~7 TLn MCteL -999.~500 DN~A -g99.9500 ~R ~F~,U ~.1090 TLD ~R 91. ~,250 MP~I NCWL -9,9o.~5~0 FCNL ~R ~4.75~0 ~P~! NCnb -99~.~500 rCNL ~N~A -~99.9500 ~FI, U 3'0313 ThD ~R 6~.~750 ~C~5 -~99.~5~0 ~N~A -~99.~500 ~FI, U ~nO0.O000 CR 47.7500 DNPA -99~.~500 ~R F!L~ TRaILEP :RVTCW NA.E ~?E ~XI~U~ LENGTH .001 -999.~500 84!.8 -q9~.~500 9.~500 .3555 -~99.~500 -q99.~500 3,~477 -999,~500 -999.~§00 -999.~500 -999,~500 9~.~500 .500 -~9~.~500 -~9~.~500 -999.~500 -999.~500 ° 0 -99O.~500 -999.~500 RHO ¢A5I II.,M DRHO C A L I DRHO CALX DR~O fAi, I D~HO CAt.., I DRHO CALl DRHO 2500 999.2500 -999,~5~0 -9'99,~500 4 -q99.~500 -99q.~500 ,'qgq,,~500 0 -999.2500 ).3105 -999,2500 -999.~5~0 -999.2500 -999.~500 P OlO.gO~ VE~IFI'?'ATIaN [,,!STING PAGE 8 XT FT[,~C NA~E : ?APR TRAI!.,E~ YGYN P~ NAM~ MTTNUA~ION { TE.,IR4/04/ 6 YGTN :
