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181-178
Wallace, Chris D (CED) From: Well Integrity Compliance Specialist CPF1 & 2 <n1617@conocophillips.com> Sent: Friday, April 3, 2020 7:25 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1A-12 (PTD 181-178) Report of IA pressure increase Attachments: 1A-12.pdf, 1A-12 90 day TIO trend 4.3.20.pdf Chris, KRU injection well 1A-12 (PTD 181-178) governed under AIO 26.049 was reported this afternoon for a rapid increase in IA pressure. The IA pressure was bled down, but has continued to increase. The well has been shut in and wireline services are being mobilized to the well. The plan is to attempt to locate the pressure source and secure the well. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Cell phone: (808) 345-6886 Office phone: (907) 659-7224 WELL LOG TRANSMITTAL # To: Alaska Oil and Gas Conservation Comm. Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Packer Setting Record: 1A-12 Run Date: 10/27/2019 181178 3 160 4 November 21, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS ANC@halliburton.com 1A-12 Digital Data in LAS format, Digital Log Image file E E V E ® 1 CD Rom 50-029-20688-00 DEC 0 9 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: 14�ql lq Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS r1iC%.rC1VtU NOV 14 2010 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing El Change Approved Program ❑ Plug for Redrill ❑ perforate New Pool ❑ Repair Well ❑� Re-enter Susp Well ❑ Other: Tubing Patch ❑✓ 2. Operator ConoCoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ry ❑ Stratigraphic ❑ Service E] 181-178 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-029-20688-00 7. Property Designation (Lease Number): S. Well Name and Number: ADL0026647 i<Ru 1A-12 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 8,865 feet Plugs measured None feet true vertical 6,761 feet Junk measured None feet Effective Depth measured 8,222 feet Packer measured M, 4920, 7815, 79; feet true vertical 6,175 feet true vertical r 51, 3769, 5822, 59feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 feet 15 80' MD SURFACE 2,690 feet 11 3/4 " 2,721' MD PRODUCTION 8,822 feet 6 8,852' MD JEWELERY TYPI MD apth MD&TVD feet Composite Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 8,174' MD 6,133' TVD Packers and SSSV (type, measured and true vertical depth) PATCH - UPR PKR (ME) - 3-1/2" P2P F 1,588' MD 1,579' TVD PATCH - LWR PKR (ME) - 3-1/2" P2P F 1,608' MD 1,598' TVD PATCH - UPR PKR, SPACER, LATCH - 4,890' MD 3,751' TVD PATCH - LWR PKR - 2.72" P2P W/ 4,920' MD 3,769' TVD PACKER - FHL RETRIEVABLE PACKE 7,815' MD 5,822' TVD 12. Stimulation or cement squeeze summary: PA 7,989' MD 5,972' TVD Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20AAC 25.070, 25.071, & 25.293) 15. Well Class after work: Daily Report of Well Operations Q Exploratory ❑ Development p ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ (] WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ifC.O. Exempt: 319-450 Contact Name: Jan Byrne / Dusty Freeborn Authorized Name: Jan Byrne Authorized Title: Well Integrity &Compliance Specialist Contact Email: N1617@conocophillips.com Authorized Signature: Date: 11/12/19 Contact Phone: 907-659-7224 Form 10-404 Revised 4/2017 RBDMS� NOV 14 2019 Submit Original Only November 11, 2019 Commissioner Chmielowski Alaska Oil & Gas Conservation Commission 333 West 7h Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski: Enclosed please find the 10-404 Report of Sundry (#319-450) Well Operations for ConocoPhillips Alaska, Inc. well KRU 1A-12 (PTD 181-178) for tubing patch repair. If you need additional information, please contact us at your convenience. Sincerely, Jan ByZDusctyreeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM ConocgP"ps IIA -12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1A-12 Pertinent wellwork for 2nd AnnComm tubing patch is copied below. 10/091191 Approved 10-403 (Sundry 319-450) received. 10/30/1 11/10/19 st i LUVVLK 2.12" F2P (a? 1608' RKB (ME) (CAL 4.01'1 SN: CPP35200), CMIT TBG x IA 3000 PSI ***PASS"** SET UPPER 2.72" P2P PATCH ASSEMBLY (CAL 20.84'/ SN: CPP3502231 CPAL 35126) MIT IA 3000 PSI ***PASS*** JOB COMPLETE. PRE CMIT T/I/O/OOA= 1750/1675/160/20, LRS ON LINE .2 BBLS TO PRESSURE TBG UP TO 3000 PSI PRESSURE SLOWLY EQUALIZING RIG UP JUMPER TBG x IA 1.5 BBLS TO TEST PRESSURE T/I/O/OOA= 3025/3000/200/20,15 MIN T/I/O/OOA= 2975/2975/200/20 (50/25), 30 MIN T/I/O/OOA= 2950/2940/200/20, (25/35), 45 MIN T/I/O/OOA,= 2915/2900/200/20, (35/40), T/I/O/OOA= 2900/2900/200/20, ****PASS*** PRE MIT IA T/I/O/OOA= 1550/1675/170/15,1.4 BBLS TO PRESSURE UP T/I/O/OOA= 1550/3000/200/15, 15 MIN T/I/O/OOA= 1550/2950/200/15, 30 MIN T/I/O/OOA= 1550/2940/200/15 ***PASS*** BLEED BACK TO STARTING PRESSURE (SW) : State witnessed (Brian Bixby) MIT -IA Passed to 3300 psi. Initial T/1/0/00 = 2250/590/487/0. IA FL @ surface. Pressurized IA to 3300 psi w/ 2.5 bbls diesel. Starting T/l/O = 2250/33001690/0. 15 min T/I/O = 2250/3210/694/0. (-90). 30 min T/I/O = 2250/3200/696/0. (A 0). Passed. Bled IA to 590 psi (bled back 2.5 bbls). Final T/I/O = 2250/5901494/0. I KUP INJ WELLNAME 1A-12 WELLBORE 1A-12 ConowPhillips Well Attributes Ma%Angle&MD TD WellboregPllVWI WellEa,e SU[us cl(°f guntle) Aclln (nKB) ZEA Alaska, Jim KUPARUK RIVER UNIT 500292068900 INJ 6.70 4,000.00 8,8650 Commml HISgrant Data AI Entl Date 1(B -G,4 UD RID al gat, WGA SSSV: TROP Lal WO: 62]2008 39.01 1/6119e2 I tN1z taregioe 11,13NSA, Last Tag Vetllulacskraee(atlua9 Annotatlon DapmM1(nKB) EnEDah Wellbore '.".Easy Tell ELM 8,222.0 A26I2015 1A-12 hlpshkf ^..�..............�.. INNGER:3)1 .....__...._ Last Rev Reason AUT End Dale WeIIEore -1.A-rd By WG PA Rev Reason: PULLED SS8N3P, PATCH TUBING LEAK 10/3012019 1A-12 condijw Casing Strings CON Des=npnoo CONDUCTOR on pre) n, 1fi 15.06 330 Veptn (rcKe) 80.0 set Depth (TN)-. WVLen (I... PIT 6509 GnEe rupinmaa R40 CON&CLOR; 33O�.0 zingoezcnpllon SURFACE OD (In) 10 (In) 10314 9]9 Fear) Top (N!B) 31.2 Se[DeplM1 %Noj 2,]21.0 s=t Depm (rvo ... WVLm p... 20665 0560 Grape Top? need KISS BTC PATCH UPRPKH(ME): me.D Casing Dascrlagon PRODUCTION OD us) ID (In) 7 6.29 TopRKB) 293 Se[Deplh(Shut 8,852.0 Set Depth(ND)-. WVLen p... 26.0 6,>48.5 0 Grace Top Thread K-55 SPACER PIPE: 1 .593.0 SPACER LEAK' 1.0.7].0 TubingStrings Tubinp Descrlplion Atre Ma...IDllnf Top (flKBf gat DepiM1 (n..5 Depih(No)(... YW (INn) Gratle Top[onnection PATCHBarPUP(ME): 1 suBA TUBING 0102008 31/2 N. 27.1 8,181) bet3R7 9.30 L-80 31/2 Completion Detai is To'nr.) Topincl Nominal Top n9a) (nKB) IS pi Com ID(,1) RalsLu. 2,.q 27.1 27.11 0.35 1 HANGER TUBING HANGER 3500 2,0650 2,011.8 34.02 SAFETY VLV TRMA%%SE SCSSV LOCKED OPEN W4113 2.812 ],]99.1 5,8085 31.1] LOCATOR LOCATOR 3.000 ],801.5 5,810.5 31.15 PER BAKER PER 3.000 SURFACE; 1122731.0 7,814.8 5,821.9 31.02 PACKER FHL Retrievable Packer 2.930 PATCH-.rEpis SPACER, 7,926.5 5,918.1 30.10 SLEEVE - BX Baker CMV Sliding Sleeve with B% Profile (CLOSED 6/1912010) 2.813 IATnx:4.asB.0 TU&NG ICS x8120 8,128.0 6,092.9 2955 SEALASSY Seal Assce yw2'spaout 3.00D 8,130.0 6,094.7 29,52 PACKER Baker "F-1"Pecker 4.000 PATCH, DAR PUP '.aM0 8,133.4 6,097.6 2949 SBE SBE 4.000 8.13].] 6,101.3 29.44 Bottom Sub 2,950 RAS Lo-":]]af 8,1]3.] 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 B, D4J 6,1336 29.04 SOS ELMO TTL@8162during SHOP on 318/2007(Shear Out Sub 2.950 NTubing Pup) LOCATOR;],]W.1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) '-P OSIKID Topincl Top (1,57 ('f Des Co. Runn201 IS (in) PAR; >.1p15 588, 1,58811 1,994 17.53 PATCH -UPR 312" P2P PACKER, CPP35223, SPACER PIPE, TW -3W201 1.630 PAC6eR:7e14A PKR(ME) ANCHOR LATCH CPAL35126, OA1=20' 9 1,592.0 1,583.2 1]]0 SFACERPIPE 2-1/11"PI10SPACERPJPE 10130/201 1.fi30 9 1,600.0 1,590.8 18.02 TUBING LEAK TUBING LEAK@ 1600,0.14 BPM LLR, CONFIRMED Frie 19 2.992 SLEEVB-B%T9xa5 W/ACOUETICARCHER TOOL 1,608.0 1,5984 18.12 PATCH -LWR 3-12' P2P PACKER, CPP35200, CAL= 4.01' 10/301201 1.630 PKR(ME) 9 4,890.0 3,751.3 5403 PATCH -UPR 2.72"P2P (#CPP35135), SPACER PIPE, ANCHOR 101211201 1.690 PATCH; 7,9e9.0 IFERF; ],9l9GeC5]0 PKR,SPACER, IATCH LATCH (#CPAL3506]/vAT OAL ME@4890'PIKE 7 4,912.0 3,7642 54.03 TUBING LEAN TUBING L 0.14 BPM LLR, CONFIRMED 10126201 2.992 W/ACOUSTIC TIC ACX AC%TOOL 7 4,920.0 3,768.9 SAPS PATCH-LWR 2.72- P2P as AGGRESSIVE SLIPS g0CPP3513314.0V 101211201 1690 PKR CAL) 7 ME @ 4920' PIKE wggF: e.DQ.Dawtu 7,989.0 5,9]23 29.86 PATCH UPPER PATCH ASSY 272" PARAGON II PACKER (SERIAL# CPP35005, 12.69' SPACER PIPE, LATCH 1126/2016 1.610 SEAL ASSY SERIAL# CPAL35011(OAL-18.49) @7989' (MID ELEMENT) PATCH: AaB.O IPERF A.IDDDA.104O'PATCH IS 17 ELEMENTS TO ELEMENTS; MIN I0. 1.61" 2.72" PARAGON II PACKER(SERIAL 0 CPP35008) in IPERH Atm Da124n Tbg @ 8006' (MID ELEMENT) RKB (0AL=3.93) 8,066.0 6,039.1 29.84 PATCH PER AND SPACER PIPE IN LOWERANCHOR@ 1IW2016 1.600 8,108' PIKE SFR Assv: A.129.a STATE& IDE 2.72" PARAGON II PACKER (ser.# PACKER; ST. t CPP35[)14), 19S SPACER PIPE, UPPER PACKER @ AAE: A13a.4 8,065' PIKE CENTER ELEMENT PATCH is 42' OAL OVER INTERVAL 8,066'-8,108' 2.72" PARAGON I I PACKER ( SER #; CPP35030) Demenr SOl; e.laz.o 1. CMTSOEADmaug,teu. 11,286.0 6,231.6 27.55 FISH Brmn'18'PACKER -Cali 3/8017 showsa 2" per pprox ID; CAMCO D NIPPLE, BARER SOS -PUSHED 8@7/1985 2.000 DOWNHOLE BELOW PERFS WITH 2008 WORKOVER NIPPIE; 8,1]37 SOe anal 8,3len 6252.9 27.15 FISH BMY halt of V DMY having @-8252 RKB 121261199 1 8,502.0 6,4260 24.14 FISH Vann Gun 11&1982 IPERr;831S.M=C- Perforations & Slots Shot Den Top ON.) SROTV.) nh... Topndog Btm HKB) (RKB) (nKA) Lux. Zona Dah ) Type Com IPERSA..Geati0- 7,948.0 8,057.0 5,9363 6,031.3 C -1 ,C -2,C -3,G 1/611982 40 (PERF 4"Vann Guns 4,1A-12 8,052.0 8,0]1.0 6,035.6 --TN-3A--0-L -12 1/&1982 401PERF 4"VannGuns FlSH; e,aeao 91000 8,104.0 fiOME 6,0720 UNIT B, IA -12 11611982 4.0 (PERE 4"VannGuns FISH B,31D.0 $120.0 --T1 2-40 6,085.9 6pg94 UNITS, 1A 12 101982 Zle WERE 4' Vann 8,162.0 8,154.0 5,122.5 6,124.3 UNIT B, 10-12 &2011985 4.0 CMT SO2 FISH; e.aoaD 8,219.0 8,223.0 6,1724 6.176.0 A5, 1A-12 1/6/1982 401PERF 4'Venn Gu. 8,233.01 8,26201 6,18481 6,210.3 A4,1A-12 1/61982 I 40IPERF 4°VannGuns PRODUCTION; reIr-spe.0 MEMORANDUM State of Alaska Permit Number: 181-178-0 Alaska Oil and Gas Conservation Commission TO: Jim Regg / P.I. Supervisor ( CC%/ �j'I/Ci DATE: Thursday, November 14, 2019 SUBJECT: Mechanical Integrity Tests Rel Insp Num: ConocoPhillips Alaska, Inc. Packer IA -12 FROM: Brian Bixby KUPARUKRIV UNIT IA -12 Petroleum Inspector Type Inj I w ' Sre: Inspector 5s2o ' I Tubing Reviewed By: 2250--F2250 P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK AIV UNIT IA -12 API Well Number 50-029-20688-00-00 Inspector Name: Brian Bixby Permit Number: 181-178-0 Inspection Date: 11/10/2019 - IUSp Num: mitBDBl91111162432 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well ]A-tz' Type Inj I w ' TVD 5s2o ' I Tubing 225o - 2250--F2250 - zzsa ' PTD 1811780 ' Type Test SPT Test psi 3000 IA590 3300 3210 3200 BBL Pumped: zs BBL Returned: zs pA 487 690 - 694 - 696 - Interval OTI�R P/F P Notes: MITIA Post Patch Job, SUNDRY # 319-450 ✓ Thursday, November 14, 2019 Page 1 of I THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Dusty Freeborn Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-12 Permit to Drill Number: 181-178 Sundry Number: 319-450 Dear Mr. Freeborn: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.a ogc c. a las ka.g ov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. SincerelyVJ,remyPrice Chair DATED this day of October, 2019. gBDMS± OCT 1 0 2m STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS iLUlr_CTIY]..WI QCT r32r1l;�s r,�, 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well Q Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Tubing patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ Stratigraphic El Service ❑� 181-178 ' 3. Address: P.O. Box 100360, 6. API Number: Anchorage, Alaska 99510 50-029206880000 r 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Ordergoverns well spacing in this pool? KRU 1A-12 r Will planned perforations require a spacing exception? Yes ❑ No ❑ fk 9. Property Designation (Lease Number): 10. Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool ADL0025647 ' 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): 8865' 6761' 8222' 6175 2247 psi 4885' 8286',8310',8502' Casing Length Size MD TVD Burst Collapse Conductor 47 16 80 80 Surface 2690 10.75 2721 2467 Production 8822 7 8852 6749 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7948-8057,8062-8071,8100- 5937-6031,6036-6043,6069- 3.5 L-80 8174 8104,8120-8124, 8162-8164, 6072, 6086-6089, 6123-6124, 8219-8223,8223-8262 6172-6176,6185-6210 Packers and SSSV Type: Packer- FHLRetrievable Packer Packers and SSSV MD (ft) and TVD (ft): MD= 7815 TVD= 5822 Packer- Baker "F-1" Packer MD= 8130 TVD= 6095 SSSV- TRMAXX-5E SCSSV locked open MC= 2065 ND= 2012 12. Attachments: Proposal Summary 0 Wellbore schematic ❑ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for N/A 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q - WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Dusty Freeborn Contact Name: Dusty Freeborn/Jan Byrne Authorized Title: Well Integrity & Compliance Specialist Contact Email: 1\11617 DDnco hllll S.com Contact Phone: 907-659-7224 Authorized Signature: Date: 9!29/2019 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: L4 50 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test l Location Clearance ❑� Other: RBDMSI—" OCT 10 2019 Post Initial Injection MIT Req'd? Yes [�J'No ❑ Spacing Exception Required?No Q' Subsequent Form Required: Q — �O � Yes ❑]V-1 I APPROVED BYApproved by: COMMISSIONER THE COMMISSION Date: l r ynr -403 Re vis d 41 017 A pp y �d W �yt� d �7 approval. � Suhmit Farm and o Approved application is al ' 1 v , V elate of a achmenls in Duplicate n hl.e ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 29, 2019 Commissioner Chmielowski Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1A-12 (PTD# 181-178). The request is for approval to set a 2°a tubing patch to regain tubing integrity. If you need additional information, please contact myself or Jan Byrne at 659-7224. Dusty Freeborn Well Integrity & Compliance Specialist Repair Proposal 1. Remove K3 packer and slip stop. 2. Set lower P2P packer at 1608', Set test tool in packer. 3. Perfrom CMIT-TAA to 2500 psi. Pull test tool if test passes. 4. Set snap latch, spacer pipe, and upper P2P packer at 1588'. Set test tool in packer. KUP INJ WELLNAME 1A-12 WELLBORE 1A-12 ConoeoPhillips Well Attributes MaxAngls&MD JTD Alaska, Inc. Fleltl Name KUPARUK RIVER UNIT WepMre gPIIUWI 50029206 Wellbore 3falus c1I') MO IXKB) pd B1m(XKB) INJ 6.]0 4,000.00 8,865.0 Comment SSSV: TROP HEs (ppml pale Mnaerion End Gele NBGttl lm, RIBRel-m.Ume Lasl WO: 612]12008 39.01 IIW1982 1 pA $, 9XBY1019 e:1d5o PM Last Tag VeMcN eoMmaf (aduap pnnetallan DEEM I Entl ptle mir.me Last MW By Lest Tag: SLM $2220 ]1260015 1-0-12 hlpshM ...... HANG'S,11 Last Rev Reason Annomtlan Entl pate Wellbore LasiMM By Rev Reason: ANNOTATETUBING LEAK 911fl0019 J" cond;pu Casing Strings Casing 0escrlpmar CONDUCTOR GO I., 10 (In) Tap(ttKB) 16- 15.08 33.0 Set OepIM1 IM1KB) Sel080th (TVp)... WLLen (L.. Gratle Top 80.0 80.0 6-5.00 H<0 TM1reatl cDNpucrGR; 3xoe0.0 Casing Oscelpllon SURFACE OD(Inl 10 (In) Top 10314 9J9 31.2 IM1NB) get Oep[M1 (ttKB)Set Oeplhj ul - VllM1en (L.. Gratle TaPTM1reatl 2,]21.0 24,601 45.53 K-55 OTC TUBWO LEAk LAW0 CasNB.-m"tbn PRODUCTION OTIIn) IOIin) Top ) 6.28 29.] (XK9) Set OepIM1 that S-1 peplh IND)._ Wthen p...Orade Tap IX 8,852.0 8,]48.5 2600 K85 Th -a Tubing Strings suEn Kk a.GF5.0 NEing De""hw s(nn9 TUBING W02008 3112 Ma... 1. (In) Tap 2.99 2].1 LS43) Set Oeptb lX.. Sel Oeplh (IVOI L.. Wt(IbM] Grade Tap2.rmm1[o, 8,161.] 6,139) 9.30 L-80 3112 Completion Details. Top (ND) ToPM-) (11148)(') T.Plncl Item Oes Cam Nominal 10 (In) 27.1 27.1 0.35 HANGER TUBING HANGER 3.500 SIIRF/,L E; 31.?],T[I.0 2,065.0 2 ,011.8 34.029VETYVLV TRMAXX-5E SCSSVLOCKED OPENb'14110 2,812 7]99.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 s80P PLOP; 483x4 PLUS ',d 8950 ],801.5 5,810.5 31.15 PHILBAKER PBR 3.000 PATCH -UPR aka, sPACEa, LATCH; 4, 353.0GULkIC4.9Qe 7,814.6 7821.9 31.02 PACKER FHL Retrievable Packer 2.930 iu01N 7,926.5 5,918.1 30.10 SLEEVE -BX BakerCMU Sliding Sleeve with BX Profile (CLOSED 6119001 0) 2.813 8,128.0 TiN2.9 29.55 SEALASSY Seal Assywli spaceoul 3-000 PATCH-LwRPKR;49MO 8,130.0 Q0947 29.52 PACKER Baker'F-" 1 Packer q,p0a 8,133.4 6,097.6 29.49 SBE SBE 4.000 GAS UFT; 7.743 8,13].] Q101.3 29.44 Bet.. Bob 2.950 8,1]3] 6,132.8 29.05 NIPPLE AVA'D'Nipple 8,1]4.] 6,133.6 29.04 SOS ELMD TTL@ 8162 du0ag 8BHP an 31812007 (Sh ear Out Aub 2.950 LOCATOR; 7.M.1wlrubin9 Pupj Other In Hole QAlireline retrievable plugs, valves,. pumps, fish, etc.) PBR]BB1.3 PACKER: Top MGM Top(ND) ("a) Top Incl (') Dee Ocm Run Ooh In (h.) 1,600- 1,590.8 18.02 TUBING LEAK TUBING LEAK@ 1600', 0.14 BPM LLR, CONFIRMED 91180019 2.992 W/ ACOUSTIC ARCHER TOOL 4,883.4 3,]4].4 54.03 S6LIP STOP SLIP STOP, OAL=19" 9115/2m9 1250 sLSEVB-BX; ].93x5 4,885.0 3,]48.3 54.03 PLUG K3PACKOFF W/ STINGER ASSEMBLY TO NOGG INSIDE PACKER, DAL 76" W/2.95" FN, 42.5" TO KOBE 911512019 0000 KO 4,890.0 3,]51.3 54.03 PATCH -UPR 2.]2'P2P (ACPP35135), SPACER PIPE, ANCHOR 1W21I201 1.690 PKR,SPACER, IATCH(NCPAL350fi]/30.86'OAL ] LATCH ME@4890'RKB PATCH].539.0 (PERF; ],916.a$a5J.0 4,912.0 $764.2 54.03 TUB IHIS -LEAK TUBING LEAK@ 4912',0.14 BPM UA, CONFIRMED 10126201 2992 W/ACOUSTIC ACXTOOL ] 4,9200 3,]68.9 54.05 MATCH -LWR 2J2"P2P ./AGGRESSIVE SUPS(#CPP3513314.01' 1N21)201 1.690 PKR CAL) ] ME@4920'RKB ],989.0 5,9]2.3 29.86- PATCH UPPER PATCH ASSY 2.]2" -PARAGON If PACKER 1n&I 1.610 (SERIAL 4 CPP35005,1269' SPACER PIPE, LATCH IPERFl e.Wz.Ga.mt.o SEAL ASSY SERIAL N CPA -35011 COAL -18.46) @]989' (MID ELEMENT) PATCH: 8.oGGG IPERF:e1W.Ge,1040- 7T 'PATCH IS i] ELEMENTS TO ELEMENTS; MIN IP 2.]2" PARAGON II PACKER(SERIAL 4 CPP35008) in Tbg @ 8006' (MID ELEMENT) RKD (OAL=3.93) PERF, 3,t G. 1..p 8,066.0 5,039.1 29.84 PATCH PBR AND SPACER PIPE INLOWER-ANCHOR @ 11912016 1600 8,108' RKB SEAL Assvl e.tmu STATEWIDE 2.72' PARAGON If PACKER ReCN CPP35014). 19.5' SPACER PIPE, UPPER PACKER @ 8 066'RKB CENTER ELEMENT PACKER: rI..t PATCH 1347 DAL OVER INTERVAL 8,086-8,108' 0E 8.1]x4 2.72" PARAGON II PACKER (SER N; DPP35930) 8,286.0 6231.6 27.56 FISH EroPar 18'PACKER-Caliper3l&07sh aapprM2" 8071985 2.000 camera 502: 8,1 oxo eKS cMr sat B,t¢z3e,t3o.9 ID; CAMCO D NIPPLE, BAKER SGS -PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER NIPPIP:x1]9] 8,310.0 8,252.9 2].15 FISH OMY halTof l"DMY laying@ -8252 RKB 12061199 SOS, 3,1]4,] 1 8,502.0 6,426.4 24.14 FISH Vann Gun 11611982 Perforations & Slots Shot IPERF8,218.08,MGL0- pens Tap TND) 3trh R%)) Top(XKB) BIm(XKS) XKB) (XKS) Unkeen- (sh.h. Del. ) rypa Co. 7,943.0 8,057.0 5,936] 6-,031.3 C-I,G2,C-3,G 1/611982 4.0 IPERF 4"Vann Guns 4.1A-12 IPEGF3.23aG-Uax0� 8,062.0 $071.0 6,035.6 6,043.4 G1, 1-0-12 1/6/1982 4.0 IPERF 4"VannGuns 111000 8,104.0 6,06-6.6 R0]2.0 UNITB, 1-0-12 11611982 4.0 IPERF TVann Guns FISH', az3a.0 8,1200 $124.0 6085.9 6,089.4 UNITB, IA -12 11811982 4.0 IPERF 4"VaaRGuns. $162- 8.164.0 6-,122.5 6,124.3 UNITB, 1A-12 812011985 4.0 CMTSC2 FISH: 8.310.0 8,219.0 8,223.0 6,1]2.4 Qt]6-A-5, 1A-02 11811982 4.0 IPERF 4-Vahp Guns RSH; %.a 8.233.0 8,26-2.0 6,184.8 6,210.3 j AA, 1A-12 116-11982 4,0 IPERF 4'Vann Guns PROWCTIDK 2932 a5L0 WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Injection Profile RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MITT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) LeakPointTM Survey 2) Signed Print Name: 181178 3131 1 ProActive Diagnostic Services, Inc. R ECEI� Attn: Diane Williams Ec Er) 130 West International Airport Road Site C OCT 0 9 2019 Anchorage, AK 99518 ^ n pdsanchoraae aAmemorvloa.com AOG Co 17 -Sep -19 1A-12 CD 50-029-20688-00 Date: doql dq PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE(&MEMORYLOGCOM WEBSITE: WWW.MEMORYLOG.COM hupsreadcasedhole-mysharepoint. om personal/diaoe williems reedcasedhole com/Documentsm Drive/Achives1Nasterl'emplateFiles Templates/Distribution rransmittalSheets/CouocoPhillips_Transmitdoc- Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Del ivered to: !� AOGCC ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 18 f ITT 3 125 9 TRANSMITTAL DATE-�. TRANSMITTAL It WELL NAME 2M-37 .. 50.103-20745-00 ORDERSERVICE EOSH-00096 FIELD NAME DESCRIPTION KUPARUK RIVER SERVICE DELIVERABLE WL DESCRIPTION IPROF DATA TYPE FINAL FIELD Color DATE LOGfEr 10 -Sep -19 r 1 3N-09 50-029-21541-00 6WUJ-00125 KUPARUK RIVER WL LDL FINAL FIELD 15 -Sep -19 1 1A-12 1H-114 1H-118 1H-119 3G-18 3F-03 50-029-20688-00 50-029-23584-00 50.029-23578.00 50-029-23591-00 50-103.20142-00 50-029-21448-00 DWUJ-00128 EDWI-00018 EDWI.00019 EDWI.00020 EDWI.00021 E0SH-00098 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL WL WL WL WL Caliper IPROF-WFL IPROF-WFL IPROF-WFL Caliper IPROF FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD FINAL FIELD 18 -Sep -19 19 -Sep -19 20 -Sep -19 21 -Sep -19 23 -Sep -19 25 -Sep -19 1 1 1 1 1 1 8 Print Name I Signature return via courier or sign/scan and email a copy Date and CPAI. Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. Wallace, Chris D (GED) From: Well Integrity Compliance Specialist CPF1 &2 <n1617@conocophillips.com> Sent: Saturday, September 14, 2019 9:19 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 1A-12 (PTD 181-178) Report of suspect IA pressure increase Attachments: 1A-12.pdf, 1A-12 TS and Secure 9.14.19 JFB.xlsm Chris, KRU injection well 1A-12 (PTD 181-178) governed under AID 213.049 was reported this morning for a rapid increase in IA pressure. The IA pressure was bled down, but has continued to increase. The well has been shut in and wireline services are being diverted to the well. The plan is to attempt to locate the pressure source and secure the well. The proper paperwork for continued injection or corrective action will be submitted once the path forward has been determined. A wellbore schematic and 90 day TIO trend are attached. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne / Dusty Freeborn Well Integrity & Compliance Specialist, CPF1 & 2 ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 WELLS TEAM Conocaftips MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,��`7 If �1 �1 t� DATE: Tuesday, July 30, 2019 P.I. Supervisor ' ` SUBJECT; Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IA -12 FROM: Jeff Jones KUPARUK RIV UNIT IA -12 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Supry —J�v NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT IA -12 Insp Num: miUJ190716091759 Rel Insp Num: API Well Number 50-029-20688-00-00 Inspector Name: Jeff Jones Permit Number: 181-178-0 Inspection Date: 7/14/2019 Packer Depth Pretest Initial 15 Mir Well IA 12Type Inj wZTVD 5820 Tubing '100 -125 ns PTD 1811780 TYPeTest SP, 3000 IA to 3;00 »o BBL Pumped: 36 iBBL Returned r 3.5 OA 175 360 360 Interval REQVAR P/F P Notes: 2 year MIT -IA tmax. anticipated injection pressure per AIO 28.049. I well inspected, no exceptions noted. 30 Min 45 Min 60 Min '415 f0 370 Tuesday, July 30, 2019 Page I of I MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Well Name KUPARUK RIV UNIT IA -12 Insp Num: mitJJ190716092228 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 30, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. IA -12 KUPARUK RIV UNIT IA -12 Sre: Inspector Reviewed By: P.1. Supry Comm API Well Number 50-029-20688-00-00 Inspector Name: Jeff Jones Permit Number: 181-178-0 1 Inspection Date: 7/14/2019 Tuesday, July 30, 2019 Page 1 of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A-12 TypeInj I TVD zazs zazs zazs I811780 _w Type Test _ SPTtTes 00 —t , ix— SI -- - -_PTD IA loo 1 210 218 231 BBL Pumped: 16 rBL Returned a pp 190 2000 'i I910 laso —. Interval -5820 -Tubing,2425 REQvAR Ip/F P Notes: 2 year MIT -OA to 1800 psi per AIO 26.049. I well inspected, no exceptions noted. Tuesday, July 30, 2019 Page 1 of I `9S -\-L' • • 2226")ob WELL LOG TRANSMITTAL #90430166 To: Alaska Oil and Gas Conservation Comm. December 19, 2017 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DATA LOGGED n4/2o1% M K.BENDER DEC 2 2 2017 RE: Leak Detect Log with ACX: 1A-12 AO G C C Run Date: 9/16/2017 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-12 Digital Data in LAS format, Digital Log file, Interpretation Report 1 CD Rom 50-029-20688-00 Leak Detect Log with ACX(Processed Log) 1 Color Log 50-029-20688-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari o 6900 Arctic Blvd. ` , 0D " Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: Signed:/ , / _� ��. • • RECEIVED STATE OF ALASKA NOV 0 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend _ Perforate Other Stimulate _ Alter Casing _ Change Approved Program — Plug for Redrill _ erforate New Pool Repair Well ✓ Re-enter Susp Well _ Other: tbg patch ✓ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. ment Develo p ❑ Exploratory ❑ 181-178 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-029-20688-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU 1A-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured $865 feet Plugs measured None feet true vertical 6,761 feet Junk measured None feet Effective Depth measured $262 feet Packer measured 7,815 feet true vertical 6,210 feet true vertical 5,822 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 feet 16 " 80' MD 80' SURFACE 2,690 feet 10 3/4" 2,721'MD 2467' PRODUCTION 8,822 feet 7 8,852'MD 6748' Perforation depth Measured depth 7948'-8262' feet True Vertical depth 5937'-6210' feet s g DEQ 9 Tubing(size,grade,measured and true vertical depth) 3.5" L-80 8,174'MD 6,133'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-FHL RETRIEVABLE PKR 7,815'MD 5,822'TVD PACKER-BAKER"F-1"PKR 8,130'MD 6,095'TVD SAFETY VLV-TRMAXX-5E SCSSV 2,065'MD 2,012'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: N/A N/A N/A N/A N/A Subsequent to operation: N/A N/A N/A N/A N/A 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory ❑ Development ❑ Service E Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: #317-457 Authorized Name: Kelly Lyons Contact Name: Kelly Lyons/Jan Byrne Contact Email: n1617@cop.com Authorized Title:Well Integrity Supervisor , Contact Phone: (907)659-7224 Authorized Signature: `Qi( ) Date:11/1/17 tori . /z/71/7- d% Form 10-404 Revised 4/2017 /2.447 RBDIVIS LU NU `, 201 Submit Original Only • • RECEIVED ConocoPhillips Alaska NOV 03 2017 P.O. BOX 100360 AO G C C ANCHORAGE,ALASKA 99510-0360 November 1, 2017 Commissioner Hollis French Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner French, Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. KRU well 1A-12 (PTD 181-178) for a retrievable tubing patch used to repair a known leak above the production packer. Work was performed under Sundry#317-457. Please call Jan Byrne or myself at 659-7224 if you have any questions. Sincerely, i Kelly Lyons Well Integrity Supervisor Attachments • 1A-12 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/27/17 Well reported to AOGCC and shut in for suspect TxIA communciation. 08/28/17 BRUSH n' FLUSHED TBG DOWN TO 7989' RKB; SET 2.81"XX PLUG W/FILL EXT @ 7927' RKB; DDT TBG X IA TO 1000 PSI (PASS); CMIT TBG X IA TO 3200 PSI (PASS); SET 2.75" AVA CATCHER @ 7926' RKB. JOB COMPLETE &TURN OVER TO DHD. BEGIN DDT. INITIAL T/1/0=2640/2520/140. FLOWLINE= 2600. TEST= 1000/2265/140. FLOWLINE= 1050. 15 MIN= 2020/1950/140. FLOWLINE=2000. 30 MIN=2040/1915/140. FLOWLINE= 2000. BEGIN DDT. INITIAL T/I/O= 2640/2520/140. FLOWLINE=2600. TEST= 1000/2265/140. FLOWLINE= 1050. 15 MIN=2020/1950/140. FLOWLINE= 2000. 30 MIN= 2040/1915/140. FLOWLINE= 2000. DDT#2. INITIAL T/1/0= 2040/1950/140 FLOWLINE= 2000. TEST= 975/1000/140 FLOWLINE= 1000. (BLED IA SIMULTANEOUSLY). 15 MIN= 1075/1000/140 FLOWLINE= 1050. 30 MIN= 1100/1000/140 FLOWLINE= 1050. PASS. BEGIN CMIT (PUMP INTO TBG &JUMP TO IA) INITIAL T/1/0= 1100/1000/140 FLOWLINE= 2800 TEST= 3220/3200/160 FLOWLINE= 3200 (2.8 BBLS). 15 MINS= 3240/3160/160 FLOWLINE= 3240 30 MINS= 3240/3150/160 FLOWLINE= 3240. CONFER W/CWG REP. PASS. BLEED TBG & IA TO 1000 PSI. 08/30/17 (AC EVAL): T POT (PASSED), IC POT(PASSED). Initial T/1/0/00 = SI 910/678/130/0+. Control line 1450 psi. Bled OOA to 0 psi in 5 sec(Gas). 1/1/0/00 = 910/678/130/0. Cracked slotted bleeder on T PO TP with an unknown amount of pressure, bled to 0 psi (control line tracked T PO). 15 min reading: unknown amount of pressure, CL had 20 psi, re-bled T PO TP and CL to 0 psi. 15 min reading: 0 psi, CL @ 0 psi. Cracked slotted bleeder on IC PO TP with an unknown amount of pressure, bled to 0 psi. 15 min reading: 0+ psi. Final T/I/O = SI 910/678/130/0. • 1 A-12 • DESCRIPTION �gOu�FMMWORK COMPLETED 08/31/17 (AC EVAL) : POT-IC Passed, PPPQT=IC Passed, MIT-T Failed (IA tracking), LLR-T @ 5.1 gpm @ 2925 psi, MIT-IA Failed (T tracked), LLR-IA @ 5.6 gpm @ 3000 psi. Initial T/I/O/OO = si800/573/132/0. SSSV @ 30 psi. Flowline @ 1025 psi (double blocked). T FL @ surface. IA FL @ surface. Cracked IC-PO TP slotted bleeder w/0+ psi. Pressured IC-PO to 3000 psi. 15 min 2890 psi. (-110). 30 min 2825 psi. (-65). Re-pressured IC-PO to 3000 psi. 15 min 2925 psi. (-75). 30 min 2910 psi. (-15). Passed. Attempted to pressurize T, IA tracking, hold IA on open bleed, Preformed LLR-T x IA @ 5.1 gpm @ T/I/O/OO =2925/300/130/0 (pumped continuously w/tri- plex). WV leaks &tracks T pressurel:1, flowline is double blocked in wellhouse w/a gauge between blocks, gauge maintained 2550-2575 psi through the job. SSSV pressure fluctuated through the job w/a high of 210 psi. Attempted to pressurize IA, T tracking, hold T on open bleed. Preformed LLR-IA x T @ 5.6 gpm @ T/I/O/OO = 150/3000/135/0 (pumped continuously w/tri- plex). Bled T&IA to 500/440 psi. Final T/I/O/OO = si500/440/130/0. 09/16/17 LEAK DETECT LOG WOTH ACX: RIH @ 100FPM FOR BASELINE TEMP TO 7927' RKB, LRS PUMP DIESEL DOWN TUBING TAKING RETURNS FROM IA TO TANK, LEAK RATE OF 5.5 GPM @ 3000PSI ESTABLISHED, PEFORM REPEAT PASS @ 20FPM OVER INTERVAL 7927' -7598' RKB, PERFORM MAIN PASS @ 20FPM FROM 7927'TO SURFACE, MULTIPLE STATION STOPS PERFORMED BETWEEN 4937' -4898' RKB, LEAK SIGNATURE AT 4912', LEAK RATE INCREASED DURING LOGGING TO 9.5GPM @ 3000PSI 09/17/17 24 ARM CALIPER LOG: PERFORM REPEAT PASS OVER INTERVAL 7910' -7700' RKB, PERFORM MAIN PASS OVER INTERVAL 7910' -SURFACE 10/21/17 SET LOWER 2.72" P2P WITH AGGRESSIVE SLIPS (#CPP35133) MID ELEM @ 4920' RKB. CMIT TO 2500 (PASS). ATTEMPT TO SET UPPER PATCH SECTION (POWER CHARGE DID NOT IGNITE). IN PROGRESS. 10/22/17 SET 2.72" P2P (#CPP35135), SPACER PIPE, ANCHOR LATCH (#CPAL35067/30.86' OAL) MID ELEM @ 4890' RKB. SET TEST TOOL IN PKR @ 4890' RKB. MITT TO 2500 (PASS). MITIA TO 2500 (PASS). JOB COMPLETE. MITT TO 2500. PRE T/I/O/OO= 1850/1775/120/0. PSI UP w/0.1 BBLS. START= 2525/1790/140/0 15 MIN= 2475/1790/140/0 30 MIN= 2460/1790/140/0. MITIA TO 2500. PRE T/I/O/OO=2510/1800/140/0, PSI UP w/0.6 BBLS. START= 2560/2525/140/0 15 MIN=2560/2500/140/0 30 MIN=2560/2500/140/0. • 1A-12 • DESCRIPTION OF WORKRRyyCOMPLETED 10/31/17 (SW) : State Witnessed (Lou Laube sielliA IT-lA to 3000 psi Post Patch (Passed). Initial T/I/0/00 =2345/560/740/0. IA FL @ SF. LRS pressured IA to 3000 psi w/2.7 bbls diesel. Starting T/I/0/00 =2345/3000/917/0. 15 min T/I/0/00 =2345/2950/915/0 (-50). 30 min T/I/0/00 =2345/2935/914/0 (-15) LRS bled IA to 560 (2.7 bbls). LRS continued to bleed IA to 400 psi. Final T/I/0/00 =2345/400/724/0. Summary A 30' TTS retrievable tubing patch from 4890'-4920'was set across an identified tubing leak at 4912'. Integrity of the patch was confirmed with passing AOGCC-witnessed MITIA on 10/31/17. KUP INJ ! 1A-12 ConocoPhillips 06 Well Attributes Max Angle&MD TD -..4111 Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(") MD(ftKB) Act titre(ftKB) axya,pn 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000.00 8,865.0 ••• Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1A-12,10/31/20173:41:47 PM SSSV:TRDP _ Last WO: 6/27/2008 39.01 1/6/1982 Vertical schemafc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date .........................................................................................................._...._...Last Tag:SLM 8,222.0 7/26/2015 Rev Reason:PULL PLUG&CATCHER,SET 2 pproven 10/26/2017 PATCHES&LEAK(SEE NOTES) Casing Strings """-"""•""""'- HANGER;27.1"'-"""'"'-" "Casing Description OD(in) ID(in) Top(665) Set Depth(6KB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H-40 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(665) Set Depth(TVD)...Wt/Len(I...Grade Top Thread tty..raeaaam�anaay ,I._ PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K-55 Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..I Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2008 31/2 2.992 27.1 8,181.7 6,139.7 9.30 LBO 31/2 "AAA.CONDUCTOR;33.0-80.0 Completion Details Nominal ID Top(ftKB) Top(TVD)(11K3) Top Ind(") Item Des Com (in) SAFETY WV;2,065.0 psjj!t 27.1 27.1 0.35 HANGER TUBING HANGER 3.500 2,065.0 2,011.8 34.02 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.5 31.15 PBR BAKER PBR 3.000 7,814.8 5,821.9 31.02 PACKER FHL Retrievable Packer 2.930 SURFACE;31.2-2,721.0-' 7,926.5 5,918.1 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 n 8,128.0 6,092.9 29.55 SEAL ASSY Seal Assy w/2'spaceout 3.000 U PATCH;4,890.0 I 8,130.0 6,094.7 29.52 PACKER Baker"F-1"Packer 4.000 n 8,133.4 6,097.6 29.49 SBE SBE 4.000 PATCH;4,920.0 U I 8,137.7 6,101.3 29.44 Bottom Sub 2.950 8,173.7 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 8,174.7 6,133.6 29.04 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out 2.950 GAS LIFT;7,7432 1 4 Sub w/Tubing Pup) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (") Des Com Run Date ID(in) 4,890.0 3,751.3 54.03 PATCH '2.72"P2P(#CPP35135),SPACER PIPE,ANCHOR 10/21/2017 1.690 LOCATOR;7,799.1 I ) LATCH(#CPAL35067/30.86'OAL ME @ 4890'RKB PBR;7,801.5 4,920.0 3,768.9 54.05 PATCH 2.72"P2P w/AGGRESSIVE SLIPS(#CPP35133/ 10/21/2017 1.690 la 4.01'OAL) • PACKER;7,814.8 ..-in @ 4920'RKB 7,989.0 5,972.3 29.86 PATCH UPPER PATCH ASSY 2.72"PARAGON II PACKER 1/26/2016 1.610 (SERIAL#CPP35005,12.69'SPACER PIPE,LATCH SEAL ASSY SERIAL#CPAL35011(OAL-18.46') @7989'(MID ELEMENT) SLEEVE-C;7,926.5 - - 'PATCH IS 17 ELEMENTS TO ELEMENTS;MIN ID- 1.61" 2.72"PARAGON II PACKER(SERIAL#CPP35008) in Tbg @ 8006'(MID ELEMENT)RKB(OAL=3.93) PATCH;7,989.0• O IPERF;7.948.0-8,057.04 8,066.0 6,039.1 29.84 PATCH PBR AND SPACER PIPE IN LOWER ANCHOR@ 1/9/2016 1.600 8,108'RKB --, STATEWIDE 2.72"PARAGON II PACKER(ser.# CPP35014),19.5'SPACER PIPE,UPPER PACKER IPERF;8,062.0-8,071.0- • @ 8,066'RKB CENTER ELEMENT PATCH Is 42'OAL OVER INTERVAL 8,066'-8,108' PATCH;8,056.0 IPERF;8,100.0-8,104,0 2.72"PARAGON II PACKER(SER#;CPP35030) 8,286.0 6,231.6 27.56 RSH Brown'1B'PACKER-Caliper 3/8/07 shows approx. 8/27/1985 2.000 2"ID;CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER IPERF;8,120.0-8,124.0 8,310.0 6,252.9 27.15 FISH DMY half of 1"DMY laying @-8252 RKB 12/26/1991 6,502.0 6,426.4 24.14 FISH Vann Gun 1/6/1982 SEAL ASSY;E.12e.0 = Perforations&Slots PACKER;8,130.1 Shot am SBE;8,133.4 - Dens Top(TVD) Blot(TVD) (shots/( I Top(ftKB) Blot IRKS) (ftKB) (ftKB) Zone Date 1) Type Com 6 I. 7,948.0 8,057.0 5,936.7 6,031.3 C-1,C-2,C-3,C 1/6/1982 4.0 IPERF 4"Vann Guns -4,1A-12 CementSOZ;8,182.0 ftKB 8,062.0 8,071.0 8,035.6 6,043.4 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns CMT SOZ;8,182.0-8,184.0 .; 8,100.0 8,104.0 6,066.6 6,072.0 UNIT B,IA- 1/6/1982 4.0 IPERF 4"Vann Guns 12 NIPPLE;8,173.7 ' t 8,120.0 8,124.0 6,085.9 6,089.4 UNIT B,IA- 1/6/1982 4.0 IPERF 4"Vann Guns SOS;8,174.7 er j 12 8,162.0 8,164.0 6,122.5 6,124.3 UNIT B,1A- 8/20/1985 4.0 CMT - 12 SOZ IPERF;8,219.0-8,223.0 8,219.0 8,223.0 6,172.4 6,176.0 A-5,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns 8,233.0 8,262.0 6,184.8 6,210.3 A-4,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns IPERF;8,233.0-8,262.0--" Cement Squeezes Top(ND) Rho(ND) Top(ftKB) Stm(ftKB) (ftKB) (ftKB) Des Start Date Com FISH;8,286.0 - _- 8,162.0 8,164.0 6,122.5 6,124.3 Cement Squeeze 8/21/1985 FISH;8,310.0 Mandrel Inserts St eli FISH;8,602.0 N Top(ftKB) Top D) Valve Latch PoSize T(ftKB) Make Model 00(in) Sery Type Type o n) (psi) n Run Date Com 1 7,743.2 5,760.8 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 PRODUCTION;29.7-0,852.0 KUB' 8NJ • 1A-12 ConocoPhillips02 , Alaska,Inc. ca«avw®fc • 1A-12,10/31/2017 3:41'49 PM Vertical schematic(actual) Notes:General&Safety '-"""""`-_""""""HANGER;27./"""'""`"'�� "'"'--•- End Date Annotation 8/27/1985 NOTE:WORKOVER 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION ' a 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 "" 612 012 01 0 NOTE:WAIVERED WELL IAx OA COMMUNICATION 2/17/2013 NOTE:LEAKS FOUND @ 8072&8090 10/26/2017 NOTE:SMALL TUBING LEAK @4912',found with ACX-LDL .AAACONDUCTOR;33.0-80.0 - SAFETY VLV;2,065.0 �i SURFACE;31.2-2,721.0--- PATCH; 12-2,721.0-PATCH;4,890.0 �U U PATCH;4,920.0 U O GAS LIFT;7,743.2 V c LOCATOR;7,799.1 f PER;7,801.5 PACKER;7,814.8 SLEEVE-C;7,926.5 n H; , p IPERF;PATC7,948.0-87,057.0- 989.0, IPERF;8,082.0-8,071.0- PATCH;8,066.0 IPERF;8,100.0-8,104.0- _ IPERF;8,120.0-8,124.0--4 SEAL ASSY;8,128.0 PACKER;8,130.1 SBE;8,133.4 Cement SOZ;8,162.011(08 FA CMT SOZ;8,162.0.8,164.01 NIPPLE;8,173.7 SOS;8,174.7---r' IPERF;8,219.0-8,223.0--- I _I I IPERF;8,2330-8,262.0 I FISH;8,286.0 FISH;8,310.0 FISH;8,502.0 PRODUCTION;29.7.8,852.0 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq[a alaska.gov AOGCC.Inspectors(Sialaska.gov phoebe.brooks@alaska.gov chris.wallace(a�alaska.gov OPERATOR: ConocoPhillips Alaska Inc, FIELD/UNIT/PAD: Kuparuk/KRU/1A Pad DATE: 10/31/17 OPERATOR REP: Duffy/Phillips AOGCC REP: Lou Laubenstein Well 1A-12 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1811780 Type Inj W Tubing 2345 2345 2345 2345 Type Test P Packer TVD 5822 BBL Pump 2.7 IA 560 3000 2950 2935 Interval 0 Test psi 1500 BBL Return 2.7 OA 740 917 915 914 Result P Notes: MITIA post patch per Sundry#317-457 Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 1A-12 10-31-17.xlsx • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To Jim Regg DATE: Thursday,November 02,2017 P.I.Supervisor (C 11/7/i 7 SUBJECT: Mechanical Integrity Tests I CONOCOPHILLIPS ALASKA,INC. 1A-12 FROM: Lou Laubenstein KUPARUK RIV UNIT 1A-12 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry J! — NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-12 API Well Number 50-029-20688-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-178-0 Inspection Date: 10/31/2017 Insp Num: mitLOL171031133036 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------Well 1A-12 Type Inj W TVD 5820 - Tubing 2345 - 2345 ' 2345 2345 " PTD 1811780 'Type Test SPT 1Test psi 1500 - IA 560 3000 - I 2950 ' 2935 - - BBL Pumped: r 2.7 - ITIBL Returned: 2.7 - OA 1 740 917 - 915 ` 914 - Interval OTHER P/F P ✓ — — Notes: MITIA post patch per Sundry#317-457 v SKI + t4En ER ' 0 1'';ln Thursday,November 02,2017 Page 1 of 1 OF T4 wP' Ij7,,sA THE STA,E • „���/�� f® LAsKA. Alaska Gil and Gas �` "�'+ 1-9'' of 1 '”' �� Conservation Commission P GOVERNOR BILL WALKER 333a West AlaskaSek99 01-35 Avenue O� Anchorage, 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Jan Byrne Nov 2 w 2ii Well Integrity Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-12 Permit to Drill Number: 181-178 Sundry Number: 317-457 Dear Mr. Byrne: 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, dpar — Hollis S. French Chair DATED this ( day of October, 2017. RBDMS LW" 01;i 1 3 2017 • • RECEIVED IVED STATE OF ALASKA SEP 2 6 2 17 • ALASKA OIL AND GAS CONSERVATION COMMISSION ars lot e 3fr APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 I, 1.Type of Request: Abandon H Plug Perforations ❑ Fracture Stimulate H Repair Well u Operations shutdown H Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ "rV b0I Patch/ Other: ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 181-178 " 3.Address: Stratigraphic ❑ Service Q . 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 _ 500292068800 ' _ 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA- Will planned perforations require a spacing exception? Yes ❑ No u •llh KRU 1A-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025647• 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): 8,865' ' 6,761' • 7927' . • 5918' 7927' Casing Length Size MD TVD Burst Collapse Structural Conductor 47' 16" 80' Surface 2,690' 13" 2,721' Intermediate Production 8,822' 7" 8,852' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7948'-8262' ' 5937'-6210' 3.500" L-80 8,174' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-FHL RETRIEVABLE PACKER • MD=7815 TVD=5822 PACKER-BAKER"F-1"PACKER • MD=8130 TVD=6095 SAFETY VLV-TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 ' MD=2065 TVD=2012 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service Q 14.Estimated Date for 10/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ Q - WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned H 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: Jan Byrne Contact Name: Jan Byrne Authorized Title: Well Integrity Supervisor Contact Email: N1617@conocophillips.com Contact Phone: 907 659 7224 Authorized Signature: c_ Date: 9/24/2017 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ErNo ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /a—'4(, OCT `-,i w RB®�S 1.-- C�� 1 NV 00( APPROVED BY I Approved by: COMMISSIONER THE COMMISSION Date: t O , r/ vr,_ ,,,, ,,.., ,R i � A� Submit Form and Form 10-403 Revised 4/2017 ' d'e----$/r rs valid for 12 months from the date of approval. Attachments in Duplicate • • • • ConocoPhillips RECEIVED Alaska SEP 2 6 2017 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360AOGC September 24, 2017 Commissioner Hollis S. French Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner French, Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. well 1A-12 (PTD# 181-178). The request is for approval to set a tubing patch to regain tubing integrity. If you need additional information, please contact myself or Kelly Lyons at 659-7224. Regards, J. Byrne Well Integrity Supervisor • • 1A-12 • DESCRIPTION SUMMARY OF PROPOSAL KRU water injection well 1A-12 (PTD# 181-178) goverened by AIO 2B.049 was reported to the AOGCC on 8- 27-17 for an unexplained IA pressure increase. The well was secured and diagnostics located the tubing leak at 4912'. CPA intends to set a retrievable tubing patch over the leak to repair tubing intetgrity. Post installation of the tubing patch the well will be brought online and stablized for a state witnessed MITIA. Repair Plan 1. Set—30' retrievable patch in tubing. 2. Perform MIT-T above patch and MIT-IA. 3. With passing tests the well will be brought online for stabilization. 4. Perform SW MIT-IA. 5. Submit 10-404 post passing SW MIT-IA. pc/ a 7/ �'A • KUP INJ °� �/ 1A-12 19. �illipss Well Attributes Max Angle&MD TD - Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(1KB) Act Btm(ftKB) ,_ 0,, 500292068800 KUPARUK RIVER UNIT INJ 5670 4,000.00 8,865.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-12,9/6120 17 11 2 5:13 AM SSSV:TRDP Last WO- 6/27/2008 39.01 1/6/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,222.0 7/26/2015 Rev Reason.SET PLUG&CATCHER pproven 9/6/2017 0%1 Casing Strings HANGER,27.1 Casing Description OD(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WULen(L..Grade Top Thread PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 1<-55 IUL I Tubing Strings Tubing Description )String Ma...l ID(in) !Top(FMB) )Set Depth(6..i Set Depth(TVD)(...1WI(lb/ft) (Grade (Top Connection TUBING WO 2008 3 1/2 2.992 27.1 8.181 7 6.139.7 9.30 L-80 3 1/2 Jv./AACONDUCTOR;33.0-80.0• 1 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) SAFETY VLV;2,065.0 27.1 27.1 0.35 HANGER TUBING HANGER 3.500 2,065.0 2,011.8 34.02 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.5 31.15 PBR BAKER PBR 3.000 7,814.8 5,821.9 31.02 PACKER FHL Retrievable Packer 2.930 7,926.5 5,918.1 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 SURFACE;31.2-2,721.0-' A 8,128.0 6,092.9 29.55 SEAL ASSY Seal Assy w/2'spaceout 3.000 8,130.0 6,094.7 29.52 PACKER Baker"F-1"Packer ' 4.000 GAS LIFT;7,743.2-ilk8,133.4 6,097.6 29.49 SBE SBE 4.000 8,137.7 6,101.3 29.44 Bottom Sub 2.950 8,173.7 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 8,174.7 6,133.6 29.04 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out ' 2.950 LOCATOR;7,799.1 Sub w/Tubing Pup) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) PBR;7,801.5 Top(TVD) Top Ind Top(MB) (ftKB) ("( Des Com Run Date ID(in) PACKER;7,814.8 7,926.0 5,917.7 30.10 CATCHER '2.75"AVA CATCHER ON XX PLUG 8/28/2017 0.000 7,927.0 5,918.6 30.10 XX PLUG 2.81"XX PLUG W/FILL EXT(EQ SUB HAS SIX 8/28/2017 0.000 - 1/16"PORTS,AND TWO 3/16"PORTS)(47"OAL) (XX PLUG IN CMU) CATCHER:],9260 7,989.0 5,972.3 29.86 PATCH UPPER PATCH ASSY 2.72"PARAGON II PACKER 1/26/2016 1.610 (SERIAL#CPP35005,12.69'SPACER PIPE,LATCH SLEEVE-C;7,926.5-, ° SEAL ASSY SERIAL#CPAL35011(OAL-18.46') XX PLUG;7,927.0 i @7989'(MID ELEMENT) t. 'PATCH IS 17 ELEMENTS TO ELEMENTS;MIN ID- 1.61" 2.72"PARAGON II PACKER(SERIAL#CPP35008) in Tbg @ 8006'(MID ELEMENT)RKB(OAL=3.93) 7,98. ;I O (PERF;7,948PATCH;.0-8,0579.00 i.., 8.066.0 6,039.1 29.84 PATCH PBR AND SPACER PIPE IN LOWER ANCHOR@ 1/9/2016 1.600 8,108'RKB STATEWIDE 2.72"PARAGON II PACKER(ser.# CPP35014),19.5'SPACER PIPE,UPPER PACKER (PERF;9,062.0-8,071.0- @ 8,066'RKB CENTER ELEMENT PATCH is 42'OAL OVER INTERVAL 8,066'-8,108' PATCH;8,086.0 2.72"PARAGON II PACKER(SER it;CPP35030) IPERF;8,100.0-8,104.0 I 8286.0 6.231.6 27.56 FISH Brown'1E'PACKER-Caliper 3/8/07 shows approx. 8/27/1985 2.000 2"ID;CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER IPERF;8,1200-9,124.0-- 8.310.0 6.252.9 27.15 FISH •DMY half of 1"DMY laying @-8252 RKB 12/26/1991 yr 8.502.0 6.426.4 24.14 FISH 1Venn Gun 1/6/1982 SEAL ASSY;8,128.0PI - Perforations&Slots PACKER;8,130.1 Shot Dens SBE;8,133.4 .'p Top(TVD) Btm(ND) (shots/t Top(ftKB) Btm(RKB) (MB) (RKB) Zone Date t) Type Corn 7,948.0 8,057.0 5,936.7 6,031.3 C-1,C-2,C-3,C 1/6/1982 4.0 IPERF 4"Vann Guns -4,1A-12 8,062.0 8,071.0 r 6,035.6 6,043.4 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns Cement SOZ;8,182.0 t6B • CMT Ka;8,162.0.8,184.0 - ✓ 8,100.0 8,104.0 SO6,068.6 6,072.0 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns 12 NIPPLE;8,173.7 8,120.0 8,124.0 6,085.9 6,089.4 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns • ' 12 SOS;8,174.7 IF 8,162.0 8,164.0' 6,122.5 6,124.3 UNIT B,1A- 8/20(1985 4.0 CMT 12 SQZ IPERF;8,219.0-8,223.0-, 8,219.0 8,223.0" 6,172.4 6,176.0 A-5,1A-12 1/6/1982 - 4.0 IPERF 4"Vann Guns • 8,233.0 8,262.0 6,184.8 6,210.3 A-4,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns Cement Squeezes (PERF:8,233.0-8,262.0- • Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (FMB) (kKB( Des Start Date Com 8,162.0 8,164.0 6,122.5 6,124.3 Cement Squeeze 8/21/1985 FISH;8.286.0 Mandrel Inserts FISH;8,310.0 St ali on Top(ND) Valve Latch Port Size TRO Run FISH;8,502.0 N Top(ftKB) (FMB) Make Model 00)/n) Sery Type Type (in) (psi) Run Date Com 1 7.743.2 5,760.8 CAMCO MMM 11/2 GAS LIFT -DMY RK 0.000 0.0 7/6/2008 Notes:General&Safety End Date Annotation 8/27/1985 NOTE:WORKOVER PRODUCTION;29.7-8,852.0 • \\ KUP INJ • 1A-12 ConocoPhiIIips �A Alaska,Inc. COnondiPt011Ipa 14-12,9/6/2017 112514 AM Vertical schematic(actual) Notes:General&Safety Annotation } 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 ,• 6/20/2010 NOTE:WAIVERED WELL IA x OA COMMUNICATION alum 2/17/2013 NOTE:LEAKS FOUND @ 8072&8090 .A.AACONDUCTOR;33.0-80.0A-41,v. SAFETY WV:2065.0 '. SURFACE;31.2-2,7210-� GAS LIFT;7,7432_ - LOCATOR;7,799.1 { PER',7,801.8 PACKER;7014.8 CATCHER;7,926.0 _P SLEEVE-C:7926.5 C XX PLUG;7,927.0 (PERF; PATCH:7,0 .00, p i I I (PERF;8,062.0-6071.0- PATCH;8,066.0- i • I IPERF;8,100.0-8.104.0- I I II IPERF;8,120.0-8,1240- rI I SEAL ASSY;8,128.0 F PACKER;8,130.1 SBE;8.133.4 Cement SOZ;8,162.0 fIKB CMT SO2;8,162.0.8,164.0 '. NIPPLE;8,173.7 SOS;8,174.7 IPERF;8,219.00,223.0 IPERF;8,233.0-8,262.0- FISH;8,2800 FISH;8,310.0 FISH;8,502.0 PRODUCTION;29.7.8,852.0 /III • • Bettis, Patricia K (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Thursday, September 28, 2017 3:21 PM To: Bettis, Patricia K (DOA) Subject: RE: [EXTERNAL]KRU 1A-12 (PTD 181-178): Sundry Application Attachments: 1A-12 schematic.pdf Here you go. Thanks Kelly Lyons/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Mobile Phone (907)943-0170 From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent:Thursday, September 28, 2017 2:21 PM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: [EXTERNAL]KRU 1A-12 (PTD 181-178): Sundry Application Good afternoon Jan, Please submit a current wellbore schematic for KRU 1A-12. The schematic may be sent to me via email. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Ste 100 Anchorage,AK 99501 Tel: (907)793-1238 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). It 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 it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 1 bo • • , r � N 1T G 00 x co a). v ° o Q Y h w r0 La Y o -° E 0Nz O C v � > r m u° co a c oc v `o da a c >, - Y (o 4_, co •O +� :6 Q .. 0 0 +�' OU E a 6 m 0 N N N CO N N N N N C -C N 41 - W O O r N Ur CO CO °Z Q< 0 \ U E' > 6 N o c ro t5 ro ,- N U 0 0 0 0 0 0 Ct 0 O v L W J J J J J J J J c O y W W W W W W W W 0 cy 'C U "- F- LL LL LL LL LL LL LL LL +-, (2) N a) TS Cr F- Q Q Q Q Q Q Q Q .- C ,� w Z G, < Z Z Z Z Z Z Z z U m v 0 CU c, a1 L a) �, > .. LL LL LL LL LL LL LL LL CY � � C OW9 - (D � > ate'' a) 5 0 a s o O 2 0 0- a) V > r' O c o m es cv �. „y G, 3 2 a) Y 'U L C O r a cc m a o 0 a; r u Q v a v, C a Ir w a) LL d LL d a) d ).4 0 a0 a2 a a a a, m V is a m a in �a �a y m U U a U U U O C, a► op U . 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E d es E la = E2 N T. n z _i S Y Y Y Q Q Q E ca t- a c w a < O N M N N N N E z N co • ' '-1 W cCla ~ G 3 a CV no E Q 0 VO ait • • Wallace, Chris D (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Sunday, August 27, 2017 3:41 PM To: Wallace, Chris D (DOA) Cc: Senden, R.Tyler; NSK Well Integrity Supv CPF1 and 2 Subject: KRU 1A-12 (PTD#181-178) Report of suspect IA pressurization Attachments: 1A-12.pdf; 1A-12 90 day TIO trend 8-27-17.PNG Chris, KRU water injector 1A-12 (PTD#181-178)exhibited an unexplained increase in IA pressure today. Operations attempted to bleed down the IA pressure without success. The well has been shut in and freeze protected. DHD will perform initial diagnostics to include an MITIA, pack off tests,and draw down the IA pressure. If diagnostics pass the well may be placed on a 30 day monitor period once brought on injection. Any required paperwork for corrective action or continued injection will be submitted subsequent diagnostics or the monitor period. Attached is a 90 day TIO trend and wellbore schematic. Please let us know if you disagree or have any questions with this plan. Regards, Jan Byrne/Kelly Lyons Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7224 WELLS TEAM s441o ) P 1 5 Z 017 17 conoaol'hiipa 1 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,July 18,2017 TO: Jim Regg j J P.I.Supervisor I 61 2 71 z E'I(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-12 FROM: Jeff Jones KUPARUK RIV UNIT IA-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-12 API Well Number 50-029-20688-00-00 Inspector Name: Jeff Jones Permit Number: 181-178-0 Inspection Date: 7/8/2017 Insp Num: mitJJ170718102511 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 ' Type Inj W' TVD 5820 ' Tubing 2620 ' 2625 T 2625 - 2625 PTD 1811780 - Type Test SPT Test psi 3000 IA 750 3310 - 3240 3220 - BBL Pumped: 2.5 ' BBL Returned: 2.4 OA 558 - 753 763 769 - Interval REQVAR P/F P ✓ Notes: AIO 02B.049 IA x OA communication.2 Year MIT-IA SCANNED SEP 2 52017 Tuesday,July 18,2017 Page 1 of 1 • I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,July 18,2017 Jim Regg P.I.Supervisor �19c3 7(Z `(7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 1A-12 FROM: Jeff Jones KUPARUK RIV UNIT 1A-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J f NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-12 API Well Number 50-029-20688-00-00 Inspector Name: Jeff Jones Permit Number: 181-178-0 Inspection Date: 7/8/2017 Insp Num: mitJJ170718113022 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 'Type Inj W 1TVD 5820 Tubing 2610 -I 2600 ' 2600 ` 2600 PTD 1811780 T e Test SPT Test psi 1800 IA 802 897 ' 889 ' 889 - BBL Pumped: 1.3 1BBL Returned: 1.1 OA 580 2000 1910 1890 Interval REQVAR P/F P ✓ Notes: AIO 02B.049 IA x OA communication.2 Year MIT-OA • SCANNED SEP 2 5201? Tuesday,July 18,2017 Page 1 of 1 MAY 06 20b WELL LOG TRANSMITTAL#903130768 it€iN'' To: Alaska Oil and Gas Conservation Comm. April 27, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATA LOGGED Mt. K.BENDER RE: Leak Detect Log: 1A-12 Run Date: 2/16/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20688-00 Leak Detect Log (Field Print) 1 color log 50-029-20688-00 SCANNE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,February 26,2016 TO: Jim Regg / 3('�1(o P.I.Supervisor SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 1A-12 FROM: Jeff Jones KUPARUK RIV UNIT 1A-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-12 API Well Number 50-029-20688-00-00 Inspector Name: JeffJones Permit Number: 181-178-0 Inspection Date: 2/20/2016 Insp Num: mitJJ160221072127 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 Type Inj W`TVD 5822 ` Tubing 2633 - 2645, 2651 - 2644 • PTD 1811780 Type Test SPT Test psi 3000 IA 551 3310 3230 - 3220 - Interval REQVAR P/F P ✓ OA 502 692 . 692 • 697 . Notes: MITIA to max.anticipated injection pressure per AIO 2B.049 due to known IA X OA communication. SCANNED SEP 2 6 2016 Friday,February 26,2016 Page 1 of 1 1110 S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday,February 26,2016 Jim Regg I 1 317/Ko P.I.Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-12 FROM: Jeff Jones KUPARUK RIV UNIT 1A-12 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A-12 API Well Number 50-029-20688-00-00 Inspector Name: Jeff Jones Permit Number: 181-178-0 Inspection Date: 2/20/2016 Insp Num: mitJJ160221072812 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 - Type Inj W TVD 5820 ' Tubing 2620 2645 - 2643 • 2645 PTD 1811780 Type Test SPT Test psi 1800 , IA 581 660• 683 ' 703 - Interval REQVAR P/F P / OA 498 2000 1860 - 1849 Notes: MIT-OA to 1800 psi per AIO 2B.049 due to known IA X OA communication. %WED SEP 2 6 2016 Friday,February 26,2016 Page 1 of 1 er61 -k • z.G:.1Y‘ WELL LOG TRANSMITTAL#903006220 To: Alaska Oil and Gas Conservation Comm. February 19, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECEIVED DATA LOGGED q EB '�+ 2016 3 K BENDER AOGCC RE: Injection Profile : 1A-12 Run Date: 12/21/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20668-00 Injection Profile Log 1 Color Log 50-029-20668-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Fanny Sari SCANNED rs 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: `V✓ ncv • • PTD 181 -17- 4 Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Tuesday, February 16, 2016 4:21 PM To: Loepp, Victoria T(DOA) Subject: RE: Question re 1A-12 Tubing Patch 10-404 Filing(PTD 181-178) Follow Up Flag: Follow up Flag Status: Flagged Thanks Victoria. I will send over the 10-404 for the 1A-12 tubing patch installations. I really appreciate your_help. John Peirce From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 16, 2016 4:07 PM iCA NNEii To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]Re:Question re 1A-12 Tubing Patch 10-404 Filing A state witnessed MIT IA is not required for this sundry. Please update your approved sundry with this change. Thanx, Victoria Sent from my iPhone On Feb 16, 2016, at 4:03 PM, Peirce, John W<John.W.Peirce@conocophillips.com>wrote: 10-14-15 MIT-IA MIT-OA PPPOT-T (Pre-RWO) T PPPOT Failed, MIT-IA Passed to 30( Victoria, We were did Pre-Rig MIT-IA to 3000 psi on 10-14-15 on 1A-12 (attached above from our Ann Comm database). The plan at the time was to move toward a possible RWO to replace a leaky C sand selective. However,the 2 patches we installed may have negated the need for the RWO for now. 1A- 12 injection data following the 2'd patch install is looking like we now have slowly increasing WHIP and total injection rate slowly declining which is indicative of achieving'A sand only PWI'for a change. We plan to run an IPROF shortly through the patches to get verification of A sand only PWI, but so far it's looking pretty good. We've patched off at least 4 or 5 leaks. Hopefully that's it for a while. John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Tuesday, February 16, 2016 3:43 PM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]Re: Question re 1A-12 Tubing Patch 10-404 Filing 1 • • When was the last MIT IA and what were the results? Sent from my iPhone On Feb 16, 2016, at 3:37 PM, Peirce, John W<John.W.Peirce(a�conocophillips.com>wrote: Hi Victoria, We completed 1A-12 tubing patch install on 1/26/16 (per 10-403 Apprvl#315-754 of 12/21/15 approved by Cathy Forester). I have a 10-404 ready to report the Patch install, but an AOGCC witnessed MITIA requested by Cathy on the 10-403 which has not yet been completed. On previous 10-403 approvals, we don't recall seeing MITIA's requested for'Non- Annular Communication'Tubing Patch installations. Is this a new requirement on 'Non- Annular Communication'Tubing Patch installs, or is there just a particular reason why this patch job requires an MITIA? I'm just curious. Here's a copy of the approved 10- 403: If the post-patch MITIA is going to be a future requirement for certain 'Non-Annular Communication'Tubing Patch installations, should I start writing in a work step in my proposed Tubing Patch install procedures to 10-403's calling for a AOGCC witnessed MITIA? Should I send the 10-404 to report the patch install now, or wait until the MITIA is performed to report that as well? Thanks, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office <1A-12 10-403 Approved Sundry Application.pdfl 2 STATE OF ALASKA AKA OIL AND GAS CONSERVATION COMISION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations Fracture Stimulate FT Pull Tubing FT Operations Shutdown F' Performed: Suspend F'' Perforate FOther Stimulate FT Alter Casing FT Change Approved Program FT Plug for Redrillr Perforate New Pool FT Repair Well FT Re-enter Susp Well F' Other:Install Tubing Patch 4 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska, Inc. Development F Exploratory n 181-178 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20688-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU1A-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8865 feet Plugs(measured) None true vertical 6761 feet Junk(measured) 8286,8310, 8502 Effective Depth measured 8762 feet Packer(measured) 7815,7989,8006,8066,8108 true vertical 6663 feet (true vertical) 5822,5972,5987,6039,6075 Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 16 80 80 0 0 SURFACE 2690 10.75 2721 2467 0 0 PRODUCTION 8822 7 8852 6749 0 0 ciliNNEC l/ '}t i 0 i- i 0 Perforation depth: Measured depth: 7948-8057,8062-8071,8100-8104,8120-8124,8162-8164,8219-8223,8233-82 True Vertical Depth: 5937-6031,6036-6043,6069-6072,6086-6089,6122-6124,6172-6176,6185 r ,,«,,.Li FEB 1 7 c ; Tubing(size,grade,MD,and TVD) 3.5, L-80,8182 MD,6140 TVD AOGCC Packers&SSSV(type,MD,and TVD) PACKER-FHL RETRIEVABLE PACKER @ 7815 MD and 5822 TVD PACKER-PARAGON 2 PACKERS @ 7989,8006,8066,8108 MD and 5972,5987,6039,6075 TVD PACKER-BAKER"F-1"PACKER @ 8130 MD and 6095 ND SAFETY VLV-TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 @ 2065 MD and 2012 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 - - 2868 - 1210 Subsequent to operation - - 1850 - 2447 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: p�: Daily Report of Well Operations F Exploratory Development F' Service F Stratigraphic Y..... Copies of Logs and Surveys Run (® 16.Well Status after work: Oil FT Gas F' WDSPL FT Printed and Electronic Fracture Stimulation Data F' GSTOR WINJ F WAG FT GINJ SUSP FT SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-754 Contact John Peircea 265-6471 Email John.W.PeirceaconocoDhillips.com Printed Name John Peirce Title Sr.Wells Engineer Signature /4/4 t2,g265-6471 Date 2/�!co i f e _ cv Form 10-404 Revised 5/2015 (77-1— 211 I IC- RBDMS Lu FEB 1 8 2016 Submit Original Only • 1A-12 • DTT,M JOBTYP SUMMARYOPS 1/5/16 TUBING/ PULLED UPPER PARAGON PACKER W/SPACER PIPE ALONG WITH MIDDLE SECTION CASING OF PATCH W/SNAP LATCH @ 8068' RKB; BRUSH n' FLUSH NEW PATCH INTERVAL PATCH DOWN TO LOWER PARAGON PACKER © 8108' RKB. IN PROGRESS (READY FOR NEW PATCH) 1/9/16 TUBING/ SET PBR AND SPACER PIPE IN LOWER ANCHOR @ 8,108' RKB CASING SET STATEWIDE 2.72" PARAGON II PACKER W/SPACER PIPE @ 8,066' RKB PATCH RAN SLB MEMORY IPROF SURVEY FROM 7,985' -8,150' SLM. JOB COMPLETE. 1/26/16 TUBING/ PERFORMED BRUSH & FLUSH FROM 7975'-8025' RKB W/3OBBLS DIESEL. SET 2.72" CASING PARAGON II PACKER @ 8006' RKB (MID ELEMENT). SET UPPER PATCH ASSY @ 7989' PATCH RKB (MID ELEMENT). *JOB IN PROGRESS 1/27/16 TUBING/ SET TEST TOOL IN TOP OF PATCH @ 7989' RKB, LRS PERFORMED PASSING MIT-T CASING TO 2500#, PULLED TEST TOOL. PATCH SET COMPLETE. PATCH *JOB COMPLETE; WELL READY TO RETURN TO 'A' SAND ONLY PWI. KU P 1 A-1 2 Conotophillips : Well Attribu Max Anglt; D TD Alaska.Inc Wellbore API/UWI Field Name Wellbore Status °) MD(ftKB) Act Btm(ftKB) « Hu,"''''l' 500292068800 KUPARUK RIVER UNIT INJ Inc!ncl 56.70 4,000.00 8,865.0 .-- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1A-12.2/15/201611-.0116 AM SSSV:TRDP Last WO: 6/27/2008 39.01 1/6/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,222.0 7/26/2015 Rev Reason:SET PACKER and PATCH pproven 2/11/2016 i Casing Strings HANGER 27.1" ° Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I G d ' Top Thread CONDUCTOR 16 15.063 33.0 80.0 800 6500 H 40 ,i. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(L..Grade Top Thread SURFACE 10 3/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len ...Grade Top Thread I ° 0PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K-55 ' Tubing Strings III, i Tubing Description String Ma...ID(in) Top(0KB) Set Depth(ft.. Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 2008 31/2 2.992 27.1 8,181.7 6139.7 9.30 LOU 31/2 Completion Details J�/\,CONDUCTOR,33.0-80.0 Nominal ID Top(ORB) Top(TVD)(ftKB) Top Indy) Item Des Com (in) 27.1 27.1 0.35 HANGER TUBING HANGER 3.500 SAFETY VLV,2,085.0 ', 2,065.0 2,011.8 34.02 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 I 7,801.5 5,810.5 31.15 PBR BAKER PBR 3.000 7,814.8 5,8A 2.930 7,926.5 5,918.121.9 30.1031.02 SLEEVE-CPCKER FHL Retrievable Packer Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 SURFACE;31.2-2,721.0 8,128.0 6,092.9 29.55 SEAL ASSY Seal Assy w/2'spaceout 3.000 8,130.0 6,094.7 29.52 PACKER Baker"F-1"Packer 4.000 III 8,133.4 6,097.6 29.49 SBE SBE 4.000 GAS LIFT:7,743.2 8,137.7 6,101.3 29.44 Bottom Sub 2.950 8,173.7 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 8,174.7 6,133.6 29.04 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out 2.950 I Sub w/Tubing Pup) LOCATOR;7,7991 .1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) II Top)TVD) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID lin) PBR;7,807.5 „ 1 • 1 PACKER;7,814.8 _ (SERIAL# •: 11 5,12.69'SPACER PIPE,LATCH SEAL ASSY SERIAL# 1 11 'PATCH IS 17 ELEMENTS • ID- I SLEEVE-C;7,926.5 la PARAGON11: 8,066.0 6,039.1 29.84 PATCH PBR AND SPACER PIPE IN LOWER ANCHOR @ 1/9/2016 1 600 8,108'RKB PATCH;7,989.0STATEWIDE • (sera IPERF;7,948.08,057.0CPP35014),19.5'SPACER PIPE,UPPER PACKER 8,066'RKB CENTER ELEMENT PATCH is 42'OAL OVER INTERVAL 8,0661-8,108' 2.72"PARAGON II PACKER(SER tti CPP35030) IPERF;8082.0-8,071 D 8,286.0 6,231.6 1 2.000 PATCH;8066.0 DOWNHOLE NIPPLE,PERFS WITH 2008 IPERF;8100.08,104.0 WORKOVER 8,310.0 6,252.9 27.15 FISH DMY half of 1"DMY laying©-8252 RKB 12/26/1991 8,502 0 6,426 4 24 14 FISH Vann Gun 1/6/1982 IPERF;8,1250-81240Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots) SEAL ASSY;8,128.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,948.0 8,057.0 5,936.7 6,031.3 C-1,C-2,C- 1/6/1982 4.0 IPERF 4"Vann Guns PACKER;8,130.1 �`, 3,C-4,1A-12 SBE;8,133.4 •-in. 8,062.0 8,071.0 6,035.6 6,043.4 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns Wi' 8,100.0 8,104.0 6,068.6 6,072.0 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns 12 8,120.0 8,124.0 6,085.9 6,089.4 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns I 12 CMT SOZ;8,162.0$,164.0 -. 8,162.0 8,164.0 6,122.5 6,124.3 UNIT B,1A- 8/20/1985 4.0 CMT 12 SQZ NIPPLE;8,173.7 8,219.0 8,223.0 6,172.4 6,176.0 A-5,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns SOS;8,174.7 j 8.233.0 8.262.0 6,184.8 6210.3 A-4 1A-12 1/6/1982 4.0 IPERF 4"Vann Guns Cement Squeezes IPERF;8,219.0-8223.0-. Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 8,162.0 8,164.0 6,122.5 6,124.3 Cement 8/21/1985 Squeeze IPERF;8,233.0-8262.0 . Mandrel Inserts St at, FISH;8,286.0 - N Top(TVD) Valve Latch Port Size TRO Run Top(ftKB) I01(13) Make Model OD(in) Sery Type Type (int (psi) Run Date Corn 1 7,743.2 5,760.8 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 FISH;8,310.0 Notes:General&Safety End Date Annotation FISH;8,502.0 8/27/1985 NOTE:WORKOVER 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION I 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 6/20/2010 NOTE WAIVERED WELL IA x OA COMMUNICATION 2/17/2013 NOTE: LEAKS FOUND @ 8072&8090 PRODUCTION;29.7-8,052.0 A OFTy • //7. ,. s THE STAT• Alaska it and Gas OfA LAS Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®p„ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer qi � ConocoPhillips Alaska, Inc. I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-12 Sundry Number: 315-754 Dear Mr. Peirce: 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, 4.6.g454. Cathy . Foerster Chair DATED this 1 day of December, 2015 Encl. RBDMS DEC 2 4 2015 • j STATE OF ALASKA ' • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 16 2015 APPLICATION FOR SUNDRY APPROVALS ols 6 z t-3' 20 AAC 25.280 1.Type of Request: Abandon [ Plug Perforations .__ Fracture Stimulate( Repair Well r.:' Operations Shutdown Suspend Fr Perforate fl Other Stimulate r- Pull Tubing 7 Change Approved Program l� Plug for Redrill E Perforate New Pool E Re-enter Susp Well [ Alter Casing r.. Other:lrstall Tithing Patch 1✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory I Development 1.... 181-178 3.Address: 6.API Number P.0.Box 100360,Anchorage,Alaska 99510 Stratigraphic ( Service 50-029-20688-00 • 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 7 No W' / KRU 1A-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25647 • 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): 8,865' 6,761' • 8762 . 6663 . 3331 828,683,108,502 Casing Length Size MD ND Burst Collapse Structural Conductor 47' 16" 80' 80' Surface 2,690' 10.75 2,721' 2,467' Intermediate Production 8,822' 7" 8,852' 6,749' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7948-8262 5937-6210 3.5 L-80 8,182' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-FHL RETRIEVABLE PACKER , MD=7815 TVD=5822 PACKER-BAKER"F-1"PACKER MD=8130 TVD=6095 SAFETY VLV-TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 MD=2065 TVD=2012 12.Attachments: Proposal Summary 0 Wellbore schematic El 13.Well Class after proposed work: Detailed Operations Program D BOP Sketch ❑ Exploratory fr Stratigraphic r Development r Service I'v 14.Estimated Date for 12/30/2015 15.Well Status after proposed work: Commencing Operations: OIL , WINJ iv WDSPL Suspended I..... 16.Verbal Approval: Date: GAS WAG E GSTOR E SPLUG 1-- Commission Representative: GINJ `. Op Shutdown (....... Abandoned F.. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John W. Peirce Email John.W.Peirce(a)conocophillips.com Printed Name John Peirce@ 265-6471 Title Sr.Wells Engineer (7t - Sz11S/1 S Signature Z \ Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number 3/5 - -754f Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test d/ Location Clearance ❑ Other: �r f't W) rY1 T 5 5 Z ci idl . ...IA. rt 1,v'YY d ce Etc • 5-1-4,b i 1 1 ye-ci 1 ✓l. C ti`'1,--.... Post Initial Injection MIT Req'd? Yes II-- No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: /0— 40,1- Approved BY Approved by: 064C MISSIONER THE COMMISSION Date: Z. bm}E Farm and Form 10-4o.p, ed 304.?/� pir i 9i valid for 12 months from the date of approval. Attachments in Duplicate 7., t1 vrt. //�,�,s l yai RBDMSLLDEC 2 4 2015 • • 1A-12 Retrievable Tubing Patch Installation On 9/4/15, a retrievable tubing patch was set in 1A-12 at 8065 - 8108' RKB (per Sundry Approval # 315-453) to isolate 3 leaks to the C Sd at 8072', 8090', and 8102' RKB. A test plug was set in the upper patch packer to MITT, but a MITT failed. On 9/5/15 an LDL was run from top of the tubing patch to the upper packer of the C Sd selective at 7815' RKB. This log identified a tubing collar leak at 7997' RKB at -68' above the patch. This additional leak will require another tubing patch to isolate it. There is significant oil rate benefit for restoring A Sd only PWI in 1A-12 to support offset A Sd producers. Thus, it is proposed that an additional patch be installed at 7988 - 8007' RKB to isolate the remaining C sand leak at 7997' RKB. If any additional leaks are found after the additional Tubing Patch is set, it is very likely that 1A-12 will be headed for a RWO to replace the C Sd selective. Procedure: DSL: 1. Run 1" OD LDL through the 1.6" ID tubing patch at 8065 - 8108' RKB to obtain stop counts above and below the tubing patch to verify good mechanical integrity of the tubing patch before installing another tubing patch above it. Log the entire C Sd selective from 7815' to 8130' RKB to verify that no additional C Sd leaks exist to the C Sd other than the leak at 7997' RKB. If the patch is found leaking, it will be pulled, redressed, reset, and re-logged to verify integrity. If additional leaks are found below the existing tubing patch in the C sand selective, the additional steps per this procedure will be halted to progress a RWO option to replace the C Sd selective due to an excessive an number of tubing leaks in the selective. Slickline: 2. RIH to Brush & Flush 3.5" Tubing between 7975 - 8025' RKB where a new patch will be set. DSL: 3. RIH & set a 2.72" OD retrievable lower Straddle Packer at 8007' RKB in the tubing. POOH. 4. RIH with -19' OAL run #2 assembly consisting from bottom to top of a Snap-latch Stinger, Spacer Pipe, and an upper retrievable Straddle Packer (top). Latch into the lower Packer at 8007' RKB and then set the upper Straddle Packer at 7988' RKB in the tubing. This completes the Patch at 7988 - 8007' RKB. POOH. 5. RIH with a test plug and set it in the Packer at 7988' RKB. MITT to 2500 psi to verify good integrity of the upper Packer and Tubing above the Patch. POOH with test Plug. RD. Return 1A-12 to 'A sand only' PWI service & obtain valid injection rate. JWP 12/15/2015 KUP INJ • 1A-12 ConocoPhillips "' Well Attributes Max Angle&MD TD Alaska im, Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) [;,...,HylBps 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000.00 8,865.0 -.. .. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date IA-12,9/9/20152.19.09 PM SSSV:TRDP Last WO: 6/27/2008 39.01 1/6/1982 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag SLM 8,222.0 7/26/2015 Rev Reason SET PATCH Iehal9 9/9/2015 Casing Strings "•""•""""'•"•""HANGER;27.1"""""""""" 1-. """""""""' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H-40 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 10 3/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC I Casing Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K-55 ubing Strings IIflUUT Tubing GDescription String Ma...ID(M) Top(ftKB) Set Depth(ft.,Set Depth(ND)(...Wt(Ib'F9 Grade Top Connection TUBING e S2008 trings 31/2 2.992 27.1 8,181.7 6,139.7 9.30 L-80 31/2 Completion Details CONDUCTOR;33.0-80.0• Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Coin (in) 27.1 27.) 0.35 HANGER TUBING HANGER 3.500 SAFETY VLV;2,0650 2,065.0 2,011.8 34.02 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 la 7,799.1 7,801.5 5,808.5 31.17 LOCATOR LOCATOR 3.000 5,810.5 31.15 PBR BAKER PBR 3.000 7,814.8 5,821.9 31.02 PACKER FHL Retrievable Packer 2.930 7,926.5 5,918.1 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 8,128.0 6,092.9 29.55 SEAL ASSY Seal Assy w/2'spaceout 3.000 SURFACE;31.2-2,721.0 8,130.0 6,094.7 29.52 PACKER Baker"F-1"Packer 4.000 8,133.4 6,097.6 29.49 SBE SBE 4.000 988:,1113,3023...420 ,137.7 6,101.3 29.44 Bottom Sub 2.950 GAS LIFT;7,743.2 8,173.7 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 it 8,174.7 6,133.6 29.04 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out 2.950 Sub w/Tubing Pup) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;7,793.1Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Coin Run Date ID(in) 8,065.0 6,038.2 29.84-PATCH 3 PIECE PATCH OAL 44.47 9/4/2015 1.600 PBR,7,801.5 . _;I 8,286.0 6,231.6 27.56 FISH Brown'1 B'PACKER-Caliper 3/8/07 shows approx. 8/27/1985 - 2.000 PACKER;7,814.8 0 ` 2"ID;CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 it WORKOVER 8,310.0 6,252.9 27.15 FISH DMY halt of 1"DMY laying @`8252 RKB 12/26/1991 8,502.0 6,426.4 24.14 FISH Vann Gun 1/6/1982 - SLEEVE-C;7,926.5 Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/f I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t( Type Com IPERF:7,948.99,057.0- 7,948.0 8,057.0 5,936.7 6,031.3 C-1,C-2,C-3,C 1/6/1982 4.0 (PERF 4"Vann Guns I I -4,1A-12 II 8,062.0 8,071.0 6,035.6 6,043.4 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns !PERE;8,062.98,071.0_ I I 8,100.0 8,104.0 6,068.6 6,072.0 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns 12 PATCH;6,065.0 I ;; 8,120.0 8,124.0 6,085.9 6,089.4 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns IPERF;8,100.0-8,104.0 I 112 I 8,162.0 8,164.0 6,122.5 6,124.3 UNIT B,1A- 8/20/1985 4.0 CMT 12 SQZ 8,219.0 8,223.0 6,172.4 6,176.0 A-5,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns (PERF;8,120.96,124.0- 8,233.0 8,262.0 6,184.8 6,210.3 A-4,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns Cement Squeezes Top(ND) Btm(ND) SEAL ASSY;8,128.0 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com PACKER;8,130.1 w0- 8,162.0 8,164.0 6,122.5 6,124.3 Cement Squeeze 8/21/1985 SBE;8,133.4 Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 7,743.2 5,760.8 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 CMT SOZ;8,162.0-8,164.0-V I Notes:General&Safety End Date Annotation NIPPLE,8,1737 , 8/27/1985 NOTE:WORKOVER SOS,8,174.7 's ; 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 IPERF;8,219.0-8,223.0 6/20/2010 NOTE;WAIVERED WELL IA x OA COMMUNICATION 2/17/2013 NOTE:LEAKS FOUND @ 8072&8090 IPERF,8,233.0-8,262.0- FISH;8,286.0 FISH;8,310.0 FISH;8,502.0 I I PRODUCTION,29.7-8.SS?0 STATE OF ALASKA ALARA OIL AND GAS CONSERVATION COIVDSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program Plug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other Install Tubing Patch 2- 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 181-178 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20688-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 KRU 1A-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8865 feet Plugs(measured) none true vertical 6761 feet Junk(measured) 8286, 8310, 8502 Effective Depth measured 8762 feet Packer(measured) 7815,8130 true vertical 6663 feet (true vertical) 5822,6095 Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 16 80 80 SURFACE 2690 10.75 2721 2467 PRODUCTION 8822 7 8852 6749 O NOV I `72015 RECEIVED Perforation depth: Measured depth: 7948-8057, 8062-8071,8100-8104, 8120-8124, 8219-8223, 8233-8262 SEP 2 8 2015 True Vertical Depth: 5937-6031,6036-6044,6069-6073,6086-6090,6173-6177,6185-6211 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 8182 MD,6140 TVD Packers&SSSV(type,MD,and ND) PACKER-FHL RETRIEVABLE PACKER @ 7815 MD and 5822 TVD PACKER-BAKER"F-1"PACKER @ 8130 MD and 6095 TVD SAFETY VLV-TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 @ 2065 MD and 2012 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 shut-in Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations p, Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ p' WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-453 Contact John Peirce C ,265-6471 Email John.W.Peirce anconocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature — Phone:265-6471 Date 71 Vr-t- 1/Z1 /J 5 Form 10-404 Revised 5/2015 �7� RBDMSif SEP 28 2015 Submit Original Only 1 1A-12 WELL WORK SUMMARY DATE SUMMARY • • 7/8/2015 PER CWG REP: TOOL STRING IS 1" GR/CCL/TEMP/PRES/CWH/SPINNER. DYNAMIC PASSES LOGGED FROM 7736'-8180'AT 30,60,90 FPM. LOGGED STOP COUNTS AT 7815' AND 8110'. ATTEMPTED STOP COUNTS AT 8210'AND 8265', BUT UNABLE TO SEE SPINNER IN 7" CASING. INJECTING 5000 BWPD AT 1600 PSI: C SANDS 72%,A SANDS 28% INJECTING 4000 BWPD AT 1200 PSI: C SANDS 100%,A SANDS 0% INJECTING 3000 BWPD AT 1000 PSI: C SANDS 100%,A SANDS 0% LEAK DETECTED AT 8102'. SHUT IN WELL FOR 1HR, WELL DID NOT STABILIZE; PROCEEDED WITH CROSSFLOW SURVEY. OBSERVED CROSSFLOW FROM A SANDS TO C SANDS THROUGH LEAK AT 8102' 7/25/2015 BRUSH n' FLUSH TBG DOWN TO PATCH @ 8069' RKB; SET PULLING TOOL IN PATCH & JAR FOR 20 MIN. IN PROGRESS. 7/26/2015 PULLED PARAGON PATCH @ 8069' RKB; BRUSH n' FLUSHED PATCH INTERVAL FROM 8000' TO D-NIPPLE @ 8174' RKB; TAG FILL @ 8222' SLM (EST. 7' OF FILL). READY FOR DSL/E-LINE (patch). IN PROGRESS. 9/3/2015 PERFORMED 30 MIN SBHPS @ 8212' RKB (2853.8 psia; 132.1*F ) & 15 MIN GRADIENT STOP @ 8097' RKB ( 2809.9 psia; 132.2*F ). SET LOWER 2.72" PARAGON II PACKER © 8108' RKB. *JOB IN PROGRESS LOWER PACKER SERIAL#CPP35030 9/4/2015 SET 2ND PATCH SECTION (3 1/2" PBR, SPACER PIPE, LATCH SEAL ASSY; OAL 19.6') IN LOWER PACKER @ 8102' RKB. SET TOP PATCH SECTION (2.72" PIIP, SPACER PIPE, LATCH SEAL ASSY; OAL: 22.4') @ 8068' RKB. SET TEST TOOL IN TOP OF PATCH. LRS WAS UNABLE TO PRESSURE UP TBG FOR MIT-T TO 2500#. CONFERED W/CWG REP; WILL PERFORM LDL IN MORNING. *JOB IN PROGRESS UPPER PACKER SERIAL#CPP35008 LATCH SEAL ASSY SERIAL#CPAL35011 PBR SERIAL#CPBR35007 LATCH SEAL ASSY SERIAL#CPAL35014 9/5/2015 PERFORMED BASELINE PASS TO TEST TOOL IN TOP OF PATCH @ 8068' RKB. LEAK OBSERVED IN TBG COLLAR @ 7997.6' RKB. (CROSSFLOW FROM 'A' SANDS THROUGH TEST TOOL STANDING VALVE AND INTO 'C' SANDS THROUGH TBG COLLAR LEAK.) PULLED TEST TOOL FROM TOP OF PATCH. WELL AWAITING FURTHER TROUBLESHOOTING. *JOB COMPLETE 9/8/2015 F/P WELL AND FLOWLINE 20 BBL DIESEL DOWN TBG AND 5 BBL METH DOWN FLOWLINE JOB COMPLETE KUP INJ 0 1A-12 ConocoPhillips Well Attributes Max Angle&MD TD Aid,..„„,,i,,, i Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Camazaetv16p5 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000 00 8,865.0 ... Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date 1A-12.9/9/20152.19:09 PM SSSV:TRDP Last WO: 6/27/2008 39.01 1/6/1982 Vertical schematic(ectua� Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,222.0 7/26/2015 Rev Reason:SET PATCH lehallf 9/9/2015 l Casing Strings 'HANGER;27.1"' i l[ .--..........C g Descr phon OD(in) 10 1.063 Top(ftKB) Set Depth(ftKB) Set Depth(N2..(..)WtlLen(1..Grade Top Thread �IQ��� CONDUCTOR 16 15.063 33.0 80.0 65.00 H-40 Il t° Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread °ti SURFACE 103/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 29 7 8,852.0 6,748.5 26.00 K-55 ,,, ". , „ rnpn rza Tubing Strings Tubing Description I Str ng Ma...l ID(in) I Top(ftKB) I Set Depth(ft..f Set Depth(ND)(...I Wt(!blit) !Grade( Top Connection TUBING WO 2008 31/2 2992 27.1 8.181.71 6 139 7 9.30L-80 31/2 ' Completion Details .M-A.CONDUCTOR 33.0-80.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not(°) Item Des Com (in) 1 27.1 27.1 0.35 HANGER TUBING HANGER 3.500 SAFETY VLV;2.065.0 bAl1 2,065.0 2,011.8 34.02 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.5. 31.15 PBR BAKER PBR 3.000 I l 7,814.8 5,821.9 31.02 PACKER FHL Retrievable Packer 2.930 7,926.5 5,918.1 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 8,128.0 6,092.9 29.55 SEAL ASSY Seal Assy w/2 spaceout 3.000 SURFACE;312-2,7210-A 8,130.0 6,094.7 29.52 PACKER Baker"F-1"Packer 4.000 8,133.4 6,097.6 29.49 SBE SBE 4.000 8,137.7 6,101.3 29.44 Bottom Sub 2.950 GAS LIFT;7,743.2 x^ 8,173.7 6,132.8 29.05 NIPPLE AVA'D'Nipple 2.750 8,174.7 6,133.6' 29.04'SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out 2.950 Sub w/Tubing Pup) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCATOR;7,799.1. Top(ND) Top Inc!, Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 8,065.0 6,038.2 29.84 PATCH 3 PIECE PATCH OAL 44.47 9/4/2015 1.600 PBR;7,801.5 - 8,286.0 6,231.6 27.56 FISH Brown'1B'PACKER-Caliper 3/8/07 shows approx. 8/27/1985 2.000 PACKER:7.014.8 ':"..;=,.. 2"ID;CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER 8,310.0 6252.9 27.15 FISH DMY half of 1"DMY laying @-8252 RKB 12/26/1991 8,502.0 6,426.4 24.14 FISH Vann Gun 1/6/1982 SLEEVE-C;7.926.5 Perforations&Slots e A'b'' , Illiggil Shot Dens Top(ND) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (RKB) Zone Date t) Type Com IPERF;79480-8,057.0- 7,948.0 8,057.0 5,936.7 6,031.3 C-1,C-2,C-3,C 1/6/1982 4.0 (PERF 4"Vann Guns -4,1A-12 a 8,062.0 8,071.0 6,035.6 6,043.4 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns IPERF;8,062.0-8,071.0= j 8,100.0 8,104.0 6,068.6 6,072.0 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns I I 12 PATCH;8,0650 8,120.0 8,124.0 6,085.9 6,089.4 UNIT B,1A- 1/6/1982 4.0 IPERF 4"Vann Guns (PERF;8,100.0.8,104.0- 12 8,162.0 8,164.0 6,122.5 6,124.3 UNIT B,1A- 8/20/1985 4.0 CMT 12 SQZ 8,219.0 8,223.0 6,172.4 6,176.0 A-5,1A-12 1/6/1982 4.0 (PERF 4"Vann Guns IPERF;8,1200-8,124.08,233.0 8,262.0 6,184.8 6,210.3 A-4,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns - Cement Squeezes , e Top(ND) Btm(TVD) SEAL ASSY,8,128.0 : Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com PACKER,8,1 .1 8,162.0 8,164.0 6,122.5 6,124.3 Cement Squeeze 8/21/1985 SBE,8,133.4 ITMandrel Inserts st II i n � Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn 7,743.2 5,760.8 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 CMT SGZ;8,162.0-,164.0- .'."1 Notes:General&Safety End Date Annotation NIPPLE;8,173.7 8/27/1985 NOTE:WORKOVER SOS;0,174.7 ;°1 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 IPERF;8,219.48,223.0- 6/20/2010 NOTE:WAIVERED WELL IA x OA COMMUNICATION 2/17/2013 NOTE:LEAKS FOUND @ 8072&8090 IPERF;8,233.0-8,262.0 FISH;8286.0 FISH;8,310.0 FISH;8,502.9 PRODUCTION.29.7-8,852.0 241i3 WELL LOG TRANSMITTAL As To: Alaska Oil and Gas Conservation Comm. August 10, 2015 Attn.: Makana Bender AUG 1 3 333 West 7th Avenue, Suite 100 DATA LOGGED ..r ' M.K`BEND R Anchorage, Alaska 99501 RE: Injection Profile : 1A-12 Run Date: 7/9/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1A-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20668-00 Injection Profile SCANNED 1 Color Log 50-029-20668-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: MvttSa4za.;/) 6..e.„.(eft .� OF Tye 6� //j� s THE STATE Alaska Oil and Gas ���, of/ T j\ J(j\ Conservation Commission 333 West Seventh Avenue h'r GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 \T Main• 907 279 1433 ALA911'P Fax 907.276.7542 www.aogcc alaska gov John Peirce Sr. Wells Engineer f 1 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1A-12 Sundry Number: 315-453 Dear Mr. Peirce: 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, Cathy P. oerster Chair DATED this 2/4;of July, 2015 Encl. STATE OF ALASKA f,_ .3KA OIL AND GAS CONSERVATION COM,. _,SIGN APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Flug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown 1— Suspend r Perforate r Other Stimulate r i(✓Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r7/Re-enter Susp Well r Other Install Tubing Patch F r 2.Operator Name: 4.Current Well Class. 5.Permit to Drill Number: ConocoPhillips Alaska, Inc 4 Exploratory r Development r 181-178 ' 3.Address6.API Number: Stratigraphic r Service p • P.O. Box 100360,Anchorage,Alaska 99510 50-029-20688-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception's Yes r No v/ KRU 1A-12 ' 9.Property Designation(Lease Number). 10.Field/Pool(s): ADL 25647 - Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft)• Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft). Plugs(measured): Junk(measured): 8865 . 6761 - 8762' - 6663' - none 8286,8310,8502 Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 16 80' 80' SURFACE 2690 10.75 2721' 2467' PRODUCTION 8822 7 8852' 6749' C w!V E D IUI_ 2 7 2D1ri o p-S z) ze-j AOGCC Perforation Depth MD(.7948-8057,8062-8071, Perforation Depth TVD(ft): 5937-6031, Tubing Size. Tubing Grade: Tubing MD(ft): 8100-8104,8120-8124,8219-8223,8233-8262 6036-6044,6069-6073,6086-6090,6173-6177,6185-6211 3.5 L-80 8182 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-FHL RETRIEVABLE PACKER MD=7815 TVD=58220 PACKER-BAKER"F-1"PACKER MD=8130 TVD=6095 - SSSV-TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 MD=2065 TVD=2012 ' 12.Attachments: Description Summary of Proposal J 13. Well Class after proposed work. Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service P- 14. `14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/15/2015 OIL r WINJ p - WDSPL E Suspended r 16.Verbal Approval: Date. GAS r WAG r GSTOR r SPLUG r Commission Representative. GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips corn Printed Name John Peirce Title: Sr. Wells Engineer Signature icy4' Phone:265-6471 Date 7/2+/is^ Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 1 S- 4-11D � Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No [7I Subsequent Form Required: /9 —*b 1– / 4,••----- APPROVED BY �Approved b ' COMMISSIONER THE COMMISSION Date: ?.$ -/ Q r c II tl Is v dor 11 ont s tr m the date of approval. U� /Ze, Z�P; Submit Form and Form 10-403 Rev sed 5/2015 Pp U \I �� L Y•A �{'1 r R_Altachments jn Duplicate - n7//,,� BMS. \\-k. AUG 7 inc7 Ai KUP 1A-12 IV • ' ConocoPhillips Re Well Attributes Max Angle&MD TD Alaska IncWellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) c«toKoPniaps 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000.00 8,865.0 -- "- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -- SSSV:TRDP Last WO: 6/27/2008 39.01 1/6/1982 Well CoMg:-1A-12,7i1/2013 8:26:48 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,248.0 10/10/2011 Rev Reason:SET TUBING PATCH haggea 7/1/2013 HANGER,27 ... ..-_ _ _ _ ._- Casing Strings .. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String..String Top Thrd CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H-40 _,;- Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd SURFACE 103/4 9.794 31.2 Z721.0 2,466.5 45.50 K-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String...String Top Thrd '"PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K-55 Tubing Strings Tubing Description String o.. String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String . String Top Thrd TUBING WO 2008 31/2 2.992 I 27.1 8,181.7 6,139.7 9.30 L-80 31/2 CONDUCTOR, 33-80 Completion Details A 7 Top Depth (ND) Top Incl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment ID(in) SAFETY VLV, fi i 2,065 27.1 27.1 1.30 HANGER TUBING HANGER 3.500 l , 2,065.0 2,011.5 34.07 SAFETY VLV TRMAXX-5E SCSSV LOCKED OPEN 2/14/13 2.812 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.4 30.58 PBR BAKER PBR 3.000 7,814.8 5,821.9 30.53 PACKER FHL Retrievable Packer 2.930 7,926.5 5,918.2' 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 S3RFZO2 8,128.1 6,093.3 29.77 SEAL ASSY Seal Assy w/2'spaceout 3.000 8,130.0 6,095.0 29.75 PACKER Baker"F-1"Packer 4.000 8,133.4 6,097.9 29.70 SBE SBE 4.000 GAS LIFT, _ 7.743 ^ 8,173.7 6,132.8 29.13 NIPPLE AVA'D'Nipple 2.750 1 8,174.7 6,133.7 29.12 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out Sub w/Tubing 2.950 Pup) 3 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) LOCA7,793 O R. , k_, Top Depth (ND) Top Mel _ - Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 8,069.0 6,041.8 30.19 TUBING TUBING PATCH FROM 8094'TO 8069'(OAL=29') 6/25/2013 1.610 PER,7,801 PATCH PACKER,7.815 -- till 8,286.0 6,231.6 27.67 FISH Brown'1B'PACKER-Caliper 3/8/07 shows approx.2"ID; 8/27/1985 2.000 111. CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER II 8,310.0 6,252.9 27.15 FISH DMY half of 1"DMY laying @-8252 RKB 12/26/1991 II 8,502.0 6,426.4 24.14 FISH Vann Gun 1/6/1982 SLEEVE-C, 7.927 Perforations&Slots Shot Top(TVD) Btm)TVD) Dens Top(ftKB)Ben(RKB) (RKB) (RKS) Zone Date )eh-- Type Comment 7,948-8,057 IPERF,_ _ • - 7,948.0 8,057.0 5,936.8 6,031.4 C-1,C-2,C-3,C-4, 1/6/1982 4.0 IPERF 4"Vann Guns - -- 1A-12 IPERF, _ M 8,062.0 8,071.0 6,035.7 6,043.5 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns 8,062-8,071 - 8,100.0 8,104.0 6,068.6 6,072.7 UNIT B,1A-12 1/6/1982 4.0)PERF 4"Vann Guns 8,120.0 8,124.0 6,086.4 6,089.8 UNIT B,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns TUBING _ -'1 PATCH,8,069 8,162.0 8,164.0 6,122.6 6,124.4 UNIT B,1A-12 8/20/1985 4.0 CMT SQZ IPERF, 8,219.0 8,223.0 6,173.2 6,176.7 A-5,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns 8,233.0 8,262.0 6,185.3 6,210.5 A-4,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns IPERF, -- -- Cement Squeezes 8,120-8,124 _- Top Depth Btm Depth -ti - (TVD) (ND) Top(RKB) Btm(ftKB) (RKB) (RKB) Description Start Date Comment SEAL ASSY, 8,162.0 8,164.0 6,122.6 6,124.4 Cement Squeeze 8/21/1985 8,128 Notes:General&Safety PACKER,8,130 ,- End Date Annotation 8/27/1985 NOTE:WORKOVER SBE,6133 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 6202010 NOTE:WAIVERED WELL IA x OA COMMUNICATION CMI SOZ. 2/17/2013 NOTE: LEAKS FOUND @ 8072&8090 8,162-8,164-,., T / V Cement SOZ, 6182 NIPPLE,8,174 11._, SOS,8,175 S. x a IPERF, 1i1 8,219-8,223 PERF. - Mandrel Details 82338282 :, - Top Depth Top Port - - S.,. )TVD) Incl OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°I Make Model (in) Sent Type Type (in) (psi) Run Date Corn... FISH,8,293 - py, 1 7,743.3 5,760.8 31.57 CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 7/6/2008 FISH,6310 ------ FISH,8,502- PRODUCTION, 30-8,852 + I).TD,8,865 1A-12 Retrievable Tubing Patch Replacement An (PROF ran 7/8/15 in 1A-12 found a tubing leak in the C sand selective at 8102' RKB taking 100% of PWI at 5000 BWPD through a big leak. The 1" OD IPROF tool ran through the existing tubing patch set at 8069 - 8094' RKB. This patch was set 6/25/13 over 2 leaks at 8072' and 8090' RKB. The IPROF showed the patch still has very good integrity, but it needs to be pulled to gain access to the new leak below it. 1A-12 injection data indicates the new tubing leak probably developed January 2015, when 500 BWPD (A Sd Only PWI) gradually began to climb to -4700 BWPD with WHIP's gradually falling until June '15. This prompted the 7/8/15 IPROF. There is significant oil rate benefit associated with restoring 'A Sand only' PWI in 1A-12 to support offset A Sd producers. It is proposed that the existing patch be pulled and replaced by a longer patch in order to isolate the new leak and old leaks with a single patch assembly. Procedure: Slickline: 1. RIH & pull top section of Tubing Patch at 8069' RKB. 2. RIH & pull the lower straddle packer of the Tubing Patch 8094' RKB. 3. RIH to Brush & Flush 3.5" tubing between 8030 - 8125' RKB where a new patch will be set. 4. RIH with Dummy Patch Drift assemblies to target patch set depth which mimic OAL & OD dimensions of the new patch run assemblies to verify that the new patch will drift the tubing. DSL: 5. RIH & set a 2.72" OD retrievable lower Straddle Packer at 8108' RKB in tubing. POOH. 6. RIH with -20' OAL run #2 assembly consisting from bottom to top of a snap latch seal stinger assembly, spacer pipe, and a snap latch/PBR receptacle at 8088' RKB (top). Sting into lower packer at 8108' RKB to set run #2. Shear off run #2. POOH. 7. RIH with -20' OAL run #3 assembly consisting from bottom to top of a snap latch stinger, spacer pipe, and an upper retrievable Straddle Packer (top). Sting & latch into receptacle at 8088' RKB and then set the top straddle packer at 8068' RKB. This completes the tubing patch at 8068 - 8108' RKB. POOH. 8. RIH with test plug & set it in Packer at 8068' RKB. MITT to 2500 psi to verify integrity of the upper packer and the tubing above the patch. POOH with test plug. RD. Return 1A-12 to 'A sand only' PWI service & obtain valid injection rate. JWP 7/24/2015 STATE OF ALASKA . AL.OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell "°` Plug Perforations j— Perforate f Other ]i Install Tubing Alter Casing Pull Tubing Patch g g � Stimulate-Frac �"" Waiver Time Extension �"•' Change Approved Program iOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: - ConocoPhillips Alaska, Inc. . Development Exploratory _ 181-178 . 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-20688-00 • 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25647 1A-12 . , 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 8865 • feet Plugs(measured) none true vertical 6761 feet Junk(measured) 8286, 8310, 8502 Effective Depth measured 8762 feet Packer(measured) 7815,8130 true vertical 6663 feet (true vertical) 5822,6095 Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 16 80 80 SURFACE 2690 10.75 2721 2467 PRODUCTION 8822 7 8852 6749 , +t�NED NOV 0 82013 Perforation depth: Measured depth: 7948-8057,8062-8071, 8100-8104,8120-8124,8219-8223,8233-8262 True Vertical Depth: 5937-6031,6036-6044,6069-6073,6086-6090,6173-6177,6185-6211 Tubing(size,grade,MD,and ND)- 3.5, L-80, 8182 MD,6140 TVD Packers&SSSV(type,MD,and ND) PACKER-FHL RETRIEVABLE PACKER @ 7815 MD and 5822 TVD PACKER-BAKER"F-1"PACKER @ 8130 MD and 6095 TVD SSSV-TRMAXX-5E SCSSSV @ 2065 MD and 2012 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not available 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 4043 Subsequent to operation 1176 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory fl Development r Service ci • Stratigraphic fi 16.Well Status after work: Oil fi Gas f WDSPL Daily Report of Well Operations XXX GSTOR r- WINJ P' • WAG fi GINJ r SUSP r SPLUG F- 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-191 Contact John Peirce C)_265-6471 Email John.W.Peirce @conocophillips.com Printed Name John Peirce Title Wells Engineer Signature Phone:265-6471 Date 7/S11 eft. ,___________Ip / • t" Ak.--___.. RBDMS JUL - 8 201 Form 10-404 Revised 10/2012 , w /� Submit Original Only KU P 1A-12 CQnocvPh(IIipS Well Attributes Max Angle&MD TD Aiasn<3,111+.; Wellbore APOUWI Field Name Wel!bore Status Inc!I I MD(RKB) Act Btm(ftKB) 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000.00 8,865.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grtl(R) Rig Release Date wellcomla:-1A-12.7nrzo13e:z6:4eAV _ ---SSSV:TRDP Last WO: 6/27/2008 39.01 1/6/1982 _ Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 8,248.0 10/10/2011 Rev Reason:SET TUBING PATCH haggea 7/1/2013 ANGER,27 - - -Casing Strings Casing Description String 0... String ID...Top)ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H-40 "-" Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd SURFACE 103/4 9.794 31.2 2,721.0 2,466.5 45.50 K-55 BTC • Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K-55 it Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd TUBING WO 2008 31/2 2.992 27.1 8,181.7 6,139.7 9.30 L-80 31/2 CONDUCTOR, 33eo- ■ Completion Details ..__ Top Depth (TVD) Top Inc! Noml... SAFETY VLV, Top(RKB) (RKB) (°) Rem Description Comment ID(In) 2.065 [[[[[[--.---```00 27.1 27.1 1.30 HANGER TUBING HANGER 3.500 h f[( 2,065.0 2,011.5 34.07 SAFETY VLV TRMA) -5E SCSSV LOCKED OPEN 2/14/13 2.812 (' X 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.4 30.58 PBR BAKER PBR 3.000 7,814.8 5,821.9 30.53 PACKER PHI Retrievable Packer 2.930 c 7,926.5 5,918.2 30.10 SLEEVE-C Baker CMU Sliding Sleeve(CLOSED 6/19/2010) 2.813 SURFACE, 31-2,721 L-__ 8,128.1 6,093.3 29.77 SEAL ASSY Seal Assyw/2'spaceout 3.000 8,130.0 6,095.0 29.75 PACKER Baker"F-1"Packer 4.000 GAS LIFT, 8,133.4 6,097.9 29.70 SBE SBE 4.000 7743 _. 8,173.7 6,132.8 29.13 NIPPLE AVA'D'Nipple 2.750 8,174.7 6,133.7 29.12 SOS ELMD TTL @ 8162'during SBHP on 3/8/2007(Shear Out Sub w/rubing 2.950 Pup) Other In Hole(Wireiine retrievable plugs,valves,pumps,fish,etc.) LOCA70 9 Top Depth = °-' (ND) Top Inc! Top(RKB) (RKB) (') Description Comment Run Date ID(in) __--...._ 8,069.0 6,041.8 30.19 TUBING PATCH TUBING PATCH FROM 8094'TO 8069'(GAL=29') 6/25/2013 1.610 PBR,7,801 L----,___, PACKER,7,815 8,286.0 6,231.6 27.67 FISH Brown'1B'PACKER-Caliper 3/8/07 shows approx.2"ID; 8/27/1985 2.000 CAMCO D NIPPLE,BAKER SOS-PUSHED DOWNHOLE BELOW PERFS WITH 2008 WORKOVER 8,310.0 6,252.9 27.15 FISH DMY half of 1"DMY laying @'8252 RKB 12/26/1991 4 8,502.0 6,426.4 24.14 FISH Perforations&Slots Vann Gun 1/6/1982 SLEEVE-C, 7,927 Shot Top(ND) Btm(TVD) Dens IPERF, Top(RKB)Btm(RKB) (RKB) (ftKB) Zone Date (sh... Type Comment 7,g48-e,as7 7,948.0 8,057.0 5,936.8 6,031.4 C-1,C-2,C-3,C-4, 1/6/1982 4.0 IPERF 4"Vann Guns 1A-12 IPERF, I8,062.0 8,071.0 6,035.7 6,043.5 C-1,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns a,osz.8,071 8,100.0 8,104.0 6,068.6 6,072.7 UNIT B,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns TUBING 11 I 8,120.0 8,124.0 6,086.4 6,089.8 UNIT B,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns PATCH,8,069 8,162.0 8,164.0 6,122.6 6,124.4 UNIT B,1A-12 8/20/1985 4.0 CMT SQZ ER, e.t PlxF8,10,4 'j ® 8,219.0 8,223.0 6,173.2 6,176.7 A-5,1A-12 1/6/1982 4.0 IPERF 4"Vann Guns 8,233.0 8,262.0 6,185.3 6,210.5 A-4,1A-12 1/6/1982 4.OIPERF 4"Vann Guns IPERF, at = Cement Squeezes 8,120.8.124 Top Depth Btm Depth / (ND) (TVD) Top(RKB) Btm(ftKB) (ftKB) (ftKB) Description Start Date Comment SEALASSY, __ 8,162.0 8,164.0 6,122.6 6,124.4 Cement Squeeze 8/21/1985 8,128 Notes:General&Safety PACKER,8,130 -- '417:-44-77:74;;A End Date Annotation SBE,8,133 .'/ 7 8/27/1985 NOTE:WORKOVER 9/4/2002 NOTE:PACKER/SEAL ASSEMBLY SEPARATION 7/12/2008 NOTE:VIEW SCHEMATIC w/9.0 6/20/2010 NOTE:WAIVERED WELL IA x OA COMMUNICATION CMT Soz, 2/17/2013 NOTE: LEAKS FOUND @ 8072 8 8090 8,162-8,164 Cement SOZ, 8,162 NIPPLE,8,174 SOS,8.175 IPERF, _'. -__=_ 8,2198,223 PERF, Mandrel Details 8,233.8,262 _ __ Top Depth Top Port 5... (ND) Ind OD Valve Latch Size TRO Run N...Top(RKB) (RKB) F) Make Model (in) Sery Type Type On) (psi) Run Date Com... FISH,8,286 f 7,743.3 5,760.8 31.57 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 FISH,8,310 aa],, FISH,8,502 -(h) PRODUCTION, 308,852 TD,8,865 A I• 1A-12 Well Work Summary DATE SUMMARY • 1/11/2013 PERMORMED IPROF AND MIT CALIPER TO INVESTIGATE POSSIBLE LEAK INTO C SANDS THROUGH TUBING. RIH WITH TOOLSTRING AND GOT STOPPED BY DIFFERENTIAL STICKING AT 8050'. HAD TO CHOKE BACK WELL 1500 BBLS TO GET PAST ZONE. DISCOVERED THAT SSSV HAD A LEAK AND IT WAS DECIDED THAT MAKING MULTIPLE PASSES MAY DAMAGE THE WIRELINE AND PREVENT US FROM LEAVING THE WELL. MADE ONE CALIPER PASS AND ONE IPROF PASS ON WAY OUT OF WELL. POSSIBLE LEAK IDENTIFIED @ 8080'. 1/27/2013 UNABLE TO BLEED CONTROL LINE TO 0 PSI. BRUSHED TRMAXX @ 2065' RKB. IN PROGRESS. 1/28/2013 BRUSHED & FLUSHED TRMAXX @ 2065' RKB. BLED CONTROL LINE TO ZERO. CLOSURE TESTED, PASSED. PUMPED OPEN, OBSERVED FLOW TUBE MOVEMENT. COMPLETE. 2/14/2013 BRUSH & FLUSH SSSV @ 2065' RKB. LOCKED OUT TRMAXX-5E SCSSV. RAN FLAPPER CHECKER & DRIFTED SSSV WITH NO PROBLEMS. JOB COMPLETE. 2/17/2013 LEAK DETECT RAN FROM 8170'TO 7800'. TWO LEAKS WERE FOUND. ONE @ 8072'AND ONE @ 8090'. INITIAL FLOW RATE OF 6000 BWPD WAS TOO HIGH AND CAUSED DIFFERENTIAL STICKING DOWNHOLE, HAD DSO CHOKE BACK WELL TO 3900 BWPD TO AVOID THAT ISSUE 4/13/2013 BRUSHED AND FLUSHED TBG PATCH INTERVAL FROM 8060'TO 8110' RKB; DRIFTED TBG WITH 2.75" x 18.5' DUMMY PATCH TO 8130' SLM ( NO OBSTRUCTION ) . READY FOR PATCH PROCEDURE. 6/22/2013 ATTEMPT TO SET PATCH, UNABLE TO MAKE PATCH UP TO SETTING TOOL ON SURFACE, A CONNECTOR WILL NEED TO BE MADE 6/25/2013 SET TUBING PATCH FROM 8094' RKB TO 8069' RKB (MID ELEMENT TO MID ELEMENT) 6/26/2013 SET OLGOONIK TEST TOOL IN TOP OF PATCH @ 8069' RKB, MIT-T @ 2500psi PASSED, PULLED TEST TOOL ®F Ty e • ID 4,w \ I %%ys THE STATE A las k a. Oil an d G If\ °fA LAS KA i,ciasezvation Commission I � � 0 GOVERNOR SEAN PARNELL 333 West Seventh Avenue 0F ALAS� � Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 John Peirce SCANNED MAY 0 2 2013 Wells Engineer l ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A -12 Sundry Number: 313 -191 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ` day of May, 2013. Encl. ituMAvCLJ STATE OF ALASKA Air OIL AND GAS CONSERVATION COM ION APR 19 2013 APP FOR SUNDRY APPR ALS 20 AAC 25.280 AOGCC 1. Type of Request: Abandon E Plug for Redrill (`-" Perforate New Pool f " Repair w ell (-- Change Approved Program r Suspend f'"" Plug Perforations E Perforate f ' Pull Tubing r Time Extension E Operational Shutdown 1- Re -enter Susp. Well E Stimulate ' " Alter casing f Other:Install Tubing Patch +0 2. Operator Name: a • 4. Current Well Class: 5. Permit to Drill Number: • ConocoPhillipsAlaska, Inc. Development (� Exploratory 1 , 181 - 178• 3. Address: 6. API Number: le Stratigraphic f"` Service . P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20688 -00 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ,, Will planned perforations require spacing exception? Yes ( No f.: 1A -12 . 9. Property Designation (Lease Number): ,0* 10. Field /Pool(s): V ADL 25647 • Kuparuk River Field / Kuparuk River Oil Pool - 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8865 • 6761 8762' 6663' none 8286; 8310, 8502 Casing Length Size MD TVD Burst Collapse CONDUCTOR 47 16 80' 80' SURFACE 2690 10.75 2721' 2467' PRODUCTION 8822 7 8852' 6749' Perforation Depth MD (17948 -8057, 8062 -8071, Perforation Depth TVD (ft): 5937 -6031, 6036 -6044, Tubing Size: Tubing Grade: Tubing MD (ft): 8100 -8104, 8120 -8124, 8219 -8233, 8233 -8262 6069 -6073, 6086 -6090, 6173 -6177, 6185 -6211 3.5 L -80 8182 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - FHL RETRIEVABLE PACKER • MD= 7815 TVD= 5822 PACKER - BAKER "F -1" PACKER ' MD= 8130 TVD= 6095 SSSV - CAMCO TRMAXX -5E SSSV ■ MD =2065 TVD =2012 12. Attachments: Description Summary of Proposal ° ( 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch i Exploratory r Stratigraphic fl Development r Service fi • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/15/2013 Oil E Gas r WDSPL " Suspended F 16. Verbal Approval: Date: WINJ F✓ • GINJ r WAG ra Abandoned E Commission Representative: GSTOR E SPLUG I' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265 -6471 Email: John .W.PeirceOconocophillios.com Printed Name John Peirce Title: Wells Engineer 7 2 Signature ,�'� Phone: 265 - 6471 Date �--'1 ` �1^� Commission Use Only Sundry Number: 3 3r o' Conditions of approval: Notify Commission so that a representative may witness �/` _ „p Plug Integrity E BOP Test r Mechanical Integrity Test fl Location Clearance E rC"�`YTY� Other: Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required: /0 — Li t) .4-- j APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 5 1/ /1.....3 A• . roved appl a tion } iis valid for 12 months trom the date of approval. . Form 10 -403 (Revised 10/2012) G� t � t j\\ \\ ✓ v( �r Submit Form and Attachments in Duplicate \� � O 3 y �` KUP 1A-12 - Conoc Well Attributes • M ax Angle & MD TD A)asoa.IfiC. Wellbore APIIUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292068800 KUPARUK RIVER UNIT INJ 56.70 4,000.00 8,865.0 Comment H2S (ppm) Date Annotation End Date KB -Grd (ft) Rig Release Date "' SSSV: TRDP Last WO: 6/27/2008 39.01 1/6/1982 Well Conlin - 1-8-12, 2252013 4 PM hematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 8,248.0 10/10/2011 Rev Reason: SSV LOCKED OPEN haggea 2/25 /2013 Casing Strings - 1/68008, 27 ",�... Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.063 33.0 80.0 80.0 65.00 H - 40 Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 103/4 9.794 31.2 2,721.0 2,466.5 45.50 K -55 BTC Casing Description String 0... String ID ... Top (8168) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd -_ - - PRODUCTION 7 6.276 29.7 8,852.0 6,748.5 26.00 K -55 Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBI 2 008 3 1 /2 2 27.1 8,181.7 6,139.7 9.30 L -80 31/2 CONDUCTOR, Completion Details 33-80 Top Depth (TVD) Top Intl Noml... Top (8188) ( 8188 ) (1 Item Description Comment ID (!n) SAFETY VLV. , 44=1„ 1 1 27.1 27.1 1.30 HANGER TUBING HANGER 3.500 2,065 ( 2,065.0 2,011.5 34.07 SAFETY VLV TRMAXX -5E SCSSV LOCKED OPEN 2/14/13 Z812 7 c 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.000 7,801.5 5,810.4 30.58 PBR BAKER PBR 3.000 7,814.8 5,821.9 30.53 PACKER FHL Retrievable Packer 2.930 7,926.5 5,918.2 30.10 SLEEVE -C Baker CMU Sliding Sleeve (CLOSED 6/19/2010) 2.813 SURFACE, 8,128.1 6,093.3 29.77 SEAL ASSY Seal Assy w/2 spaceout 3.000 31 -2,721 8,130.0 6,095.0 29.75 PACKER Baker "F -1" Packer 4.000 8,133.4 6,097.9 29.70 SBE SBE 4.000 GAS LIFT, ,,, . 8,173.7 6,132.8 29.13 NIPPLE AVA'D'Nipple 2.750 7,743 8,174.7 6,133.7 29.12 SOS ELMD TTL @ 8162' during SBHP on 3/8/2007 (Shear Out Sub w/Tubing 2.950 Pup) Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth LOCATOR, (TVD) Top Inc! 7.785 Top (8188) ( (°) Description Comment Run Date ID (in) 8,286.0 6,231.6 27.67 FISH Brown '1B' PACKER - Caliper 3/8/07 shows approx. T' ID; 8/27/1985 2.000 _ CAMCO D NIPPLE, BAKER SOS - PUSHED DOWNHOLE PBR, 7,801 BELOW PERFS WITH 2008 WORKOVER PACKER, 7,815 8,310.0 6,252.9 27.15 FISH DMY half of 1" DMY laying @'8252 RKB 12/26/1991 IIII 8,502.0 6,426.4 24.14 FISH Vann Gun 1/6/1982 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens SLEEVE -C, } Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date (sh.- m Type Coment 7.927 7,948.0 8,057.0 5,936.8 6,031.4 C- 1,C- 2,C -3,C -4, 1/6/1982 4.0 IPERF 4" Vann Guns 1A -12 __ -- . 8,062.0 8,071.0 6,035.7 6,043.5 C -1, 1A -12 1/6/1982 4.0 IPERF 4" Vann Guns IPERF, = 7,948-8,057 = - 8,100.0 8,104.0 6,068.6 6,072.7 UNIT B, 1A -12 1/6/1982 4.0 IPERF 4" Vann Guns - 8,120.0 8,124.0 6,086.4 6,089.8 UNIT B, 1A -12 1/6/1982 4.0 IPERF 4" Vann Guns IPERF, - ' 8,162.0 8,164.0 6,122.6 6,124.4 UNIT B, 1A -12 8/20/1985 4.0 CMT 8,062 -8,071 SQZ 8,219.0 8,223.0 6,173.2 6,176.7 A-5, 1A -12 1/6/1982 4.0 IPERF 4" Vann Guns IPERF, 8,100 - 8,104 8,233.0 8,262.0 6,185.3 6,210.5 A 1A - 1/6/1982 4.0 IPERF 4" Vann Guns Cement Squeezes Top Depth Btm Depth IPERF, (TVD) (TVD) 8,720 -8,124 Top (ftKB) Btm (ftKB) (ftKB) (f168) Description Start Date Comment 8,162.0 8,164.0 6,122.6 6,124.4 Cement Squeeze 8 /21/1985 Notes: General & Safety SEAL ASSY, 8,,128 128 End Date Annotation PACKER. 8,130 8/27/1985 NOTE: WORKOVER 9/4/2002 NOTE: PACKER/SEAL ASSEMBLY SEPARATION SBE, 8,133 1 7/12/2008 NOTE: VIEW SCHEMATIC w/9.0 6/20/2010 NOTE: WAIVERED WELL IA x OA COMMUNICATION -- 2/17/2013 NOTE: LEAKS FOUND @ 8072 8 8090 CMT SOZ, 8,182-8 ,164 Cement SOZ, .8'6 8,162 NIPPLE. 8,174 f (_ SOS, 8,175 - - - = z� iii I IPERF, - s = - 8,219 -8,223 IPERF. _ Mandrel Details 8,233 -8,282 Top Depth' Top Port (TVD) Inc! OD Valve Latch Size TRO Run N... Top (ftKB) (SKB) (1 Make Model (!n) Sery Type Type (in) (psi) Run Date Com... FISH, 8,286 1 7,743.3 5,760.8 31.57 CAMCO MMM 1 1/2 GAS LIFT DMY RK 0.000 0.0 7/6/2008 FISH, 8,310 FI511. 8.502 f PRODUCTION, 30 -8,852 TD, 8,865 . • • v 1A -12 Tubing Patch Installation Proposal 1A - is an A and C sand selective injector that was drilled and completed in 1982. A 2008 RWO replaced all of the old tubing with new 3.5 ", 9.3 #, L -80 tubing. An Leak Detect Log on 2 -17 -13 identified 2 tubing leaks in the C sand selective at 8072' and 8090' RKB that take 100% of PWI to the C sand. On 4- 13 -13, a pre -patch drift with a 2.75" x 18.5' OAL dummy patch reached 8130' SLM with no obstructions detected in the tubing. Per this procedure, a single 30' OAL retrievable tubing patch will be installed across both of the tubing leaks to halt all PWI entering the C sand to improve the injection support of the offset A sand producers. Procedure: E -line 1. RIH & set a retrievable Packer at 8097' RKB (top). This puts the lower Packer for a tubing patch —7' below the top of a 3.5" full joint and —7' below the lower tubing leak at 8090' RKB. With the C sand leaks just above the Packer, an MIT -T will not be performed to verify the Packer set integrity. POOH. RD. Slickline 2. RIH with upper patch run assembly to the top of the lower Packer set at 8097' RKB (top). Sting into the lower Packer at 8097' RKB then set the upper retrievable Packer of the patch at 8067' RKB. This puts the upper Packer —5' below the top of a full joint and about 5' above the upper tubing leak at 8072' RKB. This completes a 30' OAL tubing patch at 8067 - 8097' RKB. POOH with setting tools. RIH with a test plug. Set the plug in the upper patch packer at 8067' RKB and perform a MIT -T to 2500 psi to verify integrity of the upper Packer and the tubing above. Pull the test plug. RD. Return 1A -12 to 'A sand only PWI'. JWP 4/17/2013 ., 0 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday, April 10, 2012 Jim Regg P.I. Supervisor 1 � �tlC `I- /fZ((Z- SUBJECT: Mechanical Integrity Tests l CONOCOPHILLIPS ALASKA INC 1A -12 FROM: Lou Grimaldi KUPARUK RIV UNIT 1A -12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J NON - CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A - 12 API Well Number 50 029 - 20688 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 181 - 178 - Inspection Date: 3/13/2012 Insp Num: mitLG120313151320 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 - Type Inj W "ITVD 5822 - I IA 398 3200 - 3145 3140 - PTD 1811780 T ype Test SPT Test psi 3000 J OA 260 465 1 475 490 Interval REQVAR IP/F P - Tubing 2050 2050 2050 2050 Notes: Inner Annulus test required by variance A.A. 2B.049. 2.5 Bbl's pumped, 3.2 Bbl's returned. 2nd test on IA due to ice plug found in OA jewelry upon rig -up on OA, this is repeat of first IA test. • , Tuesday, April 10, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 10, 2012 TO: Jim Regg / P.I. Supervisor � E. -'f -L{ 1 I f 7, 1 ('Z SUBJECT: Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA INC 1A -12 FROM: Lou Grimaldi KUPARUK RIV UNIT IA-12 Petroleum Inspector Src: Inspector Reviewed B P.I. SuprvjLe— NON CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1A - 12 API Well Number 50 029 - 20688 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 181 Inspection Date: 3/13/2012 Insp Num: mitLG120313135156 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well r 1A-12 [ Type Inj W'ITVD 5822 - IA 1 395 474 1 472 1 484 PTD 1 1811780 - Type Test SPT (Test psi 1800 y OA 214 2000 - 1948 _ 1934 , Interval REQVAR P/F P - I Tubing 2050 2000 2025 2050 Notes: Outer Annulus pressure test required by A.A. "2B.049 ". 1.2 Bbl's pumped, 1.5 Bbl's returned. Test pressures held well within allowable limits. Had to retest due to ice plug found OA jewelry prior to this OA test. See subsequent report for Inner Annulus pressure test this day. 1 5p i- M't L-C 12,03I31513 z• Tuesday, April 10, 2012 Page 1 of 1 • 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 16, 2012 TO: Jim Regg '' ? j 1 P.I. Supervisor \` -(• - SUBJECT: Mechanical Integrity Tests f l CONOCOPHILLIPS ALASKA INC 1A -12 FROM: Lou Grimaldi KUPARUK RIV UNIT 1A -12 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry Jae-- - NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A - 12 API Well Number: 50 029 - 20688 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG120313133510 Permit Number: 181 - 178 - 0 Inspection Date: 3/13/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A-12 - Type Inj. W TVD 5822 ' ' IA 460 3200 - 3129 3120 - PTD 1811780 - TypeTest SPT Test psi 3000 OA 20 20 25 25 Interva PE P/F P / Tubing 2050 2050 2050 2050 Notes: Inner Annulus pressure test required by A.A. "2B.049 ". 2.8 Bbl's pumped, 3.1 Bbl's returned. Test pressures held well within allowable limits. Rigged over to Outer Annulus for it's pressure test. During pressure test of surface equipment on OA portion an ice plug was found in OA jewelry, possible inaccurate readings on OA during test. Will retest IA after OA test. - tulfr_TI -I StANNEP MAP 7 9 4 Friday, March 16, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 16, 2012 TO: Jim Regg '-) P.I. Supervisor ee'' *01 i SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A -12 FROM: Lou Grimaldi KUPARUK RIV UNIT 1A -12 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry V!�� NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT IA - 12 API Well Number: 50 029 - 20688 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG120313135156 Permit Number: 181 - 178 - 0 Inspection Date: 3/12/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1A -12 Type In W- TVD 5822 IA 395 474 472 484 PTD 1811780 TypeTest SPT Test psi 1800 - OA 214 2000 - 1948 1934 Interva REQVAR P/F P ' Tubing 2050 2000 - 2025 2050 Notes: Outer Annulus pressure test required by A.A. "2B.049 ". 1.2 Bbl's pumped, 1.5 Bbl's returned. Test pressures held well within allowable limits. Had to retest IA due to ice plug found in OA jewelry prior to this OA test. See subsequent report for Inner Annulus pressure test this i day. Friday, March 16, 2012 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, March 16, 2012 TO: Jim Re gg ef 3116(12/ g n P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A -12 FROM: Lou Grimaldi KUPARUK RIV UNIT 1A -12 Petroleum Inspector Src: Inspector Reviewed By: � P.I. Supry • PY--- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1A -12 API Well Number: 50- 029 - 20688 -00 -00 Inspector Name: Lou Grimaldi Insp Num: mitLG120313151320 Permit Number: 181 -178 -0 Inspection Date: 3/12/2012 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 'Well 1A-12 ' Type Inj. W TVD 5822 • IA 398 3200 " 3145 3140 - PTD 1811780 TypeTest SPT Test psi 3000 - OA 260 , 465 .. 475 490 . Interva RE P/F P " Tubing 2050 2050 2050 2050 Notes: Inner Annulus test required by variance A.A. 2B.049. 2.5 Bbl's pumped, 3.2 Bbl's returned. 2nd test on IA due to ice plug found in OA jewelry upon rig -up on OA, this is repeat of first IA test. TA 2-- i da j' Friday, March 16, 2012 Page 1 of 1 • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, January 03, 2011 11:13 AM To: 'NSK Problem Well Supv' Cc: NSK Well Integrity Proj � � � Subject: RE: ConocoPhillips Monthly Injector Report - Dec 2010 Attachments: CPAI Failed MITIA Monthly Data 12- 10_edit.xls Martin, et al, I am conducting a review of December's Monthly report. I have just gotten started and wanted to pass back the comments /questions I am developing. also am doing some editing /formatting on the spreadsheet to facilitate printing it off when necessary. I have only edited the 1A -07, 1A -12 and 1B -02 in the attached spreadsheet. The edits are highlighted in yellow. Can these changes be accommodated without a lot of hassle ?? Thanks in advance for looking at this. Tom Maunder, PE AOGCC 3. 1 B -02 — TxIA communication reported 5/6/09. Well last operated 6/09. JAN 2 0 2011 2. 1A-12 — AA 2B.049 issued 6/9/2010. 1. 1A -07 — It is noted that an MITIA failed on 11/13/09, however I have not been able to find that information in our files. I have an email from July 28,2009 that reports failure of a diagnostic MITIA, that the well will be SI, added to the monthly report and diagnostic troubleshooting will begin as soon as feasibly possible. On December 15, 2009 it was reported that a surface casing leak was suspected and that the well is SI and on the monthly report. According to our injection records, the well has not operated since April, 2008. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 1/3/2011 • • The following information is received monthly from CPAI. Reporting this information is a requirement of the administrative approval issued that authorizes continued injection /operation of the well where some integrity compromise is known. As of December, 2010 a total of 65 wells are on this report. Not all wells are actively injecting. From: NSK Problem Well Supv [mailto:n1617 @conocophillips.com] Sent: Saturday, January 01, 2011 10:55 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Schwartz, Guy L (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: ConocoPhillips Monthly Injector Report - Dec 2010 Jim/Tom /Guy, Attached for your records is the ConocoPhillips monthly injector report for December 2010. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 CeII 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 • • ConocoPhillips Well 1A-12 Injection Data • Tbg Psi IA Psi • OA Psi I 4000 3500 3000 2500 a 2000 - ••••••••...• • • 1500 • 1000 - 500 4 • !� • 0 09/10 10/10 11/10 12/10 01/11 Date J PTD# 181 -178 AIO 2B.049 issued 06/09/10 IAxOA Communication MITIA & MITOA passed on 03/16/10 MITOA & OCPOT passed on 04/19/10 AIO 2B.049 requires any pressure bleeds to be reported monthly. No pressure bleeds occurred within the last month. 0 • ConocoPhillips Well 1A-12 Injection Data • Water Injection G Gas Injection 4000 3500 3000 .°_' 2500 a u • • • a 2000 1144111116.1A • • • 1500 • 1000 500 I 0 0 500 1000 1500 2000 2500 3000 3500 4000 4500 Injection Rate, bwpd or mscfpd J Date of Water Gas Injected Tubing IA Pressure OA Pressure Injected Pressure Injection (bwpd) (mscfpd) (psi) (psi) (psi) 31- Dec -10 105 0 2218 452 431 30- Dec -10 62 0 2341 420 329 29- Dec -10 12 0 1975 421 311 28- Dec -10 81 0 1871 405 258 27- Dec -10 5 0 1889 428 338 26- Dec -10 100 0 1942 420 315 25- Dec -10 51 0 2023 427 363 24- Dec -10 4 0 2023 446 453 23- Dec -10 63 0 2002 490 642 22- Dec -10 596 0 2008 496 709 21- Dec -10 563 0 2075 441 545 20- Dec -10 429 0 2233 410 430 19- Dec -10 501 0 1992 376 335 18- Dec -10 37 0 1929 384 388 17- Dec -10 63 0 1984 342 218 16- Dec -10 5 0 2109 315 130 15- Dec -10 5 0 2167 313 120 14- Dec -10 3 0 1965 357 248 13- Dec -10 90 0 2228 352 227 12- Dec -10 915 0 2095 351 164 11- Dec -10 1325 0 1968 347 142 10- Dec -10 1 0 2149 358 162 9- Dec -10 94 0 2159 363 168 8- Dec -10 1543 0 2172 371 202 7- Dec -10 4183 0 2141 359 141 6- Dec -10 3914 0 2129 377 173 5- Dec -10 3615 0 2173 371 142 • • 4- Dec -10 1621 0 2178 392 273 3- Dec -10 97 0 2186 393 270 2- Dec -10 147 0 2180 385 233 1- Dec -10 136 0 2180 369 143 30- Nov -10 220 0 2175 381 191 29- Nov -10 389 0 2185 390 191 28- Nov -10 455 0 2201 392 172 27- Nov -10 418 0 2188 395 182 26- Nov -10 432 0 2189 404 213 25- Nov -10 468 0 2202 412 258 24- Nov -10 469 0 2206 414 277 23- Nov -10 445 0 2199 416 287 22- Nov -10 454 0 2210 423 308 21- Nov -10 587 0 2232 386 195 20- Nov -10 255 0 2135 368 126 19- Nov -10 28 0 2128 390 153 18- Nov -10 349 0 2190 385 128 17- Nov -10 158 0 2153 493 303 16- Nov -10 629 0 2364 502 364 15- Nov -10 667 0 2287 544 449 14- Nov -10 816 0 2347 530 426 13- Nov -10 757 0 2326 530 452 12- Nov -10 742 0 2329 537 473 11- Nov -10 715 0 2312 555 539 10- Nov -10 852 0 2327 510 477 9- Nov -10 687 0 2255 447 315 8- Nov -10 559 0 2202 423 273 7- Nov -10 377 0 2157 451 340 6- Nov -10 638 0 2238 448 375 5- Nov -10 526 0 2072 495 493 4- Nov -10 647 0 1731 540 590 3- Nov -10 810 0 1839 540 590 2- Nov -10 525 0 2007 319 111 1- Nov -10 67 0 2190 493 469 31- Oct -10 424 0 2243 580 652 30- Oct -10 789 0 2289 510 464 29- Oct -10 993 0 2305 355 155 28- Oct -10 413 0 1373 378 173 27- Oct -10 571 0 2200 372 163 26- Oct -10 562 0 2196 390 213 25- Oct -10 515 0 2176 400 233 24- Oct -10 571 0 2200 373 188 23- Oct -10 423 0 2152 418 277 22- Oct -10 609 0 2213 463 353 21- Oct -10 936 0 2284 400 259 20- Oct -10 586 0 2186 375 222 19- Oct -10 409 0 2139 361 202 18- Oct -10 328 0 2116 370 223 17- Oct -10 480 0 2148 362 216 16- Oct -10 355 0 2112 342 165 15- Oct -10 473 0 2149 341 163 14- Oct -10 540 0 2165 326 140 • • 13- Oct -10 464 0 2132 314 121 12- Oct -10 244 0 2079 329 125 11- Oct -10 318 0 2106 383 169 10- Oct -10 462 0 2136 431 221 9- Oct -10 659 0 2255 432 235 8- Oct -10 676 0 2252 436 249 7- Oct -10 724 0 2255 415 233 6- Oct -10 656 0 2231 384 179 5- Oct -10 525 0 2190 375 159 4- Oct -10 458 0 2173 401 208 3- Oct -10 671 0 2237 358 134 2- Oct -10 506 0 2184 387 185 ConocoPhillips P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~ V ~~ ~8sk~ (k! ~ Gay Cis. CAtl~pss'ran Anci~~rape Igo" ~~ !-R~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25th 2007 & March 21 2009, the corrosion inhibitorlsealant was pumped July 6th, 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor a i ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16110 1 A. 1 C.1 E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A 12' 5002920$880000 1811780' 2" Na 2" Na 1.7 7/8!2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" Na 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6!2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1 C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1 C-09 50029208590000 1821850 38' 8.00 6" 11 /25/2007 6.8 7/6/2010 1 C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" Na 1.7 7/7/2010 1E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" n/a 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" Na 5" n/a 2.6 717/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" n/a 1.7 7R/2010 1 E-21 50029208920000 1830020 3" n/a 3" n/a 2.6 7/7/2010 1E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" Na 7" n/a 2.5 7/8/2010 • ~~Q~~ 0~ p~p~~(Q /a~,..w.ELL~o~A.~ Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. t j , ~ r P.O. Box 100360 '~'*~ ~e:'~~=~~ ~.~1.~~~' .~ (~~t~: Anchorage, AK 99510-0360 RE: KRU 1A-12 (PTD 1811780) Request for Administrative Approval Kuparuk River Oil Pool Dear Mr. Walters: In accordance with Rule 9 of Area Injection Order (AIO) 02B.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby grants ConocoPhillips Alaska Inc. (CPAI)'s request for administrative approval to continue water injection in the subject well. Kuparuk River Unit (KRU) 1 A-12 exhibits inner annulus (IA) by outer annulus (OA) communication. Tests confirm communication; however it has not proven possible to positively locate the leak. CPAI does not plan to make repairs at this time. The Commission finds that, based upon reported results of CPAI's diagnostic procedures and wellhead pressure trend plots, KRU 1A-12 exhibits competent barriers to the release of well pressure. Accordingly, the Commission believes that the well's condition does not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in KRU 1A-12 is conditioned upon the following: 1. CPAI shall record wellhead pressures and injection rate daily; 2. CPAI shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 3. CPAI shall perform an MITT or MITIA every 2 years to the maximum anticipated injection pressure; 4. CPAI shall perform aMIT-OA to 1800 psi every 2 years. 5. CPAI shall limit the well's OA pressure to 1,000 psi; 6. CPAI shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; AIO 2B.049 • • June 9, 2010 Page 2 of 2 7. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 8. The MIT anniversary date is March 16, 2010 unless CPAI performs new MITs when the well is returned to operation. DONE at Anchorage, Alaska and dated June 9, 2010. The Alaska Oil Daniel T. Seamount, Jr. Commissioner, Chair Conservation Commission Cathy . Foerster Commissioner RECONSIDERATION AND APPEAL As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(6), "[t]he questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. • ConocoPhillips ~~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 May 4, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: CJ ~~~~~vE~ ~)U~ ~ ~ ~U10 Ale:k~ Qil €~ faas Cep:. Eommission Aneherage ConocoPhillips Alaska, Inc. presents the attached proposal per AIO 2B, Rule 9, to apply for Administrative Approval allowing well 1A-12 (PTD 181-178) to be online in water only injection service with known IAxOA communication. ConocoPhillips intends to pursue repairs should MI injection be desired in the future. If a successful repair is achieved we will request the well be returned to normal status and resume the ability to inject MI. If you need additional information, please contact myself or Brent Rogers at 659-7224, or MJ Loveland / Perry Klein at 659-7043. Sincerely, ~~~ Martin Walters Problem Wells Supervisor ConocoPhillips Alaska Inc. Cc: Working Well File, Legal Well File, File Room, CPFI PE, CPF1 DSLT • • ConocoPhillips Alaska, Inc. Kuparuk Wel11A-12 (PTD 181-178) Technical Justification for Administrative Relief Request Purpose ConocoPhillips Alaska, Inc. proposes that the AOGCC approve this Administrative Relief request as per Area Injection Order 2B, Rule 9, to continue injection with known annular communication for Kuparuk injection well 1 A-12. Well History and Status Kuparuk River Unit well 1A-12 (PTD 181-178) was drilled as a development well in 1981 and 1982. It was completed in 1982 and was converted to an injection well in 1986. 1A-12 was originally reported to the Commission on March 8, 2010 as showing signs of IAxOA communication. Recent tests and surveys performed are as follows: Date Test Result Comment 04/19/10 OC POTs Passed 04/19/10 MITOA Passed 03/16/10 MITOA Passed 03/16/10 MITIA Passed 10/29/09 IC POTS Passed 10/29/10 MITOA Passed 02/25/09 MITOA Passed 02/25/09 MITIA Passed Despite passing all diagnostic tests, the IA and OA on this well equalize after bleeds. ConocoPhillips intends to pursue repair of the leak when it can be justified. ConocoPhillips requests an AA which will allow the OA to equalize with the IA in water only injection at a pressure not to exceed 1000 psi. Well Integrity Supervisor 5/4/2010 • Barrier and Hazard Evaluation • Tubing: The 3.5" 9.3# L-80 tubing has integrity to the packer @ 7801' MD based on a passing MITIA as outlined above. Production casing: The 7" 26# K-55 (internal yield of 4980 psi) production casing has integrity to the packer @ 7801' MD based upon a passing MITIA as outlined above. Communication with the OA exists over a longer period of time. Surface casing: The 10-3/4" 45.5# K-55 (internal yield of 3580 psi) surface casing set at 2721' MD has integrity based upon passing MITOA as outlined above. Primary barrier: The production tubing is the primary barrier. Second barrier: The surface casing and cement shoe are the secondary barrier. Monitoring: Each well is monitored daily for wellhead pressure changes. Should any additional communication develop, it will be noted during the daily monitoring process and appropriate corrective action, up to and including ashut-in of the well. T/I/O plots are compiled, reviewed, and submitted to the AOGCC for review on a monthly basis. Proposed Operating and Monitoring Plan 1. Well will be used for water injection only (no gas or MI allowed), IA pressure may equalize with injection pressure; 2. Perform a passing MITT or MITIA every 2-years as per AOGCC criteria (0.25 x TVD @ packer, 1500 psi minimum); 3. Perform a passing MIT-OA or IAxOA CMIT to 1800 psi every 2 years; 4. IA & OA pressure not to exceed 1000 psi. 5. Submit monthly reports of daily tubing & IA pressures and injection volumes; 6. Shut-in the well should MIT's or injection rates and pressures indicate further problems with appropriate notification to the AOGCC. Well Integrity Supervisor 5/4/2010 2 . - KUP • 1A-12 p 1, ~~~I s ~(MOC~ Well Attributes Max An le & MD TD p r 11 Ata ~ 111 W ellbore API/UWI 500292068800 Fieltl Name WeIISWtus KUPARUK RIVER UNIT INJ Incl (°) 56.70 MD (ttKB) 4,000,00 Act Blm (flKB) 8,865.0 G "' _ S ommeM H25 (ppm) SSV: TRDP 0 Date 7/112008 Annotation Entl Date Last WO: 6/27/2008 KB-Grd (R) 39.01 Rig Release Dat 1/6/1982 WeII Confi9 - to-12 12/6I700~ % 36 .7 AM Schematic-Actual A nnotation Depth (RKB) End Date Annotation Last Mo d ... End Date 12 2 ' L ast Tag: SLM 8,270.0 12/5/2009 Rev Reason: TAG, OPEN CMU Imosbor 16/ 00 . Casin Strin s ~ _ _ C - C asing Description ONDUCTOR String 0... 16 String ID ... 15.063 Top (ttKB) 0.0 Set Depth (f... 80.0 Sel Depth (ND) ... 80.0 String Wt... 65.00 String ... H~0 Sbing Top Thrd , ~~ 2r C S asing Description URFACE String 0... 103/4 String ID ... 9.794 Top (RKB) 0.0 Set Depth (/... 2,721.0 Set Depth (ND) ... 2,466.5 String WL.. 45.50 String ... K-55 String Top Thrd C asing Description PRODUCTION String 0... 7 String ID ... 6.156 Top (RKB) 0.0 Set Depth (}... 8,852.0 Set Depth (ND) ... 6,748.5 String Wt... 26.00 String ... K-55 String Top Thrd Tubin Strin s CONDUCTOR, o~D T ubing Description String 0... String ID ... Top (RKB) Set Depth (1... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING 4.55 2.992 27.1 8,181.7 6,139.7 9.30 L-80 31/2 Com le tion Det ails SAFETY 1/LV, 70fi5 ~ ToP (ttKB) Top Depth (ND) (RKB) Top Incl (°) Item Description Comment Nom ID (i 27.1 27.1 1.30 HANGER TUBING HANGER 2.9 2,065.0 2,011.5 34.07 SAFETY VLV TRMAXX-SE SCSSV 2.8 SURFACE. o-z n1 7,799.1 5,808.5 31.17 LOCATOR LOCATOR 3.0 7,801.5 5,810.4 30.58 PBR BAKER PBR 3.0 7,814.8 5,821.9 30.53 PACKER FHLRetrievablePacker 2.9 GAS LIFT, 7]43 ' _.. 7,926.5 5,918.2 30.10 __ __ SLEEVE-O __.. ___.. Baker CMU Sliding Sleeve (OPEN 12/5/2009) _ .,.. 2.8 7n w..nj ygg 8.174.7 6,133.7 29.12 SOS/TTL ELMD TTL ~ 81ti2' tlunng St1HF' on elms Pup) Tubing Description String 0... String ID ..- Top (RKB) Set Depth (f... Set Depth (ND) ... PBR.7 BOt TUBING -FISH 2 7/8 2.441 8,288.0 8,310.0 6,252.9 Other In Hole Wireline retrievabFe lu s valves um s fish, etc PACKER, 7,815 T.... nemn IPERF. 7 948A,057 IPERF, 6.067-0,071 IPERF, 6.100-6.104 IPERF. 6.120A,124 SEAL A65V, 6,128 PACKER, 6.130 SBE. 6,133 IPERF, 8.162-8,164 Cement SOZ. 6.1fi2 NIPPLE. 6.174 OSITTL. 8.175 IPERF, 8.219-8.723 IPERF. 6,733b.262 FISH, 6,710 FISH. 6.365 Top (RKB) (RKB) (°) Description Comment Run Date ID (in) R 2R6 6.231 fi 27.67 PACKER Brown'1 B' PACKER -Caliper 3/8/07 shows approx. 2" ID 812711985 3.250 (RKB) 1A- (ah... Mandrel Details Stn 1 Top (RKB) 7,743.3 Top Depth (ND) (RKB) 5.760.8 Top Incl (°) 31.57 Make CAMCO Model MMM OD lint 1 1/2 Serv GAS LIFT Valve Type DMY Latch Type RK Port Size tin) 0.000 TRO Run (psi) 0.0 Run Date 7/612008 Com... FISH, 8.502 PRODUCTION, oa6s2 TD. B 865 Well Name 1A-12 Notes: Administratvie Application End Date 5/15/2010 Bleed History Days 365 Start Date 511 512 0 0 9 WELL IO TIME STR-PRES END-PRES DIF-PRES CASING SERVICE Annular Communication Surveillance 1A-12 4/19/2010 210 105 105 OUTER PWI 1A-12 4!1312010 334 150 184 OUTER PWI 1A 12 3/16/2010 600 625 -25 INNER PWI 4 180 4 3 3 2 .y 1Z 2 1 1 500 _ WHP _ IAP 000 _ OAP WHT 500 000 500 000 500 000 ~ 500 0 1A-12 3!16/2010 580 340 240 OUTER PWI 160 1A-12 3/5/2010 800 150 650 OUTER PWI to-12 2!7/2010 1450 1436 14 INNER PWI 140 1A-12 2/7/2010 800 150 650 OUTER PWI 1A-12 2/6/2010 1450 150 1300 OUTER PWI to-12 1/25/2010 1000 400 600 OUTER PWI 120 1A-12 11/25/2009 200 70 130 OUTER PWI 1A-12 10/29/2009 680 210 470 OUTER PWI 100ty 1A-12 10/23/2009 720 210 510 OUTER PWI ~ d 1A-12 10/10/2009 675 300 375 OUTER PWI 80 ~ to-12 10/2/2009 660 500 160 OUTER PWI 1A-12 9/30/2009 1100 400 700 OUTER PWI 1A-12 9/26/2009 2000 1000 1000 INNER PWI 60 1A-12 9/27/2009 1200 100 1100 OUTER PWI 1A-12 6/21/2009 150 650 -500 INNER MIS 40 1q_12 5/1/2009 650 200 450 OUTER MIS 1A-12 4/13/2009 600 100 500 OUTER MIS 20 1A-12 2!25!2009 350 660 -510 INNER MIS to-12 1/26/2009 150 45 105 OUTER MIS 1A-12 12/21/2008 510 300 210 OUTER MIS 0 to-12 12/12/2008 300 500 -200 INNER MIS Apr-09 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Mar-10 Apr-10 May-10 Jun-10 1A-12 8/29/2008 600 220 380 OUTER PWI 1A-12 3/2/2008 1420 900 520 OUTER PWI iaoo ~DGI 1A-12 2/29/2008 1500 900 600 OUTER P I eoro ~MGI 1A-12 214/2008 1500 1000 500 OUTER PWI B00° PWI 1A-12 1/27/2008 1300 850 450 OUTER PWI m ~0°D '^""'SWI to-12 1/22/2006 1405 900 505 OUTER PWI am° `~BLPD I 1A-12 1/22!2008 1400 800 600 OUTER PWI i $0°° 1A-12 1/22/2008 1950 750 1200 INNER PWI 10°° 1A-12 5/29/2007 200 25 175 OUTER PWI ° 1A-12 5/29/2007 250 250 0 INNER PWI Apr-09 May-09 Jun-09 Jul-09 Aug-09 Sep-09 Oct-09 Nov-09 Dec-09 Jan-10 Mar-10 Apr-10 May-10 Jun-10 1A-12 10!30/2005 750 400 350 INNER PWI Date 1A-12 1A-12 10/25/2005 10/2512005 800 750 300 450 500 300 OUTER INNER PWI PWI \_J ~~ f~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 1A-12 Run Date: 2/8/2010 March 12, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1A-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-20688-00 Injection Profile Log 50-029-20688-00 ~~ ~~ ry ~~~ ~:;~e~r~Z~'CC~,,,~~. ~K~ 1, c! L~ i 1 Color Log PLEASE ACKNOWLEDGE RECEII'T BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. U ~ ~, Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@h~ll~burton.cam _ - Date: ~ `~ Ll S 3 Signed: MEMORANDUM TO: Jim Regg ~ -y pq! ~~ P.I. Supervisor ( I l FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commis DATE: Monday, August 18, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1A-12 KLJPARUK RIV UNIT IA-]2 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~~= Comm Well Name• KUPARUK RIV UNIT 1A-12 Insp Num: mitCS08081716s400 Rel Insp Num: API Well Number: 50-029-20688-00-00 Permit Number: t8t-178-o Inspector Name• Chuck Scheve Inspection Date: 8/17/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well to-IZ Type Inj. ~' TVD sazz ~ szo z~9o z~so z~ao p,T. Isll~so TypeTest SPT Test psi Isoo pA 30o a6o a6o a6o Interval wRKOVR p~ P '~ Tubing ztoo ztoo ztoo ztoo NOteS• Initial test post workover to repair IA x OA comunication. , ~it!"iiiN~~ J~~ ~ ~ 2DD~ Monday, August 18, 2008 Page I of 1 -~D~ ~ ~,~~w~ r < . ~ ~, ~n~~~ STATE OF ALASKA ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATICI`~ - 1. Operations Pertormed: Abandon ^ Repair Well ~ " Plug Perforations ^ Stimulate ^ Other ^ Alter Casing ^ PuII Tubing Q - Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: COnOCOPhillips Alaska, Inc. Development ^ Exploratory ^ 181-178 / - 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20688-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-12 ' 8. Property Designation: 10. Field/Pool(s): _ ADL 25647 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8865' ~ feet true vertical 6761' , feet Plugs (measured) Effective Depth measured 8375' feet Junk (measured) 8310', 8365', 8502' true vertical feet Casing Length Size MD TVD Burst Collapse Structural GONDUCTOR 80' 16" 80' 80' SURFACE 2721' ' 10-3/4" 2721' " ' °• ~:, 2466' ~~~ ~~~ ~ ~ 2~~g ' PRODUCTION 8852 7 8852 6750 Perforation depth: Measured depth: 7948'-8057', 8062'-8071',8100'-8104', 8120'-8124', 8162'-8164', 8219'-8223', 8233'-8262' true vertical depth: 5937-6031,6036-6044, 6069'-6072', 6086'-6089', 6123'-6124', 6173'-6176', 6185'-6210 Tubing (size, grade, and measured depth) 3.5" , L-80, 8182' MD. r(~; Packers &SSSV (type & measured depth) pkr- BAKER'FHL' retriev pkr; BROWN'F-1' PACKER; Brown '1 B' Pkr @ pkr- 7815', 8130', 8286' Camco TRMAXX-5E SSSV @ 2065' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI Subsequent to operation SI -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG Q GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the f regoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-168 Contact nnis - 1544 Printed Name Is Title Wells Group Engineer $ f ~ ~ Signature Phone: 265-1544 Date j ' Pre ared b aro Allsu Drake 263-4612 ~~'~(~s" Form 10-404 R ed 04/2006 ®R ~ G ~ N A L ~, ~i~i.; rt ~ ~QQ~ Submit Original Only l ~ C©nocot'hittips Time Log & Summary 1NelN7ew Web RBAOrtlng Report Well Name: 1A-12 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 6/20/2008 4:00:00 PM Rig Release: 6/27/2008 7:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 6/21)/2©l)8 24 hr summary Tested tree on 1A-16RD, pumped 70 bbls freeze protect dwn IA, set BPV, RDMO, moved rig from 1A-16 to 1A-12, RU and killed well w/seawater, installed BPV. 14:30 16:30 2.00 MIRU MOVE MOB P Moved rig from 1A-16 to 1A-12, pulled over well and bermed cellar. Rig accepted at 16:30 hrs on 6/20/08. 16:30 17:00 0.50 COMPZ RPCOM RURD P RU hardline to kill tank,,RU ,lubricator and ull BPV. 17:00 19:00 2.00 COMPZ RPCOM RURD P .Spot tanks and mud shack, load pits w/sea-water, called grease truck to service leaking IA valve, RU on tree to circ to kill tank and tested hardline, tbg press= 130psi, IA ress= 600 si, OA ress= 500 si. 19:00 22:00 3.00 COMPZ WELCTL KLWL P PJSM on well kill operation, break circ w/sea-water staged rate up to 4bpm at 550 psi., pumped a total of 330 bbls sea-water. 22:00 23:00 1.00 COMPZ RPCOM OWFF P Shut in and monitored well. 23:00 23:30 0.50 COMPZ RPCOM RURD P Blow dwn and RD circ lines. 23:30 00:00 0.50 COMPZ WELCTI OTHR P Install BPV. 6/21 /2008 ND tree, NU 11" BOP and tested, RU and POOH w/ 3 1/2" tubing to the SSSV, RIH w/storm packer and set at 60', ND BOP and tubin head. Lost total of 52 bbls. 00:00 01:30 1.50 COMPZ RPCOM NUND P ND tree and install test dart. 01:30 04:30 3.00 COMPZ RPCOM NUND P NU 11"BOP. 04:30 08:00 3.50 COMPZ WELCTL BOPE P Test BOP equipment at 250 / 3,000 psi. Witness waived by John Crisp on 6-20-08. 08:00 09:00 1.00 COMPZ RPCOM OTHR P Pull BPV, PU MU landing joint, BOLDS. 09:00 09:30 0.50 COMPZ RPCOM OWFF P Bleed gas from IA under hanger. 09:30 11:00 1.50 7,852 7,852 COMPZ RPCOM CIRC P Unseat han er and ull out of PBR @ 7852', pulling 125K#. Up wt 107K#. Reverse circulate 1 annular vol, 3 b m 180 si. Page 1 of 5 f Time Logs Date _ From To Dur 5 De th E. De th Phase Code Subcode T Comment 11:00 15:30 4.50 7,852 5,952 COMPZ RPCOM PULD P LD hanger. POOH and LD 1900' of 3.5" o m I g~ witj~~~, spooling SSSV control line. Retrieved 34 SS bands, previous run tally is suspect. Tally had 60 SS bands run in hole. Control line came out of hole banded to every other joint. All bands retrieved were in good condition. LD SSSV and tubing, strap and kick out. 15:30 18:00 2.50 5,952 5,984 COMPZ RPCOM HOSO P PU MU storm acker. RIH to 66' below wellhead. Bottom of 3-1/2" tubing at 5984'. Set packer and LD Dp and running tool. PT packer to 5 0 si. 18:00 21:00 3.00 5,984 5,984 COMPZ RPCOM NUND P Drain stack and ND BOP and bleed off OA. 21:00 00:00 3.00 5,984 5,984 COMPZ RPCOM NUND P ND tubing head and remove pack off assembly. Csg hanger rose 7.5" out of cs head, dress fluted hanger, replaced one dams ed lock dwn stud and land nut, Toatal fluid loss 52 bbls for last 24 hrs. 6/22/2008 MU new tubing head, NU BOP and test breaks, POOH w/ storm packer, cunt POOH LD tubing, rack and tall 3 1/2" DP, PU and sin led in hole to 1,533'. Lost total of 9 bbls. 00:00 06:00 .6.00 5,984 5,984 COMPZ RPCOM NUND P Dress fluted 7" hanger, install new lockdown and gland nut, installed new tubing spool and NU while rack and tall 3 1/2" DP. 06:00 06:30 0.50 5,984 5,984 COMPZ RPCOM DHEQ P Press test casing packoff to 3000 si. 06:30 10:30 4.00 5,984 5,984 COMPZ RPCOM NUND P NU BOPE. Press test BOPS body to 3000 si chart . 10:30 12:00 1.50 5,984 5,918 COMPZ RPCOM PULD P MU storm packer retrieval tool and RIH to 66'. Latch into storm packer an P PU wt = 80K#. POOH with storm acker n 12:00 20:30 8.50 5,918 0 COMPZ RPCOM PULD P POOH with remaining 3-1/2" completion pulled from the PBR 7852'. LD, stra and kick out. 20:30 22:00 1.50 0 0 COMPZ RPCOM RURD P RU floor to run DP, load fishing tools, set wear rin . 22:00 23:00 1.00 0 403 COMPZ FISH PULD P PU and MU BHA #1. 23:00 00:00 1.00 403 1,533 COMPZ FISH TRIP P PU and sin le in hole with 3 1/2" DP. 6!23/2008 Engaged PBR and released FHL packer and tubing cut at 7,925'. POOH and LD, RIH w/BHA #2 (mill and ra le milled and en a ed fish at 7,926' and started OOH with selective tb .Lost total of 66 bbls. 00:00 05:00 5.00 1,533 7,802 COMPZ RPCOM TRIP P Singled in the hole with DP and fishing BHA #1. At depth above PBR, u wt = 165M#, do wt = 88M#. 05:00 05:30 0.50 7,802 7,846 COMPZ FISH JAR P Washed down from 7802' to 7846'. Enga ed PBR at 7486', jt #231. PU to 250M# and activated jars. FHL acker released on first lick. Page 2 tsf 5' l Time Lugs Date From To Dur S. De th E. De th Phase Code Subcode T Comment 05:30 07:00 1.50 7,846 7,486 COMPZ RPCOM CIRC P Close bag, begin circulating 3 bpm @ 500psi. Pump 280 bbl with no si ns of as. Monitor well. 07:00 13:00 6.00 7,925 0 COMPZ RPCOM TRIP P PJSM. POOH with DP, fishing BHA #1, PBR, FHL packer and 3-1/2" completion cut at 7925'. Up wt = 173M# do wt = 90M#. 13:00 13:30 0.50 0 0 COMPZ RPCOM OTHR P Clean and clear rig floor. 13:30 16:30 3.00 0 7,904 COMPZ RPCOM TRIP P PU MU fishin BHA #2. RIH with DP to top of tubing stub at 7904', up wt 170K, dwn wt 90K. 16:30 17:30 1.00 7,904 7,917 COMPZ FISH WASH P Break circ at 3 bpm, 300 psi, 40 rpm and wash dwn tagged stub at 7,917' and start dressin tb stub. 17:30 18:30 1.00 7,917 7,917 COMPZ WELCTL CIRC NP Had increase in flow from 18 to 25%, PU strin and closed bag, circ out gas through choke at 3 bpm - 300 , si shut dwn pumps and monitored well for pressure. 0 shut in press, open bag and checked for flow, no flow. Notified AOGCC rep and will test H dril when OOH. 18:30 20:30 2.00 7,917 7,900 COMPZ FISH WASH P Cont washing/milling over fish at 7,917' , 3 bpm - 300 psi, 60 rpm, off bottom torque 6,000 ft/Ibs, on bottom torque 8,140 ft/Ibs, increased rpm to 70 and worked dwn to 7,926' engaging fish with grapple, PU to 180K and ulled assembl free with no roblem. 20:30 21:30 1.00 7,900 7,900 COMPZ RPCOM CIRC P CBU at 5 bpm - 740 psi with no gas at bottoms up, shut dwn and check for flow, no flow. 21:30 00:00 2.50 7,900 4,966 COMPZ RPCOM TRIP ~ P POOH from 7,900' to 4,966'. 6/24/2008 POOH LD selective tbg, RIH and milled "Brown" packer at 8,147', POOH LD BHA #3, RIH with BHA #4 to 4281'. Total fluid loss 108 bbls. 00:00 02:00 2.00 4,966 408 COMPZ FISH TRIP P Gont POOH from 4,966'. 02:00 03:00 1.00 408 0 COMPZ FISH TRIP P LD BHA #2 03:00 04:30 1.50 0 0 COMPZ RPCOM PULD P LD blast'nts, ni le, u s and locator seal assembl left in acker. 04:30 06:00 1.50 0 0 COMPZ WELCTI BOPE P Drain stack and pulll wear ring, set test plug and test Hydril as per AOGCC. Tested at 250 low and 3,000 high, pulled test plug and set wear rin . 06:00 07:00 1.00 0 0 COMPZ FISH TRIP P Load fishing tools in pipe shed. Pull fish out of ra le and LD. 07:00 11:30 4.50 0 8,133 COMPZ FISH TRIP P MU BHA # .,RIH on DP to 8133'. Up wt 155K Down wt 100K. ....Page 3 cf 5 ~~ Time Logs ~ Date From To Dur S. De th E. De th Ph se Code Subcode T Comment 11:30 15:00 3.50 8,133 8,286 COMPZ FISH MILL P Washed down @ 80 RPMs 829 psi & tagged up @ 8138'. Began milling on acker toque 5K ROT 120K. Milled from 8140' to 8143'. Pushed acker down from 8143' to 8286' @ 3 BPM, 300 si. 15:00 16:30 1.50 8,286 8,286 COMPZ FISH ClRC P pumped hi-vis sweep @ 5 BPM, 880 si. 16:30 21:30 5.00 8,286 0 COMPZ FISH TRIP P POOH f/8286' and LD BHA #3. 21:30 22:00 0.50 0 0 COMPZ RPCOM OTHR P Clean out boot baskets and clear rig floor. 22:00 00:00 2.00 0 4,281 COMPZ RPCOM TRIP P MU BHA #4 (bit and scraper) &RIH to 4281'. Total fluid lost 108 bbls for last 24 hrs. 6/25/2008 RIH to 8281', tagged top of pkr, CBU, started OOH w/ BHA #4, LD DP, made 6.05" gauge ring run to 8200', RIH set FB-1 acker at 8130' on a-line, C & S drill line. Lost total of 53 bbls. 00:00 01:00 1.00 4,281 8,281 COMPZ RPCOM TRIP P Cont RIH f/ 4281' to 8281' and tagged kr to . U wt 150K, dwn wt 105K. 01:00 02:00 1.00 8,281 8,281 COMPZ RPCOM CIRC P Break circ & stage up to 8 bpm - 1800 psi and CBU, had 70 units gas at bottoms up. Shut dwn & monitor well. Well static. 02:00 11:00 9.00 8,281 421 COMPZ RPCOM TRIP P POOH w/ BHA #4 & LD 3 1/2" DP 11:00 11:30 0.50 421 0 COMPZ RPCOM TRIP P Break out and LD 12 Drill collars, 'ars, bum er sub, scra er and bit. 11:30 15:00 3.50 0 8,251 COMPZ RPCOM PACK P Pull wear ring. Set 7" shooting nipple and close annular. RU Schlumber E-line. RIH w/6.05" gauge ring_t_o 8251' and POOH. Loading pipe shed with com letion tubin . 15:00 17:30 2.50 0 0 COMPZ RPCOM PACK P PJSM. MU shear out sub w/ wireline entry guide, 2.75" 'D' Nipple, 1 jt 3 1/2" tubing, FB-1 packer w/6' handling pup & SBE, onto running tool. 17:30 22:00 4.50 0 8,130 COMPZ RPCOM PACK P RIH and correlate depth, set top of FB-1 'and POOH, RD SEL. 22:00 00:00 2.00 0 0 COMPZ RIGMNT SVRG P PJSM, cut and slip drill line. Total fluid lost 53 bbls for last 24 hrs. 6/26/2008 RIH with 31/2" completion, attend safety shut dwn at fire hall, space out and spot corrosion inhibitor, ND BOP, NU tree and tested. Lost total of 33 bbls. 00:00 05:00 5.00 0 4,197 COMPZ RPCOM RCST P MU seal assembly and FHL pkr, start RIH with 3 1!2" completion from i eshed to 4197'. 05:00 07:30 2.50 4,197 4,197 COMPZ RPCOM SFTY P Shut Rig down for Safety Stand Down. 07:30 10:30 3.00 4,197 6,120 COMPZ RPCOM RCST P Continue RIH with completion f/4198' to 6120'. Install SCSSV and rig up s oolin unit for control line. Page 4 of 5 .Time Logs Date From To Dur S. De th E De th Pha e Code Subcode T Comment 10:30 13:30 3.00 6,120 8,138 COMPZ RPCOM RCST P Continue RIH, tagged SBE on'FB-1' 8131'. Up wt 103K dwn wt 70K. Kicked on pump, lowered seals into SBE, pressure increased, SD pump, lowered seals down to no- 0 7' 8138' ,stacked out. Pulled seals up 10' above SBE. 13:30 15:00 1.50 8,138 8,138 COMPZ RPCOM CIRC P Loaded IAw/corrosion inhibited brine (1% by volume Baker Petrolite CRW 132) by pumping 204 bbls down tubing, displaced with 70 bbls SW. 3 BPM 185 si. 15:00 16:00 1.00 8,138 8,138 COMPZ RPCOM RCST P Lowered seals back down inside SBE on FB-1 packer fully engaging seal assembly.. PU 2', PT tubin4 to 500 psi. to veri seals. Increased pressure to 2500 psi set FHL aaker @ 7815'. Bleed pressure off. PU, sheared PBR @ 120K. S a - t R 2' o btm and land tubing hanger with a full joint immediately below. Connect control line for SCSS, RILDS. Used 70 SS bands for control line. 16:00 17:00 1.00 COMPZ RPCOM OTHR P RD Cameo spooler and equipment. RU to test tb and IA. 17:00 18:30 1.50 COMPZ RPCOM DHEQ P Pressure tubing to 2500 psi held for 15 min. bled back to 1750 psi. ~ Pressure test IA to 2500 si held _ (charted) for 30 min. Test ok, bled tubing dwn to 2300 psi and sheared SOV. 18:30 19:00 0.50 COMPZ RPCOM RURD P RD circ lines and test equipment, installed HPBPV. 19:00 00:00 5.00 COMPZ RPCOM NUND P ND 11"BOP, NU new tree, RU and test hanger void at 250/5000 psi f/30 min (test good), test tree at 250/5000 (test good). Total fluid lost 33 bbls for last 24 hrs. Installed a total of 70 ss bands on control line. 6/27/2008 Move rig and camp from 1A pad to 1 D pad. Released rig @ 07:00 on 6/27/2008. 00:00 02:00 2.00 COMPZ RPCOM RURD P RD test equipment, start cleaning pits. RU on hardline to take returns to kill tank, test hardline and circ lines w/120 psi air, fluid pack and test lines to 500 psi. Bleed off and ull HPBPV. 02:00 03:00 1.00 COMPZ RPCOM FRZP P PJSM with LRS, pump 100 bbls diesel dwn IA at 2 bpm, ICP 700 psi., FCP 900 si, RD LRS. 03:00 04:00 1.00 COMPZ RPCOM OTHR P Line up and u-tube tbg and IA, cunt clean its. 04:00 07:00 3.00 COMPZ RPCOM RURD P Blow down circ lines and install BPV. Clean wellhead and well site. Release Ri 07:00 on 6-27-08. F~a0~ 5 tsf b F .- ~~ ~ KUP ~ 1A-12 ' ~dn0~g~~~~~pS ~ 1 Well Attributes E'°'?, It1('. I ~ API / UWI F~u1G Name Wett States ,Maxmwn, Inchnahen (") TOtat Depth (nNB) ~ ~ 5002920688 KUPARUK RIVER UNIT INJ 56.70 8,852.0 Comment H2S (ppm) Date Amrotati_. End Date KB-Ground Distance (R) Rig Release DaOe ,~, _ _ _ _ t ~.. _ FM TRDP last WO: 6/27/2008 39.01 1/611982 , _ ~ ,...,. , Annotation Depth (tI KB) End Date Annotatlon End Date Ls7Taq: 8.375. Casing Strings 0 10/25Y1007 Rev Reason: WORKOVER 7112/2008 ~ L >> De ion OU n) 1 lti:Dj Top Set Depth (ti.. Sct DcpM {T VD) {ri.. l'/t {Ibsl... Grade 1 - p Sonnechon _. .. __ TOR ICOrjr ti 16.063 O 0 80.0 80.0 65.00 H-40 ~ ~ Casing Description OD (In) ID (in) Top (t1KB) Set Depth (R.. Set Depth (ND) (R.. VJt (Ibsl... Grade Top Connection `~ ,~ SURFACE 103/4 9.794 0.0 2,721.0 2,466.5 45.50 K-55 . Casing Descriptlon OD (in) ID pn) Top (RKB) Set Depth (R.. Set DepN (ND) (R.. Wt p14s1... ~ Grade Top Connection € PRi~DIJrTIQN 7 6.156 00 8,R52Q 6.74R5 2fi.00 K-rw5 ~" Tubing Strings - . 040 ... ... TuMng besenption OG (ln) ID (In) Top (iC.. set Deptn (RK... set fxpth QVD) (rUIB) Wt plum) Vrade top t:onnecnon TUBING 27/8 2.441 8,288.0 8,310.0 6,252.9 6.50 7ubilg Descdpton OD (in) ID (In) Top (R.. Set Depth (RK... set Depth (ND) (fIKB) wt (Ibs/R) Gratle Top Connection It TUBING 4.55 2.992 0.0 8,181.7 6,139.7 9.30 L-80 31/2 sssv, z,oss ~ - Completion Details SURFACE, az,nt GAS LIFT, 7,743 SLEEVE, 7,827 IPERF, 7.9488,057 IPERF, 8,062-8,077 IPERF, B,tao4, too IPERF, ~ - 8,12a8,124 IPERF, 8,1624,164 ~~- c Cement SOZ, - 8,162 PKR, 6,288 Iaan 1 9_ Fish, 8,310 y^7 Fisn, 6,3&5 Top (RKB) Rem Oc;cription Comment ID (in) 27.1 Hanger TUBING HANGER 2.992 62.5 Space Out Pup 2.992 2,065.0 SSSV TRMAXX-SE SCSSV 2.812 7,799.5 SU8 SPACEOUT FOR PBR 3.000 7,801.5 PBR BAKER PBR 3.000 7,814.8 PACKER FHL Retrievable Packer 2.930 7,926.5 SLEEVE Baker CMU Sliding Sleeve 2.813 8,128.1 SEAL ASSY Seal Assy w/2'spaceout 3.000 8,130.0 PACKER Baker"F-1"Packer 4.000 8,133.4 SBE SBE 4.000 8,737.7 Bottom Sub 2.950 8,173.7 NIPPLE AVA'D' Nipple 2.750 8,174.7 SOS Shear Out Sub w/Tubing Pup 2.950 Other In Hnle lnluns_ euin_ Fixh_ atc_1 Top (hhG) Deacripton Comm ent Run Gate ID pn) 8,286.0 PKR Brown'16' PACKER -CALIPER 318/07 SHOWS APPROX 2" ID 812711985 3.250 8,310.0 Fish DMY half of 1" DMY laying @'8252 RKB 12!26/1991 8,365.0 Fish Shear Out Assy 8/27/1985 8,502.0 Pe rfo rat Top (RKB) Fish ! o n s Top Btm ~ (ND) (RKB) (RKB) Vann Gun Btm (ND) (RKB) Type one shot Dens (sho~~~~ Date 1/611982 omment 7,948.0 8,057.0 5,936.8 6,031.4 IPERF C-1,C-2,C-3,C-4, tA-12 4.0 1/6/1982 4" Vann Guns 8,062.0 8,071.0 6,035.7 6,043.5 IPERF C-1, 1A-12 4.0 1/6/1982 4" Vann Guns 8,100.0 8,104.0 6,068.6 6,072.7 IPERF UNIT B, to-12 4.0 1/6/1982 4" Vann Guns 8,120.0 8,124.0 6,086.4 6,089.8 IPERF UNIT B, to-12 4.0 1/6/1982 4" Vann Guns 8,162.0 8,164.0 6,122.6 6,124.4 IPERF UNIT B, 1A-12 4.0 &20!1985 8,219.0 8,223.0 6,173.2 6,176.7 IPERF A-5, 1A-12 4.0 1/6/1982 4" Vann Guns 8,233.0 8,262.0 6,185.3 6,210.5 IPERF A-0, 1A-12 4.0 1/6/1982 4" Vann Guns Cement Squeezes ~op (RI(B) Dun (ttltDj ~ Start Dal[: ~ D criphon Comment t It~~ C 1 call 'r 11 ~ ! t >yUw'~~. ;Notes: General & Safety Fish, 8,502 PRODUCTION, 68,652 TD, 8,852 ~Mantrel Details set Geprh von Top (ND) Valve Latch site TRO Run g}n (RKB) (RKB) Make Model OD fin! TYPe Type (inl (psi) Run Date Comment 1A-12 Pre Rig and Post Rig Summar~ DATE SUMMARY 6/5/08 PULLED 28.4" UPPER TTS PATCH AND LOWER 41' TTS PATCH. ALL ELEMENTS RECOVERED. 6/7/08 JET CUT TUBING WITH 2.5" POWERCUTTER AT 7925' CORRELATED TO TUBING TALLY DATED 8/27/85. 6/8/08 PULL 1.5" DMY GLV W/ RM LATCH @ STA #1 7809' RKB. JOB COMPLETE. 7/6/08 INSTALL DGLV AT 7743' RKB. PT TUBING TO 2500#. SHEAR SOS AND PERFORM INJECTIVITY TEST; 10 BBL AT 1.5 BBL/MIN AT 2375 PSI. TAG AT 8275' SLM. JOB COMPLETE. FW: Nordic 3 Gas Kick 1A-12 Page 1 of 2 ~ ~ Maunder, Thomas E (DOA) ~~, _ ~~~ From: Jones, Jeffery B (DOA) Sent: Tuesday, June 24, 2008 7:30 PM To: Crisp, John H(DOA); Jones, Jeffery B(DOA); Nobie, Robert C(DOA); Regg, James B(DOA); Seheve, Charles M (DOA) Cc: Maunder, Thomas E (DOA) Subject: FW: Nordic 3 Gas Kick 1A-12 Attachments: 1A-12 Schematic Pre- Workaver.pdf; 1A-12 Schematic during kick.pdf Hi guys, here's more info on the Nordic 3 kick from Pete Nezakicky.. Jeff From: Nordic 3 Company Man [mailto:n1433@conocophillips.cam] Sent: Tuesday, June 24, 2008 7:45 AM To: Jones, Jeffery B (DOA) Subject: FW: Nordic 3 Gas Kick 1A-12 Jeff, the Hydrii was tested this morning after lay down of BHA and fish. It was tested successful(y at 250 psi low and 3,000 psi high. Let me or Shane know if you need a state form filied out and sent to you. Also...if the Sundry Notice does not specifically state to test it at 2,500 psi...do we need to test to 3,000 psi with the other components, or can we test the bag at 2,500 psi? Thanks Rance Pederson Nordic 3 Company Rep 659-7446 From: Nordic 3 Company Man f,, ~ r.~: Sent: Monda June 23, z008 7:56 PM ~~ `~ ` =~'~~`~ Y. ,r~ ~ ~'~~'r~''.-~.`'~' ..~ ~4) +.. To: jeff.jones@alaska.gov' Cr. Nordic 3 Company Man; Nordic 3 Toolpusher Subject: Nordic 3 Gas KiCk 1A-12 Jeff, Here is a summary of events in regards to the gas kick that was taken earlier this evening. • Nordic 3 has been on 1A-12 performing a tubing swap on a 2 zane selective completion (see attached schematic" Pre-Workover") «1A-12 Schematic Pre- Workover.pdf» • Previous operation prior to the fishing run when the kick oc~urred; we pulted the top paeker @ 7852' and putled that portion of the completion down to a jet cut a~ 7925'. (see attached schematic " During Kick") 9/23/2008 FW: Nordic 3 Gas Kick 1A-12 Page 2 of 2 ~ ~ «1A-12 Schematic during kick.pdf» • We ran in hole with 3-1/2 driil pipe and a BHA to dress off the tubing stub @ 7925' and then engage the tubing and pull it free from the SBE at the lower packer at 8147'. • Here is the time line of events: 16:30 - BHA @ 7904', started pumping down the tubing at 3 bpm @ 300 psi. RIH and tag stub @ 7919'. Pick up 5' and start rotating the pipe at 50 rpm. RIH and start milling the flared tubing stub. 17:15 - An increase of 7% of flow was observed. The annular preventer was shut in. SITP = 0 psi, SICP = 40 psi. AOGCC was notified by pager 17:20 - Started circulating 1 annular volume (208 bbl of seawater). 18:00 - Stopped pumping, ~ITP = 0 psi, SICP = 0 psi. Open annular and observe well for flow. 18:20 - No further indications of flow or gas bubbles. Resumed milling operations. . Annular preventer will be tested to 3000 psi as per sundry once this work string is pulled out of hole. If you have any further questions please feel free to call the rig pr my cell phone at 943-1253. regards, Pete Nezaticky / Rick Overstreet (Days) Randy Dolcater / Rance Pederson (Nights} Nordic 3 Company Man OffiCe: 907-659-7446 Fax: 907-659-7566 9/23/2008 • • SARAH PALIN, GOVERNOR t7~~TT~~++~~tt ~~ ®~~.I,nta~rl`r~`i][~7 333 W. 7th AVENUE, SUITE 100 C~"-7.ayRsA~®" C®MI~TI$SI®~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jim Ennis Wells Group Engineer ~ ~ M~+Y `~ 200 ConocoPhillips Alaska Inc. PO Box 100360 ~ , ('1 Anchorage, AK 99510 `~ ~ (~ l .1..--~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 1A-12 Sundry Number: 308-168 Dear Mr. Ennis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Encl. ~,~;,~ RECEfV ,~ STATE OF ALASKA • ~~~~ MAY 0 6 ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~v APPLICATION FOR SUNDRY APPROV~aska ©i1 & Gas Cans. mmission 20 AAC 25.280 Ancharage 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^/ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^/ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 181-178 3. Address: Stratigraphic ^ Service ^ - 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20688-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? YeS ^ NO ~ 1A-12 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25647 ~ RKB 100' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8865' 6761' 8375' 8252', 8365', 8502' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 16" 80' 80' SURFACE 2721' 10-3/4" 2721' 2466' PRODUCTION 8852' 7" gg52' 6750' Perforation Depth MD (7sa8'-8057', 8os2'-8071', Perforation Depth TVD (ft): 5937'-6031', Tubing Size: Tubing Grade: Tubing MD (ft): 8100'-8104', 8120'-8124', 8219'-8223', 8233'-8262' 6036'-6043', 6069'-6072', 6086'-6089', 6173'-6176', 6185'-62 3.5" X 2-7~8" J-55 8146', 8168' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER'FHL' ; BROWN'1B' PACKER -CALIPER 3/8!07 SHOWS AP pkr= 7866' ; 8147' Cameo TRDP-1A SSSV @ 1900' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ~ • 15: Estimated Date for 16. Well Status after proposed work: Commencing Operat June 1, 2008 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ~ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereb 'fy t e foregoing is true and correct to the best of my knowledge. Contact: Jim Ennis @ 265-1544 Printed N im Ennis Title: Wells Group Engi eer Signature Phone 265-1544 ~ Q Date ~j ~ u g Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness V -~ Plug Integrity ^ BOP Test "~ Mechanical Integrity Test ~ Location Clearance ^ ~~ ~f (L~'~ Other: ~V`1~ Pte', ~~~ ~~ 4~ii y`''` `.~~ ~ ~ `,~ Subsequent Form Required: ~'!~ ' < 9' APPROVED BY Approved by: MIS N THE OMM SION Date: Form 10-4~R~ii~d 06/2006 ~ ~ i ~ ~ ~~ ~ ! ~1 `~" ~'1 ~~~ ~ ~. t ~ ~t~~ -' Submit in Duplicate `. • • KRU 1 A-12 Cr~noco~'h~lps A1~ska, Inc, 1 A-12 L 1Q-12 Replace Leaking Selective Workover Procedure for Sundry Pre-riq Work 1. Power cut tbg mid joint @ 7925' below top packer & production mandrel. 2. Pull DGLV @ 7908' and leave open. 3. Set 3" `H' BPV within 24 hrs of MIRU. 4. Prepare location for Workover Rig. Rig Work 1. Verify sundry approval to replace leaking selective. 2. MIRU Nordic #3. Pull BPV. Circ seawater. Verify well is dead. Install BPV. ND tree. NUBOP, 11" w/ 3.5" pipe rams. Function test BOP. Pull BPV. Install blanking plug. PT BOP rams 250/2500, annular 250/2500 psi. AOGCC 24 hr advance notification of BOP test required. (Note: MASP using 3/8/07 BHP & 0.1 psi/ft gradient is 2050 psi) Pull blanking plug &BPV. 3. Unland tbg hanger. Attempt to pull tbg from PBR. If unsuccessful @ 80% yield (114M#), rig up E-line and power cut tbg in middle of first full joint above packer. POOH w/ tbg sideways, spooling SSSV control line as necessary. Survey all equipment pulled for NORM. 4. If PBR pulled OK, go to step 5. If tbg was chemical cut, single in w/ Baker washpipe, overshot w/ grapple, DC's and jars on 3.5" workstring. Circ down to top of PBR locator and engage fish. Pull and/or jar as necessary to remove PBR stick. POOH. 5. RIH w/ fishing assembly on 3.5" workstring and engage 'FHL' packer. Pull and/or jar as necessary to remove 'FHL'. POOH. 6. RIH w/ Baker Rattler fishing assembly. Engage 3.5" tbg stub and attempt to pull seals from Brown IB packer. If unsuccessful, begin pumping filtered fluids through Rattler to shake BHA loose and POOH. 7. If seals released, go to step #8. If not, RIH w/ 250' washpipe assembly & circ down to Brown packer @ 8147'. POOH. RIH w/ overshot fishing assembly. Engage tbg stub and pull/jar as necessary to remove seals. POOH. 8. RIH w/ Brown 'IB' packer burn over assembly. Mill up packer and remove from hole. 9. Roundtrip casing scraper to tag btm. POOH sideways to above perfs. Install storm packer @ +/-100'. NDBOP. Remove tbg head & replace casing packoffs. NUBOP. Test BOPE. POOH w/ storm packer. Finish laying down workstring. 10. RU eline. Set'FB-1' pkr w/ tailpipe, 2.75" 'DS' nipple & SOS @ 8130' KB. RD eline. • 11. RIH w/ 3'/2", 9.3#, L-80, EUE 8rd Mod completion as follows: a. Baker seal assembly b. 3.5" tbg c. GLM w/dummy d. 3.5" tbg e. CMU w/ 2.813" DS profile f. 3.5" tbg g. FHL pkr &PBR h. GLM w/ SOV i. 3.5" tbg j. 2.875" Camco `DS' nipple @ 500' 12. Locate seal bore on 'FB-1 pkr. Spot corrosion inhibited brine in IA to 'FB-1' pkr. Sting into sealbore. Tag btm & pull up to string weight. Pressure tbg to 2500 psi to set 'FHL' @ 7860' KB. 13. Shear PBR. Space-out 2' off btm, land tbg hanger. RILDS. RU chart recorder to tbg & IA. With the annulus open, PT tubing to 2500 psi for 15 minutes. Bleed off tubing pressure to 1750 psi. Holding the tubing pressure at 1750 psi, PT IA to 2500 psi for 15 minutes. Bleed off tubing pressure to shear the dump kill valve. Install TWC. NDBOP. NUWH. Test tree and packoffs to 5000 psi. Pull TWC & install BPV. RDMO. Post-riq Work 1. Freeze protect well with diesel. 2. RU slickline. 3. Replace shear valve w/dummy. PT tbg 2500 psi to test dummy. 4. Pressure tbg to 3500 psi to shear SOS. rage i or ~ ~ • Maunder, Thomas E (DOA} ~rom: Ennis, .1 J [J.J.Ennis@conocophiilips.com] Sent: Thursday, May 08, 2008 2:41 PM To: Maunder, Thomas E ~DOA) Subject. 1A-16RD (182-031) and 1A-12 (181-978) BOP stack diagram Attachments: Nordic 3 11in 5m stack.pdf i a~~. ~C?P si~c~ di~gr~r~ ~fi~~~~~ci ~~ r~qu~~f~c~. Q~ ~v~ r~eed tc~ ~t~rt incl~dir~g ~~1 ~1# ~C~3'~? Jim E»nis / j.ennFs@conocophlllips.cam (so~1zs~~~a ryv~ (907)632-~z$~ {c~ P~~.~~~~~% ,Jl.~~. `~' :f_ lU~i~ From; Maunder, Thomas E {DOA) [mailto:tom.maunder@aCaska.gov) Sent: Thu+~lay, May 08, 2008 12:4b PM To: Ennis, 7 J 5ub~ect: i~E; 1A-16RD (182-03i) and IA-1Z (i81-1~8) .~(i7i, Sorry I missed thaf. Yes, if you have ~ ne~ drawing that wauld be appreciated. clectranic wQU)d be great. i presume the s#ack is 3-ram and two sets of pipe wiil be a~ailable. ! knavd IVIASP might nofi require 2, but back-up never hurts. ! alsa noted that you planned a 25t10 psi BQP test, ag~in in line with the MASP. Hot~ever, ~he requirement that 1 have placed an the sundry is 3fl00 psi minimum. Gall or messa~e ta discuss. Thanks again fior the quick response. Tom Maunder, PE ACJGC~ From: ~nnis, J 7 [mailto.].J.Ennis@c~nooophiliips.com] Sent: Thursday, May 08, 2a081f:31 AM To: Maunder, Thomas E {DOA) Subject: RE: 1A-16RD (i82-031) and IA-IZ (181-178) ~c~~~ t~caar~i~B~ Ter~; ~~ ~~~r~ ir~ ~i~ ~~dc~r4~ ~t~p ~Lf ~ve vvil# b~ u~ir~~ ~c~rciic ~3 and tt~eir i s" stack. L~o you ~e~t~ ~ stac~ ~i~~r~~;~ Jim Ennis % J•en»is~conocoptri!lips.com {SO7)ZG5-1.ri~4 (IA~ r90TJ632~TZ81(C) 9/23/2Q48 rage L vi ~ ~ ~ From: Maunder, 'i'homas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Wednesday, May 07, 2008 4:55 PM To: Ennis, 7 ) Subject: 1A-15RD (182-031) and 1A-12 {181-178j Jim, I just finished reviewing the sundries to workover 1A-16RD and 1A-12. A couple of questions ._. 1. What rig wili be employed to conduct the wvrtc? 2. What stack ~nfiguratian wiA be empioyed? Tom Maunder, PE AOGCC 9/23/2008 isu~ai un iii~~~~ivu vv cu t~C~vi ~ui~ ~ Yage 1 OI 1 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] r..~ Sent: Tuesday, February 19, 2008 1:34 PM ~ ~~?~,, ~ ,f' ~ ~' To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Problem Well Supv; NSK Well Integrity Proj Subject: Kuparuk Injection Well Reporting Jim, Per our phone conversation, here is a list of injection wells that we are in the process of pursuing AA's for A1026. Each of these wells have been waivered under ConocoPhillips Well Operating Guidelines and reported to the State as a group on a spreadsheet in June 2007. They also may have been reported individually at the time of the waiver or in the first group report submitted 10/08/03. Up until this time ConocoPhillips has assumed that we had implied AOGCC consent to continue water injection in each well in its current condition. The purpose of this email is to ensure that we do indeed have consent for water injection and to notify the State that AA applications are in progress. ,~" 1A-12 - 181-178 - IAxOA communication - rnor x0 communication ~~~~~ ~~~ ~ ~ ~~0~ 3N-12 - 186-079 -Slow TXIA 3N-13 - 186-081 -Slow TxIA 1C-10 - 182-193 - IAxOA communication Wells 1A-12, 2V-02, 3N-12, and 1C-10 were added to the Monthly injector report this month. 3N-13 is already on the report. Please let me know if you have any questions or if additional reporting or action (other than the AA applications) is required. Thanks MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/13/2008 6d ~3~~ ~~~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth / ~ar~~ ~~~ dt GUU~' ~r~r NO. 4624 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk 03/12/08 • Well Job # Log Description Date BL Color CD 1 A-12 11964583 LDL tJ7:C, (- (~- 02!28/08 1 1 E-1128 SAND LATERAL 11978443 MEM INJECTION PROFILE 03/03/08 1 1R-04 11964585 USIT ~. - 03/02/08 1 2L-330 11837544 OH EDIT (SONIC SCANNER) ~}-. ~' 11/27/07 1 1 31-01 11994626 LDL 03/06/08 1 2N-327 11994628 PRODUCTION PROFILE ~~-.~ 03/08/08 1 1Y-28 11994629 PRODUCTION PROFILE 03/10/08 1 3S-08C 40016310 OH MWD EDIT VISION SERVICE e" c( 01/17/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~#~~~ F~~ 2 0 a~p8 REPORT OF SUNDRY WELL OPERATION4~aska oi4 & has C~rt~. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other n patch , Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillips Alaska, InC. Development ^ Exploratory ^ 181-178 / 3. Address: Stratigraphic ^ Service ^/ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-20688-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 100' 1A-12 8. Property Designation: 10. Field/Pool(s): ADL 25647,' ALK 465 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8865' feet true vertical 6761' feet Plugs (measured) Effective Depth measured 8375' feet Junk (measured) 8252', 8365', 8502' true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 80' 80' SURFACE 2721' 10-3/4" 2721' 2466' B-SAND LINER 3949' 7" 8852' s;~;~~~p MAR ~. 7 2008 Perforation depth: Measured depth: 7948'-8057', 8062'-8071', 8100'-8104', 8120'-8124', 8162'-8164', 8219'-8223', 8233'-8262' true vertical depth: 5937'-6031', 6036'-6043', 6069'-6072', 6086'-6089', 6123'-6124', 6173'-6176', 6185'-6210' Tubing (size, grade, and measured depth) 3.5" x 2-7/8", J-55, 8146' & 8168' MD. Packers &SSSV (type & measured depth) pkr- BAKER'FHL' ; BROWN '1 B' pkr- 7866' ; 8147' Camco TRDP-1A SSSV= 1900' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1870 -- Subsequent to operation 2016 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ ' Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG ^ GINJ ^ WINJ ~ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name GUy S Ch ~ Title Wells Group Engineer °~ '"~~ ~08 ~ ' Signature `` Phone Date C Pre ared b Sharon Allsu Dr ke 263-4612 Form 10-404 Revised 04/2006 4&~sy~i'~d~' ~~ ~`Iri~ ~ ~ ADO Submit Ori i my ?t' ~/~ • 1A-12 Well Summary • DATE Summary 1/19/08 SET LOWER PATCH UPPER ELEMENT (TTS 350 PARAGON II) AT 8115.5' WHICH PUTS THE LOWER PACKER ELEMENT (1.8" INFLATABLE PACKER) AT 8152.2', SET UPPER PATCH BOTTOM ELEMENT (TTS 350 PARAGON II) AT 7908' ((IN PROGRESS)) 1/20/08 SET UPPER PATCH ASSY OVER LEAKING INJECTION MANDREL, ELEMENT (TTS 350 PARAGON II) SET AT 7883.5', PATCHES COMPLETE, READY FOR BOTTOM ELEMENT OF LOWER PATCH TO BE PUMPED ON. LRS SHEAR PUMP OUT PLUG- PUMPING 7 BBLS DIESEL DOWN TUBING- BUILD UP PRESSURE SLOWLY AT 500 PSI INCREMENTS, SHEAR AT 3400 PSI. • • Conoctit~~tltps Alaska} tnc, 1A~12 _ _ _ APL 5002920b82300 VYell T e: INJ SSSV Type: TRDP (flapper only Orig Completion: 1/6/1982 SSSV locked out (1900-1901, Annular Fluid: Last W/O: 8/27/198 OD:3.500) Reference Lo Ref Lo Date: PBR (7852-7853, OD:3.500) PKR pass-7as7, OD:6.000) PATCH p881-7906, OD:3.500) Perf (7948-8057) Perf (8062-8071) Perf (8100-8104) Pert (8120-8124) PATCH (8113-8155, OD:3.500) PKR (8147-8148, OD:6.000) NIP (8161-8162, OD:2.875) sos (alas-e167, OD:2.875) Perf (8219-8223) Perf (82338262) DMY (8252-8253, OD:2.000) - - Shear Out _ Assy (8365-8366, OD:2.000) _ An le TS: 30 de Angle @ TD: 22 deg @ Last Tag.Date110/25/2007 I Max Hole Angle: 157 deg @ 4000 _ I I Casing String -ALL STRI NGS Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 SURFACE 10.750 0 2721 2466 45.50 K-55 PRODUCTION 7.000 0 8852 6749 26.00 K-55 Tubing Strin -TUBING Size Top Bottom ND Wl Grade Thread _ 3-500 0 21-16 _ _ 6109 9?~0 JS5 BTC-AB MOD 2.875 81-t6 212 t,128 3.50 Perforations Summary Interval TVD Zone Status Ft SPF Date T Comment 7948 - 8057 5937 - 6031 -4,C-3,C-2,C 109 4 1/6/1982 IPERF 4" Vann Guns 8062 - 8071 6036 - 6043 C-1 9 4 1/6/1982 IPERF 4"Vann Guns 8100 - 8104 6069 - 6072 UNIT B 4 4 1/6/1982 IPERF 4" Vann Guns I 8219 - 8223 I 6173 - 6176 A-5 i 1 4 1 4 1 1/6/1982 I IPERF j 4" Vann Guns I 8233 - 8262 6185 - 6210 A-4 29 4 1/6/1982 IPERF 4" Vann Guns Stimulations & Treatments _ _ Interval Date Type 21 F2 - 216-1 "21!1985 Cement SQZ ~ Comment CEMENTED S PT'd HMO psi 'Gas Sift Mandr® sNalves -- __ - ------------- St MD TVD Man Mfr Man Type V Mfr - V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 7809 5817 Otis 3.5 X 1.5 Extended DMY 1.5 RM 0.000 0 5/31/1994 PKG - - Infection MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vhr Cmnt 2 7904 5RAA C2mrtn 3.5X 1 DMV 1 n BK_ 0.000 0 9/1/2005 Other lu s e ui ., etc. -COMPLETION De h TVD T e Descri lion ID 1900 1869 SSSV Camco TRDP-1A. Locked out fla er onl 9/1/99. 2.812 7852 5854 PBR Baker PBR 2.813 7866 5866 PKR Baker'FHL' 2.992 7881 5879 PATCH LEAKING INJECTION MANDREL, ELEMENT (TTS 350 PARAGON II) SET AT 7883.5' PATCHES COMPLETE set 1/20/2008 1.630 8113 6080 PATCH SET LOWER PATCH UPPER ELEMENT (TTS 350 PARAGON II) AT 8115.5' WHICH PUTS THE LOWER PACKER ELEMENT (1.8" INFLATABLE PACKER) AT 8152.2', SET UPPER PATCH BOTTOM ELEMENT (TTS 350 PARAGON II) AT 7908' set 1/19/2008 0.875 8134 6098 NIP AVA BPL PORTED NIP 2.750 8147 6110 PKR Brown'1 B' PACKER -CALIPER 3/8/07 SHOWS APPROX 2" ID 3.250 8161 6122 NIP Camco NO GO 2.250 8166 6126 SOS Brown 2.441 8167 6127 TTL 2.441 .Fish -FISH De th Descri lion Comment 8252 DMY haH of 1" DMY la in `8252 RKB 8365 Shear Out Ass sFn2 vannr_,un ____ _ - -- _ __ G_ eneral Notes I Da-e I Note _ _ I 8/27/1985 NOTE: TIGHT SPOT IN CSG aC~ 7600'. FOUND DURING WORKOVER ~ KRU 1 A-12 Vann Gun (8502-8503, OD:2.000) MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg? ! I P.I. Supervisor ¡ I \Æ!I(! 1, "X'J(O 7 DATE: Friday, July 20,2007 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC ]A-12 KUPARUK RIV UNIT 1A-12 Src: Inspector \~\J\1~ Reviewed By: P.I. SuprvtJbP--- Comm FROM: Bob Noble Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IA-I2 API Well Number: 50-029-20688-00-00 Inspector Name: Bob Noble Insp Num: mi~CN0707I9I3I053 Permit Number: 181-178-0 Inspection Date: 7/1512007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wcll¡]A-12 I ~¡ -,------ -,.---- ¡Type Inj. I N i TVD -1- 5866 ~( IA ]50 1700 1680 1 1680 ì !TypeTest i SPT I Test psi YOA -+---- -+-~ P.T.D! ]811780 i 1700 ]35 140 140 I ]40 I ! v' Tubing 800 800 800 I 800 I Interval 4YRTST P/F P I ! - Notes: SCANNED AU G 0 6 2007 Friday, July 20, 2007 Page 1 of I 03/20/07 Schlum~erger /1.. ~J 1 l~~' NO. 4193 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: Alaska Oil & Gas Cons C'Dmm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ¡'i¡'~R ;~ (. Z007 SCANNED APR 0 3- 2007 Field: Kuparuk C)IŒ- /~/-11-0 Well Job # Color Log Description Date BL CD 1C-03 11632674 PRODUCTION PROFILE 03/03/07 1 1C-02 11632676 PRODUCTION PROFILE 03/05/07 1 1A-12 11638832 SBHP SURVEY 03/08/07 1 1 E-20 11638833 GLS 03/09/07 1 1E-168 11626470 PRODUCTION PROFILE 03/12/07 1 1E-117 11626471 INJECTION PROFILE 03/14/07 1 1Q-09 11638839 INJECTION PROFILE 03/16/07 1 3S-22 N/A INJECTION PROFILE 03/16/07 1 3M-23 11638840 LDL 03/17/07 1 1C-10 11638841 INJECTION PROFILE 03/18/07 1 2A-23 11628986 INJECTION PROFILE 03/18/07 1 1 H-21 11638842 GLS 03/19/07 1 10-42 11638843 SBHP SURVEY 03/19/07 1 2L-323 11628988 INJECTION PROFILE 03/20/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~. i6 . . I I I I I I I I I I I I I I I I I I I e /8/-/78 e Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. February 12, 2006 7048 2 3.5" 9.3 lb. J-55 BTC AB-MOD Tubing Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: 1A-12 Kuparuk Alaska 50-029-20688-00 Suñace 8,172 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: This log is tied into end of the tubing tail @ 8,167' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The caliper recordings indicate the 3.5" tubing appears to be in good condition with respect to internal corrosive damage. No significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions are recorded. The caliper recordings indicate slight buckling from 5,200' to above the upper packer (7,861 '), culminating in a mash in joint 252. This is the second time a PDS caliper has logged the bottom 15 joints of this well. A comparison between the current log and the previous log (August 6,2001) indicates no increase in corrosive damage. The current caliper log recordings indicate that the interval previously described as joint 15 (listed as erosion/corrosion with a 69% wall penetration and 49% cross-sectional wall loss) is the packer identified as joint 263.5 in this report, and does not represent damage to the tubing. MAXIMUM RECORDED WAll PENETRA nONS: No significant wall penetrations (> 18%) are recorded. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. I Field Engineer: W McCrossan Analyst: M. Lawrence VVrnness:C. Fi~patrick P.O. 80< Staffoni, T>< 77497 CFr.::< ",.-" E··" Pf)S~' ····IM·· ,»)~,"L)r:)::~ A);tdh:"',- ~l~I0'I:,I.cpm 6S9--23Ül Fax: (907) 6S~)'~14 ~I ' F'roP,ctive PI'lone: or Prudhoe Ba'ý Field Office FEB 2 4 2006 I I S R art Overview B dy Regia Analysis I lA-12 Kuparuk ConocoPhillips Alaska, Inc- US.A Survey Date: rool rype: rool Sizf': No. of Fingf'rs: Ff'bruary 12. 2006 MFC 24 No. 040665 1.69 24 Wf'II: Field: Company: Country: I I ~---- -....------------, Damage Profile ("/" wall) ~----~ Penetration ami Metal loss (% wall) I IHf'talloss body pelwtration body o o 40 to OVPl' 85új¡) ß.5(~/~ I I 20 to 40% I to 1(% ¡ to 10% 20{~~; I I Damage 30 I 20 I 10 o I Isolated gener;)1 line nng holt: / poss plttmg COITOSjÜn corrosion (CJ!TOS!On ¡¡Ae hole ClM 2 I Bottom of Survey = 263.9 2 o o I I Analysis Overview page 2 I I nwtalloss 50 100 r ~ I I I I f· I I I I I I Correlation of Recorded Damage to Borehole Profile I Well: Field: Company: Country: Survey Date: 1 A-12 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Pipe 1 Pipe 2 3.5 in (21.4' - 8132.4') 2.875 in (8132.4' - 8167.2') I I I I I I I I I I I I I ClivI 1 Inj. Mandrel I I Bottom of Survey = 263.9 I I Appro,. Fool Df'viatioll Appro,. Borf'holf' Profile l- I I I I I I 'r~1 26 I ' I I 1 1774 I I I 1555 ~ (!J ...Q E ::J Z 'J'" 263.9 o .50 Damagf' Profìlf' (% / rool Deviation (df'grf'es) 2342 3121 o ~ 3893 ...; LL C -1/:r:-'} I i.fOUj 5443 6217 6978 7743 8167 100 I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION We!!: Field: Company: Country: Survey Date: lA-12 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf )-55 BTe-AB MOD 0.254 in 0.254 in 2.992 in loint No. Jt. Depth (Ft.) .1 1 1.1 2 ') 4 5 1 1 II 21 24 28Q 111 342 374 1 5::5 5'14 '11'1(, (;17 (;48 679 .., 24 1'1' 1 Pf'1 'I (Ins.) n.01 n.Ol n n 1 0.01 OJ)] 001 0.02 0.01 0.02 om 0.02 0.02 0.03 0.02 OJJ4 0.01 0.01 0.02 0.02 0.02, . 0.02 c¡ 0.01 S 0.02 c¡ 0.03 I' U ') !i' " ;\ II '1 " ,. " I) ,I II II ·1 II ;\ iÌ II iÌ iÌ II I' II II " II " Com nìf'n ts ~';;'.r"" Profile (%wall) o 50 100 'P;-n \;1. e LII Min. , l- I () S I .1 h (, S i I) I) 11 .. 14 .. (Ins.) I I , I I · · } , · - I · _~-==~__~~_rÆ II I I II 2.92 )S PUP PUP I I I I I I III I t. I ) ) · I I , , ) : , It. tr " ,. ~I . II ~ I I I II 2.93 2.94 2.94 2.9') 2.93 2.91 29) 2.91 2.95 2.96 Sh;ìllow nilling ,~-~_."~ 1\ : I _~______^^,__^___MM___'~__ I I I I ------ --_.-------~-~~- ,-------_. -------- --,---~- ~------------- __m_m_...____ __ ---- ------------ -~---------- .____..m ~,------~ Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I Pipe: Body Wall: Upset Wall: Nominal 1.0.: 101 4<) '10 'il ')2 ~'J ~--^.--~ 54 5') 56 '17 'i8 C) (,0 6' I ( ( ( ( 6 6 6 6 6<) 70 71 "") ,--_____J.__~__.._ 73 74 I 75 PDS'EPORT JOINT TABULATION S EET Well: Field: Company: Country: Survey Date: 1A-12 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 3.5 in 9.3 ppf I-55 BTC-AB MOD 0.254 in 0.254 in 2.992 in II. Depth 1'¡'1i (Ft.) I I¡-'P ~)k,.) 15_55~..__. 1587 1617 164é\_ 1680 1711 1742 un 1805 183:5 IB66 1)7 1 )7 1 76 ~ 1 2158 2189 2221 225_'~__ 2282 2311 2342 2372 2402 ._2434 2466 24n ..,-' II 78 79 80 () 91 <)1 92 en 94 95 % <)7 'j', 741, 77R 2809 2841 2871 29QJ 2933 2965 29%. 30213 I J - , ) Peli. MeLd Min. (Ins.) Pen. Body (Ins.) 0.01 S OJ127 0.01 S 0.02 H . (L03 II 0.02 7 (I (J.OI 4 () 0.02 H (ì 1.0.0414 (i (1.02 <) II ·Ö.0312 o Il02 (ì o 0 0 o 0.0310 Ii 0.01\ II 1.02 <) (ì 1.01 4 Ii 1.02 ß o 1.01 ') II 1.02 9 Ii 0.01 3 II 0.03 11 o 0.03 10 (I 0.02 9 0.03 10 (UB II 0.01 4 0.01 (, 0.01 (, 0.01 4 0.05 IH . 0.02 9 (, 0.0'1 13 Ii 01 (, .: 02 9) 12 91 )3 10 4 )3 II) 11 S j . ()J1L --.iL_ 41 0.02 <) (!.O1 ') I 0~Ö'2 <) Ii OJ)') 9 ) 0.03 11 I 0.01 S 2 .. 0.0417 S 0.02 <) Ii -Ö.02 1)1 0.0311 I i} {} II II i) (} ¡¡ ¡¡ 'I II II "1 II II il IÌ ;1 II ii II ¡) II ~ ¡¡ Ii () il (i (I (I ¡) " I 2.9()._ 1 2.95 I,~_.,.._._---_...~_. 1 2.95____.. .__: : .. '~:Z;~'--- _.~_.~~~-~- II .: -~-- - ..~.. j 2.92 .: 2.93 SIF\lIow pittinK__ I ''2.95 ) 2.95 Ii 2.91__.~'__.~~~--~.-== I) 2.BI .?5SV ......_.____.___.~ Ii 2. 97 12 B ---..-.- Ii 2. B Ii 2 )2 I 2 )4 , ~:,'~~~- I 2*~~D54~!?~_........_.__ ) 2.93 __. ____ _. ._._ Ii 2.% 1 2.95 ) 2.94 _ _~_. .__ ..___. ) 2.91 i 2.89 Lt Df'posits. >i.97 5ballow pittinK 2.89 2.94 Shallm~ nining:. 2.9 2 ') 2 ii( It 2.1)6 2.92 .- --~----- --.- - ..-.- - ....- I t 2.95 ..-------- -----~-- --._---~ 2.94 2CJ1 2.92 2C){) 2 JI9. 2.94.. .,;2~2t 2.92.. ._.._ ... ~~~~P9sitS.. -- --~.~._--~,..~--- - --------~-~._----- _._-_._~ .._---~~ - Page 2 ..- .- ___I ""n .'g9 Profile (%wall) I) 50 100 I I I I I I I i I I I I I IIIi _..~m Body Metal Loss Body I I I I I I I I I I I I I I I I I I I PDS EPORT JOINT TABULATION S Pipe: Body Wall: Upset Wall: NominaIID.: 3.5 in 93 ppf )-55 BTC-AB MOD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 1A-12 Kuparuk ConocoPhiUìps Alaska, Ine. USA February 12, 2006 It. Depth r Pel!. (v'.e-t.d Min. -^~~ _^^__n___^___ joint Pf'IL Damage Profile No. (Ft.) Body COil HnE'lltS (%wall) (Ins.) (Ins.) 0 50 100 9)1 3059 II 0.01 j) j 2.94 ~5ballow rJiltilJg~_ . 9( 1nC)! i! OJ)l ) ) iq .....- 11 I! II 0.01 "I ) f) ~-------^ , ---- 1iS)' i! 0.03 I ^_~__MM_ ......~-_...,.~ II 1¡Fijj i! 16 j ~,~. ,.,iH;n" ~__,_w --~-~.._---- 0.04 I' 1) 1-1 i! 001 4 4 104 {)4i i! .0,01 6 J I t---l05 3274 i! 0,Q4 '7 ) 2.90 Shallow pittitW;. Lt. De[>()sits. .1 I 106 3306 i! 0.03 ¡ ) 2.88 r 'an",';tc fill! 107 ·11-{Y i! i:j ! I 2.q2 h" ow nifl;ng . I .~ i! J3 ! I ) ql ow n;H;ng . 108 I", 10C) {"1C)C) II )3 4 )94 11:1 ow nitt;ng I e..-·I! Ò 1410 i! 11 ') ! 2.92 1M,2 i! n ) --~- -. II 1 0.03 1494 i! ) )1 3 ) - - ~ 112 111 1'12(, II J )1 ! 114 {"i:;i';(~ i! )1 j ') 11 '1 :¡~ái'; i! B 0 I I 11(, 1(, 17 i! 0.03 0 ) 117 :¡(,4á i! _0.0) 9 ) I 1 If, -1 {,flO i! OJn 6 ! {) q4 119 ··1710 i! 0.03 0 ¡ 2.92 ~~~ 1)0 i74) i! ·o.Öi 9 ! .. ~- 2.94 PI i77) II 4 ! -~-~.~ CUll 2.89 12:1 1f104 0 6 ) ) <n ~...~- 0.02 IIn 'Hf)) II '(i:Ö3 ¡ ¡ ) ) q) 174 '{)1('i n 0.03 13 I 2.95 Sh¡~Jow pitting. 1>'1 II 0.01 'i ) ~ ~ I 3893 2.93 : 1>(, II 0.01 6 ) ... ---~-_._-------- 3923 -~... 2.93 127 i! 12 ! ~_M~____ -- ------ -- 1952 0.03 2.91 178 3984 n 11 2 .-.- .~.. lJ.03 291 179 II ==l~OI 6 ) I .-. 4015 I 2.94 lin 4046 II 0.02 c ) n_ __ 2.91 111 4ci 76 II )4 I ) .. 2.Q3.. 117 4108 i! II e ) 1-n 4137 i! )1 e ) I H4 4169 II B I ) 11'1 4200 i! )1 4 I I'H, 4217 i! 0.03 I) ) ---II I 1:17 47(,1 . 4 ) !{ 0.01 11B 42(H II un ____ / 0.01 29L.. lFJ ..~.4J 2 5 i! 0.01 ) 2.9J 140 435ì í! 0.01 ì 2.96 4385 i! ) ~... 141 OJ)! ,.... .. ~295 ..- 141) I) ) M~~_ ~~ 4415 0.01 2.91 II ¡ 14~ () .'i ~~\~; niHim:! ------_.~ 4445 0.04 I ~.C¡6 144 44ì8 () 0.01 4 I 2.94 14'1 4509 'j) 0.01 , ) 'i' ) 146 4539 j) 0.01 T~I¡ ) 147 '4')70 () 0.01 () ) :> Body Metal Loss Body Page 3 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: BodyWaH: Upset Wall: Nominal I.D.: 3.5 in 9.3 ppf J-55 BTC-AS MOD 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: lA-12 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Joint It. Depth I'C·¡ Pf'n. MM.d ¡'vlin. Damage Profile No. (Ft.) I Body Comments (%wall) (Ins. ) (Ins.) 0 .50 100 ¡) (, 4 -.. I 148 4602 0.01 .. 2.93 ~~- ~~-~~~- 149 4632 Iì OJ)1 å ; 2.93 .._~ ....1.5Q. ..4663 n CUB II 2.95 -~""--- .._..~ I II q I ~................- 151 4694 lJ.CP 2.~~;j - - 152 Ii 001 S I 2.94 I I -J 53 Ii 0.01 ; I 2.94 154 ~ n OO! (, ) L(º- ~ IS'1 ~ ) il om ; ) 294 ..---l2Q 8';) n 0.02 CI I .2.22 tr 157 fW! ¡) 0.02 q I 2.93 tr 9 ) ii q ; . rr 0.02 2,94 944 n 0.01 4 I 2.88 49/4 n 0.01 I h , 5005 n 0'<11 s ) 5036 il OJ)I 4 ) 2.91 5067 Iì 0.01 4 ; 2.93 509R ¡) O.()I S I 512R n 0.()2 q ;, '1160 II OM it Shallow niHing. I t. 5192 II 0.02 9 4 16R '1n4 (1 [003 1 . 2.90 ,tinh, hi irllinn ¡h9 '12'1S n 0.01 2.94 170 '1286 ¡) 0.03 I 2.90 Sh;¡lInw nitting _IZL. 5318 I) 003 i) 2.92 ~~-^-'^ ~-----,.- 172 5350 n tJ.Ol ') 2.90 --'............ n 5 -- ----- 1ì3 5381 O.Ql ) 2.91 Lt. Dtl~~sits. ,)4i2 ,...- 174 n 0.02 9 I 2.84 17'1 ')441 n C)j)2 ...JL.. .......2 2.85 "inh, h, "llinn t76 n .._0.0111 I , I 5474 2.89 - .~ 177 5504 n OJl2 i) 4 2.87 .. , .- PR 553') ¡) 0.02 (, I ) 2.88 79 5567 I) 001 4 I ; 2.B7 Slight I m 559R n 0.02 9 ; 2.() Z . .,.. 1 5629 n 0.01 ) ) \2 .'1660 n (Un In ) Lt. nµnncik 5691 n 002 g ) Slight '1721 n 001 ) I , ~-~" S7S3 II 0.02 9 ) 57¡:n ¡) 001 ) ------ I I , 2.9C I I I ¡) O{)1 4 ) ----~~- _'_"n 5814 2.90 .. I !RR 5846 n 0.02 H I 2.92 Slight n , ,. ---- lW) 5B76 n 0.01 4 ) 2.90 S907 n q ) --~-,.,. 190 0.Q2 .. 2.92 _.~,,- _..._~ 191 S91R n 0.ü2 q I 224 . -~ 192 S96R n 0.01 ; ) 2.87 -1· n ) ) ,-~ 6000 0.01 2.92 I 6031 n 0.01 ) I ffi~ Slight 6061 n 0.01 4 ) 2. 6093 n 0'<)1 ') ; 2.93 6124 n 0.02 q ) 2.92 III I Body Metal Loss Body Page 4 I I I I I I I I I I I I I I I I I I I PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf J-55 BIC-AB MOD Well: 1A-12 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. NominaIID.: 2.992 in Country: USA Survey Date: February 12, 2006 Joi JI. Depth í', liLT' \ck· L II ~~^-^" ".- ~.,"" Damage Profilf' Pen. Min. No. (Ft.) LD Comments (%wall) (Ins.) I (Ins.) 0 50 100 I ---- ~_u...~. 6155 !i O()) . å ) 2.91 II 199 6185 !i O()) H ) 2.90 200 .0217 II or)) I) I 2.93 Slight 201 624/... II o ÖI å ) it)! 202 6276 Ii OJ)] ') ) 2.94_ 203 (,'WF\ II om 11 ) 2,13lL :>nllllUW p.i1tiDK .-- -.- 204 6338 II o7i¡ ,) i 2,94 !i o]¡7 ¡ . ~- 205 6370 I 2.93 !i ¡ ¡ Slight , 206 6401 0.G1 2.90 -2(57 6430 !i 0.03 ]) ) 2.97 !i ~() ) -.-..- 208 6461 0.02 2.93 I ii om '¡ ¡ ~--- 209 6492 .L2! . (;s:);; I oiÙ ,; ) I 2.9L I 65.52 iÌ oJii ¡ ) 2.91 657ß iÌ om (, ) 2:c):f Slight I 6609 iÌ om '; ) 2.92 ()('41 iÌ om "4 ) 2.92 I 6672 ii ofj-'¡ 1J ) 2.91 Shallow pittillK_ tt I 6701 iÌ O()'; II ) M'_ ~""'~"'_._ tt 2.92 JI. Df'posits. o~iT'{ I) ) ------ , tt I 6T\'j II 2.90 ~5light Buckling. Sh¡l!lgw pitting. ~.~- )11'1 67(;7 iÌ OJ)l ') I 2.93 ---... ... ~ ~~II 219 6797 II (un 10 _ _nM."'_ ¡ 2.ß9 220 6¡:\:ì 1'1 IJ onl ') ) 2.90 6/)')1'1 II ') ) ~. 221 0.01 2.90 I 222 61'11'11'1 IJ 0.02 q 2 I 2.ßI3~ Slight II I!I I ')') 'J 6919 ii 0.02 r) ) 2.93 tt .;.......--, u 224 6947 !i 0.01 ) ; 2.ßß I ))'j 6978 !i 0.02 q ) 2.94 I!I I I I I 226 7010 I) 0.01 ; 4 I 2.90 I I I 7040 I) 001 ; ) uI90 Slight 7071 ii 0.02 t) ) 2.94 I!I ii I) i _ ~.. ~ . II 7102 (W3 2 .c)4~ 'I II Of) . ,) ) _M_'._U IIiIi 2.9L !6 q 0]) { . I) ) 2.ß9 Shallow Ditting. Lt. Deposits. IC) ii Oi11 11 ) 2.9() Slight "[t.-;:::: IIiIi ii O() q ,1 2.90 !iii !i oJ) 9 ) 2.91 _..~'"._- !iii !i O(){ In 4 2.90 Lt !iii I Ii oJ) ¿ I 2.ßß II! iÌ ~i) ; __ ___On _____u_~m__._ . ~~~~- - I 0.01 ).93 F,R TIn iÌ II ) --~" --.- ~_.-- tt 0.03 2.96 Slight Buckling. 7406 I! 0.02 q ; 2.91 !iii 743ß I! 0.03 II! , 2.94 II 746R I! q } _"_._m^_'..,"~.w._ m.___ ~1t ~ 11.º~2 2,,96.. ì49r) I! ... ()J) 2 ¿ } .. _..2,.26 Slight Bucklin..!s. !iii 75'11 I! Ii __m_~._ . .. tt 243 0.03 } 2,97. II ,1. } -~.,-- 7559 0.01 2.92 Ii ¡; ) .. ~--- ~ !iii 7591 0,01 - ').93 , Shallow Dittillg, __m._ ~L '-7(~-21 I Ii 0.t1L F ) 2.ë)4u 1 76')) IJ 0.03 Ii ) 2.93.1 ,Iioht 1=:",I,.III1\<:. I!II ..- Body Metal Loss Body Page 5 I I I I I I I I I I I I I I I I I I I RT JOINT TABULATION Pipe: Body Wall: Upset Wall: NominaILD.: 3.5 in 93 ppf )-55 STe-AB MOD 0.254 in 0,254 in 2.992 in Well: Field: Company: Country: Survey Date: 1 A-12 Kuparuk ConocoPhillips Alaska, Inc. USA February 12, 2006 Joint It. Depth Pen I Pen. Pen. )¡Ie tnl n_ ^~^^ ~ ~.,""~ ' ,_.~ Damage ProtÎIf' Min. I I I Body I LD Comrnents (% (Ins.) (Ins.) I 0 50 100 7()W:¡ I II 5 i ,~,~...."---- , II 248 ~~ . 0.0! 2.89 Lt. DeJ}o~"?,_. ---,-~~.- 249 7713 !) 0.03 10 ) "light 250 7743 0 0.02 q t t nnnn.-;"~ 251 7773 q -'oiÚ I IU 4 "light I t-I~=;;'''-;+'- 251.1 7803 !) 0 0 0 \I C¡ ,\i1 1 II "kh @-In.oi)) 252 !) ~. 16 4 ,~. , ,. tt 7819 0.04 !)( Mash. 252.1 7847 . .1) 0 I 0 0 \I SBR 252.2 0 0 -,_._-~".._.. - I 7861 0 _NlA .n PACKEI\ _, _____~......m . I 2')3 7870 0 O. ß II 4 2.91 2:: .1 7902 !) I 0 0 N A CIM :> Ini 1T':;¡;~¡;iij¡ 1): ()O\ I I 2' 4 7910 0 o. ß 12 4 It ¡'''nnc,t, tt I 2:: 1 7939 [i 0 0 0 \I CHANCE OVER .,.- --- ~- ~.~... I ---- -~ R "o;;t It. /941 0.ü1 ) ) 7961 0.02 9 ) Ii "o;;t It. 22Ji.L 0.02 ) R ;,o;;t It. 80C ) B JÒo;;t It. I .¡ I B J¡o;;t It. ~I ì 8040 !) ) R J,o;;t It ~ 101 8059 0 I R JÒo;;t It 262 8080 Ii 0.01 I ) R J,o;;t It 263 8100 0 6 i :> 97 R I"o;;t It 263.1 8119 0 ) ) 2.99 Rbo;;t It PIJP 2_IL;)· :> 8127 It 4 2.94 PUP lo;;nl"Ìf,d nittinº, I h I I 263.3 ! 8132 0 0 2.75 ...ÔY..A BPL Nil' .- ------ -- ~ 263.4 8141 0 0 2.40 A V A IPI.5It:,<:'YE' ~_.._--,-,-,.._- ~2635 8146 0 0 0 3 ')k PACKER ~ .~:J rl.i)·1_6 8155 0 0.04 Iii ) 2.39 PUP Isolated J2j.t.ti.r.1.~. IIUS .~ 263.7 8160 0 0 0 0 ì ')'" NI) CO ~.~:J ---- ---- .......... 263.8 8162 !) 0.02 IU I :> 41ì PUP 263.9 81¡~7 II 0 0 0 2.44 I UBINe rAIL .~ Body Metal Loss Body Page 6 I KRU 1A-12 I 110.....12 ---- API: 500292068800 WellT 1 Angle ía) TS: 130 deg ía) 7947 SSSV Type: TRDP (flapper only Orig 1/6/1982 i·""· @ T~122d" @ 8865 sssv ~- -_. locked olltL_ . ~f11pletion: (1900-1901. ~-~--_. 8/2'7/1985 -- -id--- -- --- Annular Fluid: Last W/O: Rev Reason: TAG, set DMY, 00:3.500) SLEEVE 1 Reference L?g: 8389 -.-. ""..~---~.- ~-----'3"fL.?9 Date:J~____¡_ .. Last Update: 110/17/2005 ...~ '=.'=-~ Last T-"g~ TO: 18865 ftKB I ..- LastTao Date: 9/1/2005 .--- -'MaxHole~57 deo@4000 r---- T Strinå....A.LL;:)Ki N\.:i T ,m Bottom T D lira Ie Thread ìllfY 1 ,0 } 80 6! 0 ;-, } .-- 1 0 2721 2 ;6 4! <-! SBR ---- IN 8852 6 f9 21 <-! 17"""_70'" ~35ÒOj H.lDlf lna- 'USING Size [ TaD I Bottom I TVD I Wt 1 Grade ì Thread .500 1 0 I 8146 [ 6109 [ 9.30 [ J-55 ì BTC-AB MOD PKR~-- ".- .875 1 8146 [ 8168 1 6128 1 6.50 1 ì I (7866-7867. I -- =K~ I 00:6.000) rVI one I Intel"' :i Status Ft SPF Data 7948 - · 109 4 1/6/1982 I 4" 8062 - · 9 1/6/1982 IPERF 4" - - UI B 4 1/6/1982 IPERF 4" , · UI B 4 1/6/1982 JE'.EBF 4" '- - lJi B 2 8/21/1985 - - 4 1/6/1982 IPERF 4" Perf 8233 - 8262 - 29 1/6/1982 IPERF 4" Vann Guns (7948-!3057) ~8{ê ervæ Date TVDe Perf -8' 64 8/21/1985 (8062-8071 ) ¡Ga Perf St ill: TVD Man Man Type VMfr V Type VOD latch POrt IRO ~~~ Vlv (8100-8104) Mfr Cmnt 1 7809 5817 Otis 3.5X1:5 DMY 1.5 RM 0:000 0 1")"'1"""" , , Perf PKG (8120-8124) St MO TVD I Man Man Type VMfr V Type V OD latch Port TRO ~~~ C~~I TUBING--'d I Mfr (0-8146. r-y 7904 Cameo :3'.5 X 1 I DMY [ 1.0 [ BK 0.000 I 0 9/1/2005 00:3.500. ¡Other :"'.....¡... '",+ :.. """ ¡gv 10:2.992) ~h TVO Iype 1900 1869 SSSV :amco TRnp,1 /} 1 Ark,,'; onlv) 9/1/99 7852 5854 SBR :aker PKR-- --~- 7866 5866 PKR .er (8147-8148. 8134 6098 QII=I=\/'::_ VV £ AVA II""" 00:6.000) I 8134 6098 AVAB ~UK :U NIP I 8147 0 R Drown NIP --- 51 2 lCamco )GO 2.250 56 6 S . Brown 2.441 I rl 37 2.441 Fi~ ,-- DeDth sos- ---- 8252 [DMY [half of 1" I ía) -8252 RKB (8'166-8167. 8365 [Shear Out Assv 00:2.875) 8502 Vann Gun ___n Note Perf --- ,-- Data (8219-8223) M 8/22/1997 : (a) 7904' - 9/4/2002 ¡¡UN Perf - 2/24/200 ' WELL _ '^ " r ¡¡UN (8233-8262) -- e . lid -- : -- i- ....... _m DMY-- - fl -'" (8252-8253, OD:2.000) ......... -- M :_m_ , ShearOut~-> Im~ I Assy (8365-8366, 00:2.000) Vann Gun -~,. '"OM ""^O 002000) I I I I I I I I I I I I I I I I I Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Desc.: Pipe Use: PHILLIPS ALASKA August 6, 2001 4392 1 3.5" 9.3 lb J-55 AB-Mod Tubing Well: 1A-12 Field: Kuparuk River Unit State: Alaska APl No.: 50-029-20688-00 Top Log Intvl: 7,754 Ft. (MD) Bot. Log Intvl: 8,156 Ft. (MD) Inspection Type: Pre-Tubing Patch Assessment COMMENTS: This log was run to assess the condition of the tubing in the area of the bottom packer for setting a tubing patch. The caliper recordings indicate that the blast joints and tubing above the lower packer are in good condition. The only significant damage recorded over this interval is some isolated pitting in the joint above the top GLM that measures 0.08", or 33% wall penetration. There appears to be a 2 7/8" pup joint immediately below the bottom packer, and then what appears to be severely eroded/corroded 3.5" tubing. The bottom of the log interval is 5 ft. below the top of this joint that appears to be damaged 3.5" tubing. Complete circumferencial wall loss to a typical ID of 3.2 inches is indicated in this joint, with a maximum recorded wall penetration of 0.17", or 69%, and maximum cross- sectional wall loss of 49%. There is also a restriction of 2.09" ID indicated within the lower packer. A 3D Caliper log plot of the interval 8,114' - 8,156' is included in this report, as well as cross-sectional drawings of the damaged joint below the lower packer, and the restriction recorded within the packer. MAXIMUM RECORDED WALL PENETRATIONS: Erosion/Corrosion (69%) Jt. 15 @ 8t54' MD Isolated Pitting (33%) Jt. 2 @ 7784' MD Isolated Pitting (20%) Jt. I @ 7759' MD Line of Corrosion (20%) Jt. 4 @ 7898' MD MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: Erosion/Corrosion (49%) Jt. 15 @ 8154' MD No other areas of significant Metal Loss are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS: Packer Damage 2.09" Min. ID Jt. 14.5 (packer) @ 8147' J Field Engineer' D. Cain Analyst: J. Burton Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford~ TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 8155 Well i A / 2 PDS Caliper Overview Body Region Analysis Dam;age Co*~figuvation { betty ) Damage Profile / '!777 PDS C~iPEI?. IOINT TABLILATION SI i~ inche~ in(h~ ;~ i~ inches linches ind~e~, PDS Caliper Secdons C~oss section for joint I5 atdepth 8153.'~{ ft PDS Caliper Sections Cross section for Joint 2 at depth 7783,7 ft [fit i).()8 in = ~ ~';, \\',/Ii Pr netrati!)n lA 12 PDS Caliper Sections pDS CALIPER .JOINT TALLY SHEET Pipe: 3.5 ins 9.3 ppi J-55 AB Mod Wall thickness. Body: 0.254ins Upset = 0.254ins Nominal ID: 2.992 ins Joint Depth Length Measured Type No. ID feet feet inches 1 7753.92 21.36 nominal 2 7775.28 30.53 2.980 2.1 7805.81 12.40 nominal GLM 1 3 7818.21 31.31 3.020 3.1 7849.52 1.95 nominal X-Orr , 3.2 7851.47 '12.83 nominal SBR 3.3 7864.30 8.20 nominal PKR 4 /8/,..50 31.18 2.961 4.1 7903.68 6.3 7 nominal GLM2 5 7910.05 31.11 2.966 5.1 7941.16 2.00 nominal X-Ovr 6 7943.16 20.45 3.000 7 7963.61 19.39 3.001 8 7983.00 19.95 2.991 9 8002.95 19.74 2.996 10 8022.69 ! 9.75 2.998 11 8042.44 19.93 2.994 12 8062.37 19.96 2.996 13 8082.33 19.90 3.000 , , 14 8102.23 19.54 ~3.002 14.1 8121.77 8.33 3.020 Pup 14.2 8130.10 3.73 nominal Pup 14.3 8133.83 2.92 nominal AVA 14.4 ~ 8'I 36.75 9,47 2.985 Pup 14.5 [ 8146.22 1.92 nominal PKR 14~6 8148.14 3.46 nominal Pup 15 8151.60 unknown nominal , -- Well: 1A-12 Field: Kuparuk River Unit Company: PHILLIPS ALASKA CountB,: USA Date: August 6, 2001 Joint Depth Length No. feet feet ~ inches -- .. , , -- . -- .... -- .... -- Joint Tally page 1 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI S 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate __ Plugging Perforate _ Repair well Pull tubing Other X 2. Name of Operator ARCO Alaska. Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 929' FSL, 491' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1380' FSL, 1799' FWL, Sec. 7, T11N, R10E, UM At effective depth 1420' FSL, 1550' FWL, Sec.7, T11N, R10E, UM At total depth 1522' FSL~ 1423' FWL, Sec. 7~ T11N, 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length R10E, UM 5. Type of Well: Development Exploratory Stratigraphic Service 80' 2721' 8865' feet Plugs (measured) 6 75 9' feet None 8762' feet Junk (measured) 6 6 6 3' feet None Size Cemented 1 6" 10 3/4" 8852' 7" measured 7948'-8057', 8062'-8071' 8219'-8223', 8233'-8262' true vertical 5838'-5930', 5934'~5941', 6072'-6075', 6082-6112' Tubing (size, grade, and measured depth 3 1/2" J-55 set at 8168' 6. Datum elevation (DF or KB) 100' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 1A-12 9. Permit number/Approval number 9-788 10. APl number so-029-20688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 200 Sx Perma 8 0' 8 0' 1130 Sx Class G 2721' 2465' & 250 Sx AS II 740 Sx Class "G" 8852' 6750' 570 Sx Class G , 8100'-8104', 8120'-8124', MD 5968'-5972', 5985'-5990', TVD Packers and SSSV (type and measured depth) Baker FHL @ 7866' & Brown lB @ 8147', Camco TRDP-1A @ 1900' Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Convert from water inj,ector to WAG injector. 14. Prior to well operation (injecting) Subsequent to operation (injecting) 15. Attachments 16. Copies of Logs and Surveys run ,Daily Report of Well Operations X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~~ ~ ~~-~? TitleSenJor Operations Engineer Form ~0-404 ~ev 0~/17/89 Reoresentative Daily Average Production or In!ection Darn OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure - 0 - 0 - 7000 400 - 0 - 5600 0 - 0 - Tubing Pressure 2300 39O0 Status of well classification as: Water Injector__ WAG Injector X Oil m Gas Suspended Service Date ~"/'~/~,, ,, SUBMIT IN DUPLICATE KD~. Mt ~ING WELL REPCRT FOR 1 _'1 3 ORILLSITE lA W Z S E 0 T L N A L E T 1 B PR 2 A PR t B TS 4 B ~R 5 B PR 6 A PR 8 B PR 1~. B PR TOTALS: W Z S E 0 T L N A L E 'T 7 'B SW q B SW 11 B PW 12 A SI 13 4 SI 14 B PW 15 B ,,SI 16 B PW TOTALS: PRODUCTION WELL STATUS G4S LIKT ST4TUS ~ 7" 13" .~ :': .* ... TP TT WC H2S CSG CSG PSI CHK DEG % PPM PSI PSI 175 176 102 89 1050 13~0 610 6~ 180 17~ ~O 1 36 1220 ~20 66 130 176 105 51 87 1310 7qO 67 1~0 176 32 6 25 875 520 64 190 176 132 81 183 1410 500 4~ 130 176 72 1 28 1200 72~ 55 200 176 112 ~8 25 1050 610 72 180 176 lO~ 66 ~3 1210 5~0 52 GAS TEMP METER RATE DEG READING M$CF A. Og7 11.02 5997 '~79 q. 097 599 5997 121 97 0 2297 5lq. 6997 1.331 5097 1~3 INJECTION WELL STATUS INdECTIOE RATE 4LLOW 4CT 7" 10" INJ INJ TT CSG CSG PSI PSI DEG CHK PSI PSI 2500 1500 162 12 1259 100 2500 2~50 105 66 910 ~90 INJ INd METER RATE RATE READING BPO ~MSCFD 875¢413 3431 0.003 5527390 3060 0,003 2500 2350'14~ 66 2~50 1120. 35¢3994 3483 0,000 ~000 3000 82 20 0 20 4300 3~00 87 20 0 O 2sO0 2350 12 176 550 ~900 2q53 82 40 1020 2530 2320 168 ~7 1100 1260 SWI: 64gl + OWl: 12026 : 3 9 1,032 O O 5,775 ~070~10 2794 0,000 9. 0 5,782 2696058 5759 0,000 1~517 12,559 S/I !MP~CT C H M 0 R I D EPL S N E BBL$ ~m, ,mm ,mm ~m, ,mm, ~m O00O 0 0 0000 0 0 OOO0 0 0 0900 O 0 0000 0 0 0000 g 0 · 2000 0 0 OOOO 0 0 0 S/I C HM 0 ,. mi D S~ 0100 61 3000 0 0003 0 0245 51 3000 0 3090 0 O000 0 0000 O W Z S E 0 T L N A L E T 1 B PR 2 A PR $ B PR eB PR 5 8 PR 6APR 8 B PR 108 TS TOTALS: W Z S E 0 T L N A L E T 7 B SW 9 B SW 11 B PM 12 A PW 15 A G! 14 B PW 15 B GI 16 B PV TOTALS: DR ILLS PROOUCTION WELL STATUS GAS LIFT STATUS 7" 10" TP TT WC H2S CSG CSG PSI CHK DEG % PPP PSI PSI .. 175 176 102 89 1050 1340 610 64 180 176 40 I 36 1220 440 66 130 176 108 51 87 1310 720 67 1~0 176 32 6 25 875 520 64 190 176 132 81 183 1410 600 4~ 130 176 72 1 28 1190 725 65 200 176 112 48 25 1050 510 72 190 176 10~ 6~ 43 1210 540 54 GAS INd TEMP METER R.ATE DEG READING MSCF mmmm mmmmmmm mmmm 4297 1157 E997 879 4097 599 5097 321 97 0 2297 614 7097 1031 5097 1443 m~ 6044 INJECTION YELL STATUS mmmmmmmmmm m m mmmmmmmmmmmmmm INdECTION RATE mmmm mm mm mm m m m mmmmmmm ALLOW ACT 7# 10" INJ INd TT CSG CSG PSI PSI DEG CHK PSI PSI mmmmm mmmmm mmm mmm mmmm mmmm 2500 2225 106 55 2400 100 2500 ' 2~50 105 66 800 490 2500 2300 14~ 66 2350 1080 2500 2275 136 100 480 520 4000 3400 87 20 0 0 2500 2325 152 176 500 300 4000 295.0 82 40 1020 540 2500 2250 163 55 1180 1200 SWI: 87q5 + PWI: 20988 : INJ INJ METER RATE RATE READING BPD ~MSCFD mmmmmmm mmmmm mmmmmm 8750008 5675 0.000 5524347 3070 O.O00 3540591 3416 0.000 5063279 7270 0.000 0 0 5°743 4067207 3~21 0.000 0 0 ~.756 2690273 6881 0.000 29733 11°499 S/I IMPACT m ~mmm m mm m m m m ,mmm m mm m C H M 0 R I O ~PL S N E BBLS il,.m ill ,m.m 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 0000 0 0 O00C 0 0 0000 0 0 0 S/I ~ mm ,~mm em ~m C H ~ 0 R I O S N ~,m~ ~ ~m,~ OCO0 0 O00O 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 ( .... STATE OF ALASKA Al.J, .A OIL AND GAS CONSERVATION COMJi' .,.)N N APPLICATION FOR SUNDRY AppROVALS Operation Shutdown _ Re-enter suspended well_ Time extension Stimulate Variance Perforate Other 6. Datum elevation (DF or KB) RKB 100 7. Unit or Property name feet 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well _ Plugging _ Change approved program X Pull tubing _ 2. Name of Operator ~ 5. Type of Well' I Development _ ARCO Alaska. Inc. Exploratory _ 3. Address I Stratigraphic _ P. O. Box 100360, Anchorage, AK 99510I Service 4. Location of well at surface 929' FSL, 491' FWL, Sec. 5, T11N, R10E, UM At top of productive interval 1380' FSL, 1799' FWL, Sec. 7, T11N, R10E, UM At effective depth 1420' FSL, 1550' FWL, Sec.7, T11N, R10E, UM At total depth 1522' FSL, .1423' FWL~ Sec. 7~ T11Nr R10E~ UM 12. Present well condition summary Total Depth: measured . feet true vertical feet Effective depth: measured feet true vertical feet Kuparuk River, Unit 8. Well number 1A-12 J/V ~i;-c is/z 9. Permit number 81-178 10. APl number 50-029-20688 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 8 8 6 5' Plugs (measured) 6759' 8 7 6 2' Junk (measured) 6 6 6 3' None Size Cemented Measured depth True vertical depth I 6" 200 Sx Perma 8 0' 8 0' 10 3/4" 1130 Sx Class G 2721' 2465' & 250 Sx AS !1 7" 740 Sx Class "G" 8852' 6750' 570 Sx Class G 8062'-8071', 8100'-8104', 8233'-8262' 5934'-5941' 5968'-5972', 6082'-6112~ Casing Length Structural Conductor 8 0' Surface 2 7 21' Intermediate Production 8 85 2' Liner Perforation depth: measured 7948'-8057', 8219'-8223', true vertical 5838'-5930', 6072'-6075', 8120'-8124', 5985'-5990', SE? o ? :1989 A/aska.0ii .& Gas Cons. C0m~ _ Detailed operation program _X_ BOP ~,,,t~n _ Tubing (size, grade, and measured depth 3 1/2" J-55 set at 8168' Packers and SSSV (type and measured depth) Baker FHL @ 7866' & Brown lB @ 8147', Camco TRDP-1A @ 1900' 13. Attachments Description summary of proposal Water injector to WAG injector 14. Estimated date for commencing operation October. 1989 16. If proposal was verbally approved Date approved 1,5. Status of well classification as: Oil __ Gas _ Suspended Service Water In!ector Name of approver 17. I hereby certify that the foregoing is true and correct t~he best of my knowledge. " ~' ' FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require 10-.~ ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy. Returned SUBMIT IN TRIPLICATE , Approved by the order of the Commission Form 10-403 Rev 5/03/89 Procedure 1A-12: A Only SPFO/SRT. A Only Gas Injection 1. Pull ported AVA at 8133' RKB. 2. Run AVA blanking sleeve. 3. Allow well to stabilize at maximum water injection rate. 4. Operations Engineering to pedorm SPFO. 5. Operations Engineering to perform SRT after well has stabilized. 6. Convert well to A Sand only gas injection for 10 weeks. NC Gas In!ection. A/C Water In!ection 1. Fill wellbore with liquid to avoid being blown uphole. 2. Pull AVA blanking sleeve at 8133' RKB. 3. Run ported AVA with 2 ea 30/64" ports. (port size may change based on SPFO/SRT results from above) 4. Begin A/C gas injection. 5. Operation Engineering will communicate when to switch well to A/C water injection, based on gas injection rates. Hill · Il I I Il Il I I Illll I Ill I II 4 3 1. 5000 PSI 7" WELLHEAD CONNECTOR FLANGE 2. 5000 PSI WlRELIN£ RAMS (VARIABLE SIZE) 5. 5000 PSI 4 1/6" LUBRICATOR 4. 5000 PSI 4. 1/6" FLOW TUBE PACK-OFF 2 S E.P o 7 ~§8~ Alaska 0il & t~as Cons. CommJssioD Anchorage H I REL I NE BOP EiDU I PMEN? ii I i ARCO Alaska, inc. B(C (~ Post Office ~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 13, 1987 Mr. C.V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1A-12 Dear Mr. Chatterton' Enclosed is a copy of the 1A-12 Workover Well History to include with the Well Completion Report, dated 2-12-86. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer JG:db GRU1/50 Enclosure xc: 1A-12 Well File RECEIVED JAN 2 0 Alaska Oil & Gas Cons, Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichtieldCompany ARCO Oil and Gas Company Well History- Initial Report - Daily Inetructiona: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District Alaska Field Kuparuk River Au~. or W.O. no. A~E 603104 I~unW, ~dsh or ~rough North Slope Borough Lea~ or Unit ADL 25647 Title Recompletion State Alaska Well no. iA-I2 W/O WWS 1 AP1 50-029-20688 O~mtor ARCo Alaska, Inc. Spudded or W.O. begun Workover ID=, 8/16/85 [Hour Date and depth as of 8:00 a.m. 8/16/85 8/17/85 8/19/85 8/20/85 8/21/85 Complete record for each day reported 8761' PBTD,. Moving rig f/lA-9 to lA-12. 0730 hrs. ARCO W.I. Prior status if a W.O. 7" @ 8852' 8761' PBTD, RIH to Perf f/squeeze Move to lA-12. Accepted tis @ 0730 hfs, 8/16/85. Pull BPV. Pull dummy vlv @ 7762'. Bullhead 70 bbls of 9.9. ppg brine. Well tak'g fluid. Cut wt to 9.1 ppg. Displ well to brine. Mix & pmp Lite Sal pill. Set BPV, ND tree, NU BOPE, cst BOPE. PU tbg, shear SBR, POOH. PU 3½" DP & fishing assembly& RIH. Latch onto SBR w/overshot, rotate out, POOH. LD SBR, w/mill. Mill packer. Circ, POOH w/pkr. RIH w/sqz guns. 7" @ 8852' 8761' PBTD, RIH w/Stinger on DP 9.1NaC1 RIH w/4" OD & 2' long cs$ gun. Would not go past 8153' PuN biC & scrpr. Tag btm @ 8272'. Wsh & ream to'8281'. penetration w/10,000 lb bit wi, POOH. RIH & perf f/8162'-8164'. Rn Baker BP & sec @ 8175'. Rn Baker cmt retainer & set @ 8140'. RIH w/stinger on DP. , POOH. No 56.24% 8/22/85 8/23/85 7" @ 8852' 8761' PBTD, RIH w/Stinger on DP 9.1NaC1 Sting into cmt reit. Pmp 100 sx of cmt. POOH, RIH w/bridge plug. Set @ 7825'. ND BOPE, NU tbg head & BOPE, cst. RIH retrieve BP. RECEIVED 7" @ 8852' 8761' PBTD, RIH R-3 packer RIH tag cmt @ 8129' drl cmt JAN2 0 POOH, LD DC & JB, PU R-3 pkr, TIE. Alaska OiJ a Gas Cons. CommJssi Anchorage 9.1NaC1/NaBr POOH w/BP, PU bit, & JB. retainer, cmt to 8167'. 7" @ 8852' 8761' PBTD, POOH, LDDP 9.1+ NaCl/NaBr RIH w/R-3 pkr, set pkr, cst sqz perfs to 2000#; OK. POOH, rn bit & DC's. Drl BP @ 8167', psh to btm, attempt to drl junk @ 8,281'; no success POOH. Rn csg scrprs to 8262'. CBU. POOH, LDDP. The above is correct Signature For form preparation and ~lstributlon~ see Procedures Manual, Section 10. Drilling, Pages 86 and 87. Date I Title_ Drilling Superintendent ARCO Oil and Gas Company Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish Alaska I North Slope Borough Field ILease or Unit Kuparuk River I ADL 25647 Date and deptrt Complete record for each day while drilling or workover in progress as of 8:00 a.m. 8/24/85 thru 8/2~6/85 8/27/85 IState Alaska IWell no. lA-12 W/O RECEIVED JAN 2 0 Alaska Oil & Gas Cons, Commission Anchora~ 7" @ 8852' 8761' PBTD, POOH, prepare to pull tubing 9.1NaC1/NaBr RU WL, RIH w/GR & JB to 8259'. POOH, tight spot @ 7602'. PU DP & ream f/7548'-8238'. Mill f/8238'-8287', POOH. RIH w/perm pkr & tail pipe assy, Set @ 8147'. RIH w/c0mPl string, set retv pkr, shear pkr, land tbg. Tst pkr, observe retrns to annl. Pkr not holding, prepare to pull tbg. 7" @ 8852' 8761' PBTD, Set Standing Vlv 9.1 Brine POOH w/tbg, chg out Baker pkr. RIH w/compl string, set pkr @ 7866', shear PBR, RU WL, RIH w/standing vlv. The above is correct For form preparation and distribution see Procedures Manual Section 10' Drilling, Pages 86 and 87 IDate ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Weli History- Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ~County or Parish Alaska I North Slope Borough Field [Lease or Unit Kuparuk River I ADL 25647 Auth. or W.O. no. [ Title AFE 603104 I . Recompletion WWS API 50-029-20688 IAccounting cost center code State Alaska no. 1A-12 W/O Operator I A.R.Co. W.I. ARCO Alaska, Inc. 56.24% Spudded or W.O. begun Date Workover Date and depth Complete record for each day reported as of 8:00 a.m. 8/28/85 I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prtor status if a W.O. Old TD New TD Released rig Date 1500 hrs. Classifications (oil, gas, etc.) Oil FloWing. Producing method ,-, 7" @ 8852' 8761' PBTD, RR 9.1NaCl/NaBr Tst SSSV, set BPV, ND BOPE, NU tree & tst. Displ well to diesel. RR @ 1500 hrs, 8-27-85. RECEIVED JAN 2 0 i~g7 Alaska Oil & Gas Cons. Commissio~ Anchorage I PB Depth 8/27/85 IKind of rig Type completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 8761' PBTD Rotary Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is Correct see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent r May , 1986 Page 2 rton (' ([7 I?.Av o 1986 KUPARUK RIVER UNIT INJECTION LOGS . . ~.~:~.~r, ~INITIAL INJECTION Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 3/1/83 3/6/83 lA- 13 2/4/83 10/17/83 lA- 14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 Well Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 1E-23 1E-27 1E-30 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Well Number Date of Initial Injection Date of InjeCtion Profile 1F- 10 8/13/84 10/30/84 1F-11 8/12/84 9/24/84 1F-13 8/16/84 9/25/84 1F- 15 8/16/84 9/26/84 -Well Number Date of Initial Injection Date of Injec. tion Profile 16-3 16-6 16-9 16-14 16-16 -,. 10/25/85 ' 12/20/85' 7/28/84 9/23/84 9/15/84 9/23/84 8/24/84 9/22/84 8/24/84 9/22/84 ATTACHMENT I I Drill Site lA Well No. 1A-4 1A-5 1A-7 1A-9 1A-11 1A-14 1A-15 1A-16A KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Log Date 7/6/83 10/29/83 2~8/82 5/7~82 1/25/82 3/23/83 1/19/83 3/21/83 3/8/82 4/1/82 6/5/82 5/11/.82 6/8/82 Drill Site Well No. Log Date 18 18-1 12/26/81 18-2 6/25/81 18-3 11/16-18/81 3112/82 18-6 11/18/81 9/10/82 18-7 11/23/81 18-8 12/28/81 8/4/82 18-9 6/24/82 8/3/84 Drill Site Well No. 1C-1 1C-2 '1C-3 1C-4 1C-5 1C-6 lC-7 1C-8' Lo9 Date 5/9/81 5/8/81 7/13/81 11/8/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 10 10-1 · 1/80 5/23/83 10-3 8/5/80 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 ~_..~D-8 (WS-8) 5/i0/78 Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ~IQ~ 12/1785 Drill Site Well No. 1E 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Lo9 Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/8! 11/12/82 10/28/81. 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Log Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. Log Date 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 1F-2 1F-3 1F-4 1F-5 1F-6 3/!2/83 I D . Alaska Oil & Gas 1F-7 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 10/28/82 11/19/82 5/7/83 Attachment Page 3'' Drill Site Well No. Log Date 1Y 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 ~6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~IY~-.'1~. 5110183 ~... 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 5/ 3/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 I2~15~12ttlt85. - Drill Site Well No. Lo9 Date 2Z ' ' ~ 7/10/83 2Z-2 '" 6/24/83 7119/83 2Z-3 ' '8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 VLF: pg: 0052 Anchorag~ Drill Site lA Well No. "1A-4 ~1A-5 X~lA.7 ~1A-9 "1A-11 '~1A-12 X~lA- 14 "~ 1A-15 X,,lA-16A ATTACHMENT I I KUPARUK RIVER UNIT Production., Logs Log Date 7/6/83 10/29/83 2/8/82~x, 517182/ 1/25/82~ 3/23/83 ,/'~ 1/19/83"~ 3121183/ 318182 4/1/82 6/5/82 5/11/822~ x~ 6/8/8 Drill Site Well No. Log Date 18 ~18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81"-7~ '~ 3/12/82/ "18-6 11/18/81X, ~-, 9/10/82,,' -~ ... ~18-7 11/23/81 ~18-8 12/28/81'-,> '~ 814182/ ~IB-g 6/24/82 ~ x,% 8/3/84 Drill Site 1C Well No. \ ~'~1C-1 '"~1C-2 "1C-3 ~1C-4 NolC-5 '""1C-6 'X~lC_7 'x. 1C-8 Log-Date 5/9/81 5/8/81 7/13/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date ,, _ 1D "X~lD-1 1/80'> ~ ~- 5/23/83/ t'""'" "~lD-3 8/5/80 1D-4 x7/30/80~ ~ ~ 8/13/80/ ~ ~ '~lD-5 6/11/81 ~1D-6 6/9/81 '~1D-7 6/8/81 X~ID-8 (WS-8) 5110178 RECEIVED FEB ~ ! 1981~ Anchorage ARCO la Inc. ( Office Bo .,,0360 ~orage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Well Completion Reports Dear Mr. Chatterton' Enclosed are Well Completion Reports for the following wells: 1A-9 1A-12 Kavik #1 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L118 Enclosures ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA IL AND GAS CONSERVATION C MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [~X WATER INJECTOR 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-178 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20688 4. Location of well at surface 9. Unit or Lease Name 929' FSL, 491' FWL, Sec. 5, T11N, R10E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1380'FSL, 1799'FWL, Sec. 7, T11N, R10E, UM 1A-12 At Total Depth 11. Field and Pool 1522'FSL, 1423'FWL, Sec. 7, TllN, R10E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 100' RKB ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1 2/22/81 01/1/82 01/6/82*I N/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafrost 8865'MD, 6759'TVD 8762'MD, 6663'TVD YES~[~ NO [] 1900 feet MD 1700' (approx) 22. Type Electric or Other Logs Run D IL/SP/GR SFL/FDC/CNL/Cal CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD I SETTING DEPTH MD CASINGSIZE~WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# H-40 Surf 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surf 2721' 13-1/2" 1130 sx Class G and 250 sx AS II 7" 26# K-55 .Sur. f 8852' 8-3/4" 740 sx Class "G" and 570 sx Class G 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) 7948-8057 ' 8062-8071' 3 1/2 8168' 8147' 8100-8104' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 8120-8124' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 8219-8223' 8162'-8164' 100 SX Class G 8233-8262 ' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 2/28/82 F1 owing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 3/10/82 13.2 TEST PERIOD ~ 2373 1 239 -- 96/64" 522 ,,. Flow Tubing Casing Pressure CALCULATED.I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press1.90 -- 24-HOUR RATE I1~ 4735 2472 -- 26.1 o 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 * NOTE: Wel 1 was recompleted 8/27/85. GRU13/WC05 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. GEOLOGIC MARKERS NAME Top Kuparuk River Form. Base Kuparuk River Form l 31. LIST OF ATTACHMENTS NONE MEAS. DEPTH 7945' 8326' TRUE VERT. DEPTH 5933' 6266' 30. FORMATION Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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 ~SParately 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 ARCO Alaska, Inc. [ Post Office B~ J0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 7, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached in duplicate are subsequent notices following wells at the Kuparuk River Field: Well Action Date Performed 1A-9 Fracture 1 0/1 7/85 1A-1 2 Fracture 1 0/1 4/85 1R-1 5 Fracture 1 0/23/85 1R-1 6 Fracture 1 0/23/85 on the If you have any questions, please T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me at 263-4212. ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichfieldCompany ( .... STATE OF ALASKAO ALASKA OIL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Uam~'°'t'Qpe~'a't°~' SKA/~I%I~,U/~L~ ! I~.l.C 7. Permit No. · -. · 81-178 3. Address 8. APl Number P. O. BOX 100:360, ANCHORAGE, ALASKA 99510 so- 029-20688 4. Location of Well SURFACE LOCATION. 929' FSL, 491' ~IL, T11N, R10E, UM Sec. 5 5. Elevation in feet (indicate KB, DF, etc.) 1 00' (RKB) 6. Lease Designation and Serial No. ADL25647 ALK 465 9. Unit or Lease Name KUPARUK RIVER UNIT 10. Well Number 1A-12 11. Field and Pool KUPARUK RIVER F I ELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On October 14, 1985, the "A" sands of Kuparuk well 1A-12 were hydraulically fractured and propped to improve production. The treatment consisted of 206 BBLS of gelled diesel as pad and carrying fluid and 1,008 LBS of 100 mesh and 11,592 lbs. of 20/40 sand as proppant. 71BBLS of gelled diesel was used as a flush. Prior to pumping, equipment and lines we're tested to 6400 psi. A~x'~ ~ I.. ' Alaska 0il & Gas C.,.'~;~s. C0mmJssJ0~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use Title KtJPARUK ' OPERAT i ON$ - COORD ! NATOR Date 11 / 6 / 85 Conditions of Approval, if any: Approved by Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. [ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 24, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton' Enclosed are 1A-12 1A-9 Subsequent Sundry Reports for If you have any questions, please call me at Sincerely, Gruber Associate Engineer JG/tw GRU12/L35 Enclosures the following wells' 263-4944. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~X OTHER 2. Name of Operator 3. Address p: n: Rn; !00360~ Anchorage, AK 99510-0360 4. Location of Well Surface: 929' FSL, ~+91' FWL, Sec.5, T11N, R10E, UH 5. Elevation in feet (indicate KB, DF, etc.) RKB 100' I 6. Lease Designation and Serial No. ADL 256~7 ALK ~65 7. Permit No. -"!-!78 8. APl Number 50- 02~_,~n,.oo 9. Unit or L~as~"l~'~'n~e Kuparuk River Unit 10. Well Number 1A-12 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or COmpleted Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 0730 hfs, 8-16-85. Killed well. ND tree. NU BOPE & tstd to 3000 psi-ok. Pulled tbg hanger & tbg. Retrieved pkr. Perf'd 8162'-816~~ w/Z~ spf. Pumped & squeezed 100 sx Class G. Tstd squeezed perf~s to 2000 psi-ok. Ran pkr & set ~ 81~7~ WLN. Ran completion assembl,v, Set pkr ~ 7866'. Tstd tubing to 2500 psi-ok. Set BPV. ND BOPE. NU tree & tstd to 5000 psi-ok. Disp well w/diesel. Secured well & released rig (~ 1500 hfs, 8-27-85. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space b~ow for Commission use Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10~,03 Rev. 7-1-80 GRU12/SN06 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office BoX 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 16, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1A-12 Dear Mr. Chatterton: Enclosed is the Well Completion Report for 1A-12. I have not yet received a copy of the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, J. Gruber Associate Engineer J G/tw GRU11/L135 Enclosure RECEIVED 0CT21 Alaska 0il & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ~. AND GAS CONSERVATION CO("" .~IISSION 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. 81-178 . 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-20688 4.' Location of well at surface 9. Unit or Lease Name 9297 FSL,-~,91' Ft~L, Sec. 5, T11N, R10E, UN Kuparuk River Un~l; At Top Producing Interval 10. Well Number 1380'FSL, 1799'F~/L, Sec. 7, T11N, R10E, UN 1A-12 At Total Depth 11. Field and Pool 1522'FSL, 1/+23'.FWL, Sec. 7, T11N, R10E, UN Kuparuk River Field , 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0i l Poe] 100~ RKB ADL 256~7 ALK /+65 i"~. Date Spudded 13. DateT.D. Reached 14. Date Comp., Susp. orAband. '15. Water Depth, ifoffshore ,16. No..ofCompletions 12/22/81 01/1/82 01/6/82*I IN/A feet MSL 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 8865'ND, 6759~TVD 8762~HD, 6663'TVD YES~] NO [] 1900 feet MD 1700' (approx) 22. Type Electric or Other Logs Run ....... D IL/SP/GR~, SFL/FDC/CNL/Cal~. CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED '" 16" 65// H-/+0 Surf 80' 2M' 200 sx Permafrost 10-3//+" /+5.5# K-55 . Surf . 2721' 13-1/2" 1130 sx Class G , and 250 sx AS II " 7" 26# K-55 Surf 8852' 8-3//+" 7/+0 sx Class "G" and 570 sx Class G , 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) 79/+8-8057 ~ 8062-8071 ' 3 -1/2 ,t 8168 ' 81/+7 ' 8100-810/+' "26. ACID, FRACTURE, CEMENT SQUEEZE, ELFC. " 8120-812~' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIALUSED 8219-8223' 8162'-816/+' 100 sx Class (; , 8233-8262t · 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) 2/28/82j Flowi ng Date of Test Hours Tested' PRODUCTION FOR el L-BBL GAS-MCF WATE~-BBL CHOKE SIZE i GAS-elL'RATIO ..... 3/10/82 13.2 TEST PERIOD ~ 2373 1239 -- !)6/6M'I 522 _ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) PresJ.90 -- 24-HOUR RATE ~ /+735 2/+72 -- Z6. l° '28. CORE DATA ' - ' , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED 0CT21 Alaska 0il & Gas Cons. Commission ·Anchorage Form 10-407 TENP2/WC/+2 *Well was recompleted 8/27/85. Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate , .., , , 29. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT; DEPTH GOR, and time of each phase. Top Ku pa ru k 79~5 ' 5933' N/A Ri vet Form, Base Kuparuk 8326' 6266' Ri ver Form 31. LIST OF ATTACHMENTS ' NONE 32, I hereby certi'fy that the foregoing is true and correct to th'e best of my knowledge 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 intervai'reported ~n 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 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 9, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1A-12 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 August 14, 1985, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/JWR/tw SN/L055 Enclosure ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ( STATE OF ALASKA ~O~ ALASKA OIL AND GAS CONSERVATION C v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELLX~ OTHER [] 2. Na~ CAq%r~J(o~, ~no. 3. Adl~r. es~. Box 100360, Anchorage, AK 99510 4. Locatio~ of Well .... ~urTace: ~z~' FSL, /+91' FWL, Sec.5, T11N, R10E, UN 12. 7. Permit No. 81-178 8. APl Number 029-20688 50-- 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1A-12 11. Field and Pool Kuparuk River Field Elel~l~[~Ol~(~} teet (indicate KB, DF, etc.) 6.ADLLease2564?DesignationALK and/+65Serial No. Kuparuk River 0i ] 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 I-'1 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 p~'o_p_osed work, for Abandonmentsee 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1A-12 to a selective single completion. The procedure wi]] be as follows: 1. Well will be killed with brine. 2. Current completion assembly wi1] be pulled. 3. A retrievable packer will be run to test casing. /+. The well will be completed as a selective single. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: August 14, 1985 RECEIVED AUG 0 919t Alaska 0il & Gas Cons. Commission Anchorage 14.1 that the foregoing is true and correct to the best of my knowledge. Title Regional Dri 11 ing Engr. Approved Copy Date Approved by IRI~IIA[ SlIIEIt BT IOH~tE C. SMITH By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 (JWR) SN/084 and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PLEASE NOTE: BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE ATT-N: L0'RIE L'. .JOHNSON - AFA/311 P.-.O~ BOX 3160 ANCHORAGE, AK: 9 9 510 AUG 1 91982 Alaska Oil & Gas Cons. Co~nrniSsion DATE: Anchorage ARCO Alaska, Inc.(' Post Office B%.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 6, 1982 C. V. Chatterton State of Alaska Oil and Gas Conservation Com~. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Chatterton: Enclosed are well completion reports for KuparukWells lA-10 through 1A-16A. Very __truly yours, ~. S. D~yton JSD/er cc: L. K. Blacker -AFA 330 w/o Attachment L. M. Sellers -ANO 332 w/Attachment' E. A. Simonsen -AFA 311 w/Attachment H. C. Vickers -AFA 326 w/o Attachment t ECEIVED J U £ 1 1982 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc, is a subsidiary of AtlanticRichfieldCompany B. WELL COMPLETION OR RECOMPLETION REPORT AND LOG -1. Status of Well Classification of Service Well OIL~[] GAS [] SUSPENDED [] . ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska. ;[nc. 81-178 3. Address 8. APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20688 4. Location of well at surface 929'FSL, 491 'FWL, Sec 5, T11N, R10E, UN 9. unitor LeaseName Kuparuk River Unit At Top Producing lnterval 1380'FSL, 1799'FWL; Sec 7, T11N, R10E, UM lO. WellNumber 1A-12 At motal Depth 1522'FSL, 142.3'FWL, See 7, T11N: R10E, UM 11. Field and Pool Kuparuk River Field .5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. IO0'RKBI ADL 25647 ALK 465 Kuparuk River Oil Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 12/22/81 1/1/82 1/6/82I -- feet MSL 1 -17. Total Depth (MD+TVD)18.PlugBackDepth(MD+TVD)19. DirectionalSurvey [ 20. DepthwhereSSSVset [ 21.ThicknessofPermafro't 8865 ' 6759' 8762 ' 6663 ' YES ~] 'NO [] 2018' feet MD 1700 ' (approx). 22. Type Electric or Other Logs Run DIL/SP/GR SFL/FDC/CNL/Cal CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~;" ~5# H-afl Rllrf RI]" 2/~" ?fln.qw P~.rmnfrnsf. · 11'1 3//z" ~5.5~ K-55 S~,rf 7771' 13 1/2" 113i3~× £lns.q R l~.nd , , nnd 25fl .mx AR T T;~.n ] 7" 2(;~ K-55 Surf 8852' 8 3/4" 740sx Class G lead and 570.~× £lm.q.q G t~lil 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) 7948-8057 ' 3 1/?" 79n5, 7R2/, ' 8062-8071 ' ,,'. 8100-8104 ' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8120-8124' ~ DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8219-8223 ' ~/a - 8233-8262 ' 27. ~ PRODUCTION ii-'EST ' Date First..Pcoduction I' Method of Operation (Flowing, gas lift, etc.) 2/28/82 I Flnwing .... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 'I GAS-OIL RATio .... 3~1ri~R? 13 ..? TEST PER. OD.e ?~'7~.. 1,2:~9 -- .'~ . 9.6/6/," Fl~)w.,.Tubing Casing Pressure , CALCULATED "1~ O-~.-'B~L GAS-MCF WATER-BBL OIL GR~VITY-API'(~'rr) "Press[90 -- 24-H0UR RATE -r , a ; " ' ~ . : ~ ~ 735 :. ?.a. 72 ,_. ~ 26.1 o . 28. CORE DATA · · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' ' ;,. , : ¥., . ,: . ,, .. ,. REC,EIVED , - , : , J U L 1 4 1982 , , . . '"".. ' Alaska 0il & Gas Cons. Commission ... Anch0rags Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS ........ NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOp Kuparuk 7945 ' 5933' River Form. .'. '.. Base Kuparuk 8326 ' 6266' River Form. · ,. .. · · 31. LIST OF ATTACHMENTS · · 32' I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,.(~, ~~ ...Title RecJJ-°FI 0ps' Engr' E)ate .... 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 injecti'on, 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 mgre 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 r'ecords for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Me;chod 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". · J. J. Pawelek/Ann Simonsen ,.-., c_ C- $ ~ WELL i',F,,'~E Transmitted here;.:ith are the following' PLEASE HOTE' BL - BLUEL!HE, S - SEPIA, F - FILM, 6TAPE ~ ' ......""'liD: [.,/ //'//F~u.~ F-"¢'% ..-- DATE: RErEi?T AC~,,,O,';L[:,J',_~'" / LE.:',EE :-'",E-dR:i f~ECE.;?T TO' RECEIVED APR 0 8 1982 ARCO ALAS~SA, INC. ATT~!' Ar.;~i SIMO;~SE~! ': AFA/311 Naska Oil &.Gas Cons. Commi,~iol P.O. BOX 360 Anchorag~ ,-,,iC;:'~r:''''~ '" 9c510 J. J. Pa'..:elek/Ann Simonsen DATE' (/~ ~- S z.. WELL "~"-'~,~,.,~ Tra::smitted here,..;ith are the following' ?L~.~.: ~,0~E' BL BLL'EL! ~.-, S SE?.~A, F - FILi.i, T - TA?~ ?.~rE.! .~T AC .... n, ~:;-,~ [~' L ~ ,.,::,,~.~,~ ~E,FT TO' ARCO AI_AS;C'~, I''~ ATT~I'~,,~ .... -qIl'!0~iSEi~, P.O. BOX 360 DATE' , M,- Ga.:, (',OILS. Colt'iltl:$.~lOll A ...... 1<~ Oil & ' ~ · AFA/31 1 HC.,~Tii ~LLPE EiiG,~,~r~_i,~,,S~ .... J. J. Pawelek/Ann Simonsen DATE' .:~ ~-~.~---% !./EL',_ ,,~,.,._:" ~':~' · Tra::s..ni~;-:d~ ho,'-~,.,i~h_,~,, ~ are t~o,,~ follo'.,:inc' -.. PL_.= .... OTE' BL- BLU~L?~,"~ S - SEP:'A, F - FILM, T - TAPE APR 0 8 l~i!'' A!3ska [iii & Ga,q C(.ins.--Co,'nrmssior~ ARCO ALAS}CA, I''~ ATTiI' A~;F~ SIMO~SE~ '= AFA/311 .... P.O. BOX 360 A:;C"~OIA~E ~" c~:510 NORTH ~LOPE Ei:GI,,cr_RI~,G .....I¢~' TRAi!SMITM FROM' J.J. Pawelek/Ann Simonsen Transmitted herewith are the following: PLEASE NOTE: · BLUEL!NE, . ~_~ - SEPIA, F- FlU,l, T - TAPE EECr~PT ACr,,,u,'~.~:,;uED: __ .... ,.,~iu,.~ ECE~?T TO ARCO ALAS~CA, I''~ ATT~!' AN~; SIMO~ISE?! P.O. BOX 360 RECEIVED DATE: MAR 0 3 ' Alaska 0il & Gas Cons. Oommissio~ Anchorage - AFA/311 II02TH, SLOPE EiiGIi.IEERii;G( Tra::smi:ted he:'e:.;ith are the fol'lowing' PLEAt.- ,, . __ ~0~ · BLUELZ;~= SEPIA, F - FILi,1, T - TAPE TO: ARCO ALASKA, P.O. BOX 360 DATE.MAR. 0 ]5 ]982 Alaska Oil & Gas Cons. Comm.~ssior) Anchorage - AFA/311 ARCFO A~asi~a, Inc. Post ofdce.B( '60 Anchorage, At~,~a 995'10 Telephone 907 277 5637 February 22, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' State Reports Dear Sir' Enclosedplease find Well Completion Reports for the following drill sites' 11-6, 12-4A, 13-19, 14-9A, 14-26, 15-15, Also included are Monthly Reports for January on drill sites: 13-20, 13-23, 14-30, 15-1, and lA-14. Sincere ly, p. A. VanDusen District Drilling F,,ngineer Enclosures PAV/GLA: sms /£ ARCO Alaska. Inc. Is a Subsidi:~ry of AtlanticRic dleidCompany WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-178 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 .... 5o-029-20688 4. Location of well at surface LOCATIONS 9. Unit or Lease Name VERIFiL~D 929 FSL, 491 F~L, Sec.. 5, TllN, R10E, U~ E Kuparuk River Field At Top Producing Interval ' 'Surf. 10. Well Number 1379' FNL, 3480' FEL, Sec. 7, TllN, R10~ 1^-12 At Total Depth 1 1. Field and Pool 1522 FNL, 3857 FEL, Sec. 7, TllN, R10E, IJM Kuparuk River Field 5. Elevation in feet {indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River Oil Pool 100' RKBI ADL 25647 ALK 465 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 12/22/81 01/01/82 01/06/82 feet' MSLI 1 .,17. Total Depth (M D+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey i 20. Depth where SSSV set 21. Thickness of PermafroSt 8865'~, 6759'TVD 8762'HD,6663'TVD YES ~ NO [][ 2014 feetMD 1700' (approx.) 22. Type Electric or Other Logs Run DIL/SP/GR SFL/FDC/CNL/Cal CBL/VDL/CCL/GR' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16'" 65# ' H-40 Surf. 80' 24" 200 sx P. F. cmt 10-3/4" 45.5# K-55 Surf. 2721' 13~" 1130 sx Class "G" lezd&250sx A.S.II ..... 7" 26# 'K-55 ' Surf. 8852' 8'3/4".'! 740 sX Class "G" lezd&570sx Class "G' - 24. Perforations open to ProdQction (MD+TVD of Top and Bottom and 25. TUBING RECORD .~ . · in,terval, size. and number) ' .. SIZE DEPTH SET (MD) PACKER SET (MD) 7948'- 8057" 3~-~.'' 7905' 7828 ., 8062' - 8071': ' ,., ~ ' 8100' - 8104' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 8120'.- 812.4', . · :,, ,~ ,~ . ,,~ DEPT.H.._ INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED' 82t9 ' 8223' N /A 8233' - 8262' - 27. PRODUCTION TEST I ' . . . Date First Production, .,,Method of Operat on, (Flowing~'.gas lift.; etc.)" ', IN/2-k Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I,GAS-OILRATIO I - TESTpERIOD.I~ ,. ;, :. , ' FloW,Tubing ' Casing Pressure ' cA'LcuLATED OIL-BB,L GA..S:MCF WATER-BBL OIL GRAVITY-APl (corr), Press.. ' :' ' ~' ' · "... 24-HouR RATE*' '. ' .. ' ' :, '. . " , 28. : · ~ . C~RE DATA · Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. · ~ ,:. -. ~ , : · :' , ~'~ ' ., · FEB¢ _ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE ';,Lil:::tJLfJLill;~----~ -- MARKERS ........ .. · ...... ;--POHMATILIN TESTS ,- , ~ · ' NAME . ... ~:~._. .~ Include inte~l t~ted, Pressure. data, all fluids r~over~ and gra~i~, :,,:_. ' ..... ~ ....... - ' MEAS.'DEPTH. TRUEVERT; DEPTH .... .,.'-"GOB;and ti~e of. eaCh se.' . T~'~a~ . 7940i ·.. ......, . . .: ..... -' ~e-~a~ - · ' 8325':' · ' ..... - - -. :'- ' " ' ....... .. : . ,~-( :.. x . . . . ' . . ~ . ..2 ¢ ..... .. · ~ .. ~ . . . , ." . ~ · . : .i ,' ~ ,', ...... . . . . .. . ; -, . , ., ~., .. . ... ,; ~ . , ./ ~ ',- . ~ . ~. ' -. . .,. , .] - -, . .. ..... .. :. · . , . . , ..... · , .: ~. ~ ..:' . · . · ::.~ , . , _ ... . , · , J .... . , . . , . ,.~ ,. , : ,. . . . , . - . ; :, - , ,, ,- . - . . , . : . '... - ., ·., . . . . · · ,. . ~ ., , - '., ,., .,..' , ..:, . : ..'.... ,,. ., . . ,, 31, LISTOF.ATTA~HMENTS .. . .... , ...- -... . . 32. I ,hereby certify that the foregoing is true and correct to the best of my knoWledge ., , : ~nior Signed ~;.. Tit,e .~illing ~gineers.t~ / 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" Olassification 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 productiqn from more than one interval (multiple completion), so state in item 18, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced,'showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. · Item 28' If no cores taken, indicate "none". - Form 10-407 lA-12 Drilling History NU hydril and diverter system. Spudded well @ 2330 hrs, 12/22/81. Drilled 13½" hole to 2?55'. Ran 65 jts 10-3/4" 45.5#/ft K-S5 casing w/shoe @ 2721'. Cemented 10-3/4" casing w/ll30sx Class "G" lead cement followed by tail of 250sx Arctic Set. ND hydril and diverter system. Instld 10-3/4" packoff ~ tstd to 2000 psi - ok. NU BOPB & tstd to 3000 psi - ok. Tested casing to 2000 psi - ok. Drilled FC & cement. Tested casing to 2000 psi - ok. Drilled FS and 10' new form. Tested new fora to 12.5 ppg, EM~'- ok. Drilled 8-3/4" hole to 8400'. Ran DIL/SP/GR/SFL/FDC/.CNL/Cal. Continued dril~g 8-3/4" hole_ to 8865'. Ran 221 jts 7" 26# Blrrr casing w/shoe @ 8852'. Cmtd ?" casing w/740 sx lead slurmf followed by 570 sx tail cement slurry. Set ?" packoff and tested to 3000 psi - ok. Test Casing to 2000 psi - ok. Drilled cement to F.C. at. 8?62'. Arctic Packed 7" x 10-3/4" annulus w/300 bbl H20:,~"250sx A.S. II and 100 bbl Arctic Pack. Displaced well t° NaC1 brine. T~sted casing to 2000 psi - ok. Ran CBL/VDL/CCL/GR and Gyro. Ran Geo-Vann gun & 3½" completion assy w/tail @ 7905, and pkr @ 7828'. Tstd paCkoff'to 3000 psi - ok. Displaced well w/ ~77-Bbl diesel. Tested'tbg to 1500 psi - ok. Set packer w/3000 psi. Tstd 3~" 7" . ~ x annulus w/1500 psi and 0 psi on tbg. ND BOPE Nil tree and test to 3000 psi. Drop perf bar & fire guns @ 4 spf through the following intervals: 7948' - 8057', 8062' - 8071',.8100' - 8104', 8120' - 8124', 8219' -8223', and 8233' - 8262'. Flowed well for clean-up. Dropped ball and pressure to 2500 psi - guns dropped, 'Closed SSSV. Bled tbg & annulus to "0" psi. InStl/l BPV. Secured well and released rig @ 0600 hrs, 01/06/82. FEB 2 4 1982 A aska 0il & Bas Cons. Anchorage. Mr. Bob Hines ARCO Alaska, Inc.. P. O. Nox 360 Anchorage, Alaska 99510 February 2, 1982 Re: Our Boss Gyroscopic Survey Job No. Boss-16952 Woell: A-12 (SEC5 TllN R10E) Kuparuk Field North Slope, Alaska Date of Survey: 1-4-82 Operator: Tom McGuire Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of serivce. Sincerely, KA/pr NL SPERRY-SUN, INC'. Kirk Afflerbach 0mm~ss~istrict Supervisor Enclosures cc: Dave Rees - BP Alaska Exploration Company Steve Lambert - Union Oil Company Donald James - Sohio Petroleum ComPany ixIOF, TH SLOPE, ALASKA GYROSCOPIC SURVEY I-tOSS 169_52 RECORD OF SURVEY DEPTH ANGLE DEPTH SEA DIi~EC D PI BEG · ....... , ........ ~.. ........... ~..:.: ,:.~;:~? ?~::?.,:.~..~: .,?.-::~ ,.,.~:..:. .. ,: ..... : ,. . .... ..... g. 9~:~.~:~:~....~:?:-. :.'0' :0~0' ~:~::: 5.:.:~:.',[:..~O.O.w ?:::.::?~:~:?:~:t::~:.~`~:~`.~:~..5`:~:.:~:~:~.~::~.~.::~:"..~t:.~` ~:..-::..:.?:!'::~':~ ~ ~ ~ :SL~".. 2-:....':~ ~t~O 0 ~ 299.94 19~.9z,~ S 7.OUE b.21 S 0.22 ~ 5.~2 S 2 600'" () 46 '~:-'599':9.t:.::':;.:;::~'~99,'9Z .... ''~W'- :'"' .... 9'.167i.~:..':';:'8 ~9 58 W 0.050 700 0 45 699.90 599.90 S 4.1uw 1'0,~4 S 1,67 w' 10,~7 S "9 11 _ ~- oo :/Z_Co _Z..?~?.~..~.~.~2~?...~.?.? ........ ~.~.S...~A~.W~ ................ ~.~..,.A:L....~ ........ ~..~.~..L._.~:~. .............. L.Z._,A:L~_!~_~_.~.Z..N_ .......... U., ~ 0 C1~ 0 33 89~.b9 799.89 542.t~OW 12.28 S 2.80 W 12.D9 S 12 1000 0 43 999.89 899.89 552.40W 1~.02 5 ~.62 w 1~.52 5 i5 i,~.ou 2 2~ _~,~.~/+ ~,,~') ~ s~ iow i~, '/(~ ~ ~ 'z~! w io ~JL~_~...~,__~!~, ...... ~:~ ......... :.~,,..,.'(~ l~, 1300 8 [~1 1298,85 ' 1198,8b STi.~0W - 2~.09 ~- 2~.9o W ~..59..5 ~Z l/,,oo 11 5D 1B97.1~ 1297.1b 5~4.'~0W ~o.43 ~ ~?.lo W z~,D) ~ 5Z ~4zi ........ ~~f~~~~~i ...... z~.~.g 5 ...... b7._,ll_W ....... 71..61 S 52. i.~ o ~z ~.~..s .'.~t~:~:o i'.:.:-:, i.~:....~,~.. 1900 26 55 1869,37 1769.37 S56.60W 124.0~ S 168.22 W 209,00 S 53 ~5 ~ W 3.929 207,~5 2000 ~1 0 1956,84 1856.84 S56.80W 150.62 S 208.70 VV 257.38 S ~4 lO ~ w ~.08~ 2b5.77 21oo a~ 39 .2o~o.~6 ~9~o.36 S~.:~.6ow 1.8__~?~__s_ ........... ~o_~.~_.6 ..... w _ ~..Z~.~o~_~__.~%L~ ..... W.. JAN · ~;'~2 ' ,, ' RECORD OF SURVEY MEAS, DRIFT VERTICAL SUB DRIFT TOTAL COORDINATES C,L 0 $ U R E S SEVERITY DEPTH ANGLE DEPTH SEA DIRGE DISTANCE ANGLE DEG/iOOFT D..M ........................................ 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Z ...... 5400 52 ~9 4052.97 ~95~.97 S60.70W 1586.51 S 2~4~.11 W ~914.72 S ~7 1 ZO W 0.~,5~ Z909.06 -5500 51 51 ~114.16 4014.16 S61.10W 162~.98 S 251z~.21 W 299~,63 S bY 7 29 W 0.837 298d.1~ . 5600 5(:).31 .. 41.76.,82 ....... ~~2 .... $6!.,.60W ..... l(~E.,.~z+~ ~ .... 2582,61 ..... W ........ 30~..!.,.~6 ....S.. 5.7._ 1.3 5.~::k~ 1~..~ .... ~.~07 :.~ ~ c - ( ~ ': : ~ .~:.:~: '~ ; ': ::':::~ "Z'(::'~ ~ ~":~:; :: ':::::~:(:~:' :;~'::);':~:::::c~:~: ;::~:~ 4~'::::::;f:::~:. :~.::'f ~ :~::: ~..: .:..:.~:::.~::.~:.:¥~?~'~:: ::;.~ '~' ::~ :~:~ ::::::::::::::::::::::: ¥:;::?~.:~ :'.~ ::'.':":": :: :.:;:[~::~::'":~::.?."?:~'~::': 3:.:;:: :.~:: c :-. ~,' L: ~: .... :~ O.D :~:~_2...:2 l::::::..:.~.~.~Z:2_,:~6:.:....:::.~.~:Z:Sj,:~.6:::-: ~8 ~ ,-80~.:: ::: ::17. ~0. i5.~ ::: S :::~::: 2ZS2 ~: .~.~.~.~.::::::.~:.:~~ 5.:... S.:~ 5.7:.;.. 3 l.:.: =..[ :. V,::.. ........ 0...,/~/+~5 ..... 6000 47 ~3 z~z~39.25 4339.25 S62.20W 180~.~ S 28~8,~6 W ~72.~6 S 57 ~7 52 W 0.'76~ ~67.85 6100 46 57 4507.00 4407.00 562,50W ].~9,58 S 2913,51 w Z4~5,67 S 57 4B 5~ W 0.783 · ;¥?".::.:'"~:: '.:~ ::::::::-~.':~¥'~ ':::'..:~." f~?;:::.': ~::"~ ' '~' ' "'c c ' .~:;:~:::;::.:.:~:~.:~ :::::::::::::::::::::::::::::::: ~.:.:.::W ...:::.: ~.::~ 0 · ~ ~ ~ 3 ~ $ ~ · 7 3':: ~:~.:..:~:~:::~.~:~::0~::.:.::.:.::~....~.:.~::::::.::: ~ ~..;.;:~ ;::::::¥:,~.:7.~.o...::::.~ ~;:::::~:~::::.:::~::..~ .:..o:.Z::~::... ::0:~:~:.;::.-~.:::~::: S.~ :~:.:~.::~;~:.~.`:::.~:;:¥:~::~:.:~:.:~.::~z:::.~:~:...:~:::...:..::.~::.~:::~::~:a:.:~?~:~:~.~.~:~:[:....~...~::~. ::.~.8::~?:~:~ ........ ~.~:c~.:~:~:~:.:~::::..: ..?::~..:.......:-:::....::.::. ::~:......:::.:~:~;: ..~?:: '..:::. :~..:.::~: ........ :c:,?:-: .... ...: .. :.:.. 6600 49 25 4,859~7l ~759.71 S65~0W 1995.~8 S B2~6~ W ~798.05 S 58 18 Z~ W O.~i~ 3795.02 6700 42 40 4932,77 ~8~2.77 S65.80W 202~,75 S ~293,76 W ~86~.80 S 58 25 57 W 0.81~ [' -': .c ':" ': ' :~ '-;:':'"~ :: .... 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' 8300 27 22 6242.66 61~2.66 866.60W 2380.28 S 41~1.06 W 4767.74 $ 60 2 59 W 1.~10 z~767.~3 -8400 25 12 6332.30 6232~30 8'70,80W 2396.~7 S 4172,33 W 4811.94 S 60 7 ~ W 2.297 ~811.38 ..... : ~ ....... : ..... ~.'..~:I.._ ..... :. : ~ ' :--~ .: - ~ .,. =-- :. ~:~ ..... .- .~ -:.. -~... . .:.. ---- --- --.=,-.r, i ..... :~ 7~-..-.~ :'~1,'-- - - --~ : ~--: .... EXTRAP()LATED TO TD~ JAN. 82 TRUE -.COD[.'.' .MEA..SUR~D ........ VER~T!.CAL,. . ..-.T:OT.AL.,.~: COORD!.NATE'-S..... ........ ..C..: L.....~:.5,..:U...R-E .... ... ......... : . .........:...:,...:: ...: ~.:.. ~.. : :.:;.. ~:..;:. :.. ~::.:...:..:.~..?..:..;:..:..:?~.:.:.:..: ::..-.: ......:...:.::.: :.:..~:..:~.~:..~.~:.:::.~.:.:....~.:.:.~..~:::~:~:~:.:.~::~:.~.:::~:~..~?::.~::~.~:~:~/:~::::~.~:~:..:.~::.:..:: ), :. t.: ~ :'~':: . ,~ .... :-..., '..'... ,~..' ,,:.,..':.. ,. ..... ~ '::.:: ': :'.,,'-:,' :::.:. :','.~., ': .,. ', : ':' )' ~ .': :. .: : :'.;...',.:. ,:.::..',,. '.-~.~::..:..'..:.:.::,:':.(.~v::)':':.'.::.:'_.:'.,..:.:.-:.:-.?~ :~::.~:~:.):..::~::::~.`.~..:.:~.:~:.~::.~:....:`..~:`:::::).).`.~).::~:..~.):. :-:.7..:,:).)"'::'":":':::".:....::"'.'.:~,::'~.?:'"L: ~ :',:;'.', . :: .'":':'Jr':.:' ' ",:',).: .'..:': -::',:'..., .; ..... ' '.' -', ' ,SEA TOP KLIP 79z,,.0 5928..53 2308.19 S 3970.7z+ W z+:592.88 ,5 59 z,,.9 ,50 W 582~..,53 ~.~. ":~'/..:"::F~::'t2.:~::;~c"~:~:~:t:.~:~.~::¢~:.:. ~¢?,.'..'-':.';:"':':.~'::L :f;~t'?.;:~'~;:h~:~3t:~:¢~::~ ':~,"' ~::'~:..~?'.:.~'-':?c.~?~::::.t¢?::'t :.:t':.'¢~.:"~-".'i-::" '":':':'::~,.t~..~:':~:.~::¢?¢:.'~'~?~':'.':.'~ "~.~',,:f~'::":"'":.:'.-:.: "?.,:.~.'::~:?:".'~ ....... .... 't.. ::'"':':::~:'.~.: "'.-z..' .... :".::,:-" ".:. . , ,'. :, ' c 82 ..- T 200 200. 100 0 0 3.44 S 0,,01 E 700 VO0, 600 0 o ~0,34 S 1,67 w ' 800 800, 700 0 0 11,~7 5 2,1i ....... ~00 .......... 900.', . .. 800 ....... (~ ...................................... 0 ~ 1.2...~.2.8[~ ...... S ....................... ~[ ~..-~{'-~:J7::.'}"9 .nr'~::::.~[~::~:.::t...:[~t ........ "'"'"~':"'"':'~:'~ ........... .-:.-.~.~.~:.:~.~:~x~.:.¥~.~.........~..:.,~..... .......... :"~'~:' '~'z~':'~ '':'''. 1301 1300, 1200 1 1 2~.1~ S 22,10 1403 1400. 1DO0 2 1 30.70 S D9.04 W ..... 1505 ......... !5.0.0_., .......... !.~0 ........... .:. ....... 5 .......... . ............................... 3 ............ . ...... ,_:....... ...... , ..... ...,.~4E.~:..OA.:....S. ................ .. ..5.7 ,. 9 ~. .. .. w . ..... ...... 1'935 1900, 1800 34 11 13~.11 S 181.~8 W 2051 2000, 1900 · '51 17 165,92 $ 231,16 W 2773 2500, 2400 273 56 467,28 S 650,84 W 2929 2600, 2500 328 55 537,24 S 747,53 W 3742 3100, BO00 642 72 900.25 S 1275.64 W B921 3200, 3100 721 . 79 978,46 S ' · 1401.62 W ' ~102 .. 3300~ ,.BPOO R02 .~ ' R1 ..... ' ...... ]DBA.AA S 1. SBO.R1 W ""-' ' '"' "'-" '- '"' '"'~-'-" --' -------~"-'-'~--"'"-'~'"'-"" ""'"" -"' ' - --- "'-'" - -x "-'~-L..,..:~,,~: i~.}~;~:,~.~(.~ ;44.59.J..~<;;Z~.::.,.: ~:~:~(C?t::.:s~. o ~...(;?.;.~::~.:~.~..~.{;;~::U~.~`~.~.~::?~:?~?:~?~?~/~/.~:~.?~.~:~:~7~:~{~::~?;?.~?~:~.:~:~:~.~.~:~zz o a':~?.2 o':~.s.'jt.~(Z~}:'~'::~'a ~,. as ;w. · :' ::': ::.' DEPTH:.!'' .i.i.i:i:~i:::'-'?:!:~: F!.ERE'NC'E':i?'.i-:!t:.: ': '.'.:'cORRIZG:'TI''I.:ON'i:.?.iI'i.:' ~::~:.~.::::,?:.TiOT'AL::i: ~?::,::COORD'.[NATE S.:.:.'f,:::::.: ::'...?' ~80~ 3700. ~600 110~ 71 1348,42 S 2027,04 W 5636 ~200. ~lO0 1~36 59 1675.78 5 2606,8~ W 9790 4300. ~200 1~90 5~ 1731.87 S 2709,56 W 59~1 . ~aO.O, ..... ~~~] 51 !785., 2~3.-.~ .... ZS.0~.~Y~. W ' 6089 : ':~:'.;~:5:0'0, ':'-t.:~fiO0::: 1589:'t'~ :~ -,.... C::~8:..:t:::;~;:/~,..';~:~. :'.';':'..:::.-:;:~: .... ::'..Z8~6.19: S :',-'-2906.18 W ....... ~ 2 ~ ~ ~; ,~t, :. ::.- ~..~:.~:.]:~:~.600.,'~t.;~..t,;~ ~ ~ 00?;;~-.::L.:~: 5~: ~.:~L.~jy~%~:~.~.t..t.~.:~:~t::~:.:~.~:~:~::~..~.::..~:~::~.~:::?~:~t:~..~:t~:~.~.~:~?:?t~:~.~:.~.~:..::t..:.~,.':~ .......... .:.~:-:.t:.:: ~ 88 ~:'t2 9,~.-~t-:5..; {:~.?:: ~:.: ~ 00 ~, ~,~ ':.W . .:..'-:~;_ :-~ :--'.,~,~>L. ~'~~t: t':~','~~:~:~ :~:?:.:~ :~ :~.:.:': :~ .~~"~i:::.:~::~:: :~:?:: ~,~ 0 0 ::f?:"::-~:t ~z??.'~:b-:; ~ :':::~??::;::~. :'::::-!: :~':!:::.'~ ?~?~?~'~::~'~;~.? ~::~: ~:~' ~?::'. ~:~: t".~:~.::: ~ ..:~:~:s~:??:L::~.~zo~w 665 5 ....... a7.9 ] .. 6924 7054 '~ "'"~ 7308 7432 4900. 4,800 1755 38 5.0 00._-.. z~9_O 0 . ! 79 ! "~ 6 ......... ... -- 5'100.'i'"!,:!' ; 5000 1824~ :'"' ......... ".33 :,?:~,:.~....i:i... · ~ ~oo. ~ ~:,~,:. ~ ~ oo.. :.:~ ~:~ s~:-~:'~ :. :,...,::.~,,..:,.~ .,: ':: ~ o~."."~:':';. :'..;?.:~" ' 5400. 5300 1908 26 5500. 5400 19B2 24 2011.30 5 3265,79 W '~'2081,39':-5" '3431.02 W 211'~.0B':'::5:,, 3508.01 'W ~172.86 5 3652.71 W 2201.16 $ 3720.59 W ... .,: · · ·., - .... :',; · ", -".:,...:,-:'.:.'..,,.::...':,:.~,:.~. ':~?, :','::.': ..,',, :-.':'~'::'. ',.:::-. :'." ' '~.:,'"~%.~..~ ::..<~ :~t.:':, ?": :;."'. ¢::: .: .L':" ~: ~ .-..: ' . .-(~t'~: ',' .;~.:':':.~J:"; ' ~ ' ' ". ' ' 8022 5000. 5900 2022 15 2324.67 S 4008.18 W 8138 6100. 6000 2038 16 2348.97 $ 4060.25 W 8693 6600. 6500 2093 9 243B.Z9 S ~285.04 W 8801 6700. 6600 2101 8 2444.~7 ~ 932~.78 W ,_ INTERPOLATED VALUES FOR EVEN ;1,000 FEbT OF MEASURED DEPTH. 8 2 lO00 999, 899, 13.0~ S 3.6Z W 2000 ~956, ~856,. ~5~.~0 S 208,35 W · " .... -.-.. ','-t'--'.~ -~ . ..,.:.'...-.,..--~.":.',:,:_-:~'~ -,' .' ~ -~:,(X-:.:':'.~-~"' .~ .~ .:~.:...,-,,~:,('.'..,('.:'.:,..,'.{-:,?..::.'.??-:f...~. T:...~ .~..:.::.'.%.':':.".:' .. ,.':.{:.:. ::'-:ee:".:-~-:,::;.':.::'~:...:;~:',-~'~.,:: {'.;..'.. :' "'/(-:' . (.~-.-; ('.-L.-' :' { 7000 5158. 5058, 2100,5~ S ~476,10 W 8000 5980, 5880, 2~20.37 $ ~998.09 W ~ ,,., ,:. ,., :"-::'::" ' ........ ~ : ........ i ARCO ALASKA INC. ' -'-i .............. .-.' - -::.-.:- . · · ._ ......... : .......... :.__' .... - ............... W~...LI-._ ~-_~,% -- !/.- .........................., ........................ : ............... - ' ' GY'ROSCOPIC SURVEY '' ~ ' · _i .................... ~. .... ~ . . -' ' ' - :--- :--- ..... ...... i ..... : .....: :_.~ ...................... .=--~ - ...:..~.'_: .... RADIUS OF. C U RVA:]"UR E: ~;- .... : ...... : ........... ----:.i ......................... .~:- ............ _.: .... ! ........... : ............SCALE.. ;..1 ....................... ,. ............... _ _. --* 'T-T-- ........... -~ ...... , ...... .... :-':-- ......... :--~---: ........4:-:- ......... : .............. ~-)-- , ............. FEBRUARY.-_::_.I ,._!982 .......... ':__.:_:_/. ....... :--_ ..... ~.__:_--_.._: .... ....... : .... ~__ · .......... i- .... : .... -:. .... _,._._: ................. i__L_ ~ ..... .:._ ........ ~ ............... : ....... ~ ............... i .... .:. ...... _' ............. .:__ _.~ .......... ; ~ ~ . .. ~ .... . . : · . . _ . VE RTl C AL-'"' SECTI ON ARCO ALASKA INC. W ELL. '--_.A ~12. · - _ ' SURFAC'E--LOCATION~IS 491 EWL' SEC~-5,-'TIIN.:R IO.E._L.]._~: GYROSCOPIC SURVEY RADIUS: OF CURVATURE SCALE' ...... FEBRUARY' ..... ~ : . . .. ~-. . , . , . . _ .... ,*-..=': :":-,':.~-: ':' ~-- :'-: ? ~.,=.~=.~L.~.= ......... ~ ....iz°o" ' * :~ ..... ; ..... ' ' ' ....... , ......................... . ..................................... . ................................ ~ : ............ , , ......................... : ........................ - .{_... ......; ............. ~ .... '. ,, . . . ~ ~ : ~ ~ . '. ............. 2400 - :' ....... ~ ................ !. ........................... _ ' ' ~ ........ -~:::=::;. : .: -.., . . ,==- -: -.~ ............... :-.::,-:.= .... ~--: ....... ~ ............................... -~ ...... : ...... : 2800 ~ ........................ ~ .............. ; ............... ~ .......... ~ .......... ~.--: ......... ~ ~ .... : ....... ~00 .......... - t .... ' ' : ~ - *' - - -- ~ ......... ~-- 3600 ..... i .... : ........... ~ : ....: .... ' - ' ~; ..... .i '- ~ ']] ..... ]'""=~ ..... ; ...... :'~ ........ = ....... = .... . ,': ~..:J._Z i .............. :]'];-': 7-'"]'~'.'=,' ...... ]] .]-.'-.. ;. ; .........i ........... ......... ~ ......... =.-i..:-: ...... ; } - ' ' ' ' ' ' ~ ' ....... , [ :._...-.....~ . . -'' > .......... : ...... .: ~ ..... . ................................................ ; .................................... 4800. . - .~-~-*:;:~ ~ . -:.'=:=,."-' . · . , - -- .. :- - - i : ~ . '? ~.,-;, ~ ........ L..~.,L.& ....... '_L__~ ....... ] ........ : : : ';' ' : ....... ~ .-.--: ..... i:-- ............ ~. i 5600'-.' ....... ~ - ==f=_ .. _: ..: .... },.~] ? .. :'?'=.~ : ,"., :. ,.-.: L'~'._ .... . ; ' - .......................... : ....... : .... "'*-=-*-*--::: ........ :---:~: '-. :- *:--, *': =='-.-" - - i - -' .' ........ , .... 6000{ · "~;]7 ...... ~; ......... ; ...... ='"; ;~Y"'; .............. / ~-~ ....... =~'~ ........................ ~ ..................... ~ ...... ~ ................. ~ ........... ~ ........ ~ ~ ...... ~'-~ ~::::~: . ......... : -- .... .............. sper, r, -sun · January 5, 1982 Mr. Bob Hines ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. Boss-16952 Well No.~~ (SEC5 T11N R10E) Kuparuk Field North Slope, Alaska Date of Survey: January 4, 1982 Operator: Thomas McGuire Dear Mr. Hines: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Multishot Directional Survey on the above well. Thank you for giving us this opportunity to be of service. Yours very truly, NL SPERRY-SUN, INC. Kirk Afflerbach District Supervisor KA/pr Enclosures TOT~! n!RECT!AN ANGLF 'VE_R-T-~ , LATI_T_LIBE F4~GE 1 ~'__ BOSS-16952 JANUARY 3, 1982 .... -0.00 0~00- : . 100 S 4 0 W 1 19 9;~.99 1.16 8 0.09 W 0.62 1.~ 3.45 S 0.04 W 1.66 0.25 , 20¢) S 6 42 E i 19 199.96 . :300_ _s ~ ,~ - ~'"" ~ ' ....... ':':':"' ",~ ~ .0: 15 W :- :3:,':i 90. 55:. ::..-:.::.-.:..:..::'::.::400 . 32 30 .. ~ ..... : '0. 5.1: .:: ..:..::.::::'~.399'~.4 ::. ::::::::::::::::::::::::::::::::::::: ~ ~ :'..:-:::::::: ': :'-:':: :::::::::::::::::::::: ================================================================== ....:..:...: :. :::. ...... ::::::::::::::::::::::::::::::::::::::::::::::.:.....: :::::::::::::::::::::::::::::::..:.. ...... :. ::::::::::::::::::::::::::::::::...: .... ...... :::::::::::::::::::::: .... 0.. l ..... ~00 S 23 48 ~ 0 4& 599,92 ~.00 S 1.43 ~ = 51 00o 700 ~ 4 6 ~ 0 45 &99.91 10.27 ~ 1.74 ~ 6.39 0.26 - ............... ,.~, · ~: < ..... :::.' :.::::;:.: .::~: :~l ~ .': ':...:.::.::8, 2~ ..... 0"I2: ...... · .... ::,~,,-,~ .'~o :'~ .':u :. '.:0 .:..::::::~.i::~O' :::'::::::: :::::::::::::::!:'~ ================================================================================= ==================================================================================================================================== ============================================================== :::~:::::...~ :::'.~?: .... :::::::::::: ::':::'::':::::::::::::::::::':':':: :': :.": ::..: ....: :': %: ::':':::::::::..:::: :.~::' :':::':'::: :::::::::': ?:::: ::::::: :::::?: :'::: :.:::::::::::::::::::: ::':::::::::::::::::::::::::.: ::':':~': :::':~:::::::::':::~:': ::::' :::::::.:.::~:: ::':::":: ::: ::::::::::::::::::::::::::'::::::::::::::::::::::::::::: :'?:':'.~::::~:::::: :: :::'.:::? :::.:::.::::: :'::': :'::::: :::::~:::::::?:::':':':':: ::::': :::::":::.::::': ::'.::::: '.....':.: :.:~':::::: 8':' :::: ::.:::::.: ~' :. :::: :-::::::'; .. ::::::: :::::::::::::::::::::::::::::::::::::::::::::: ~:..~:::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::~:~:.:~:~::::~:~:~. :: · ::':::::': :::::::::::::::::::::::::::::::: :'~ ================================================= ~ ' :...:::~~2' .... O~' ' ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::' .:::~:::::::::~ :'::.::~ =============================================== :? :::.~:~_~.:_:o' - .............. - ............ ================================00 --~:~-. -- -- -- ......... .: ~ ' 10~ 85 14.~6 S 5,80 ~ 12.05 1.76 1100 S :,C 6 W 2 28 . 59 ':' 67 1200 S 56 6 W 5 7 1199.62 18.5:3 S 11.15 W 1:~. ~- · -- ..- ..~ 4 73 1450 S 54 18 W 12 39 1446.03 35.22 S 4:B.~::::/ W 5.9.'-''= · 1500 S 46 0 W 14 1 14~4.69 42.62 S ~,7.19 W 70.55 4. 73 ~' ...... -. ,- ,, ~- =~ ~,~,~ ~-~ 123.31 S 16~:.~6 W .--U6.61 ~.~7 1.~oo ~ ._.._c w - - ~0()() o :,~ 4~ W ~ --- . ...... -~=~ -~ ,.~ 4n~_~:~ 4~ , - = -. o: ' o ~44 . l~_._& ........... - -. , ......... , ..... .. :'.'.....::::.:::...:'.'. ·., - ~ ~ ~& ~~ .................................. ...... . .................... ::.::. ............. . .............. ....: .... ~... ..~.=.:::::. ....... 21 ()0 - .' ..... ~ ~'~ ........................ ~ . ......... ~' ).c, ...... 5- '. ............ - ................................................... .............. . ............ · ........................ · ..................... ) .9 ..... ~7(, ~ ~,. ..... : ................................. ......... · ............... : .: ................. 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S ............. .::..~( 4. ~.7 .N ............. ~ ...... .. ............ · ...... · ................ .. · .: ............................... ...: ......... .~ :...-::: .... : .... .... ..... , ~-I .:: .................... ~1~..47 ..................... ...................... . :..: .:. ...... ..:.::.: ............. : ......... . ....... ..: ............ :::. ............. ===================================================================================~5.:.:.:.:.:::::::::~.:::::::N::::::.:::::.::~:~.::::.::~:9::::..:::.:::~:.¥:::::::~:~::.~.:?:?:::.:.....: .: :..:::::::.::::::::::::::::::::::::::::::::::::::.:~:::..:.::::::.:::::::::::::::::::::::::.:::::::::::::::::::::::::::::::::::::~::::::::::::::::::.:.::::::.::.:::::::::::~:::::.::::::::.....~::..:::::::::::::.:~::::::.:::...::.:::::::::::::::::::::~:::::::.:::::::::::::::::.::::::::::::::::::::::::::.::::::::::::::::.::.:.:.: :: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::.:: ' .::. ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ::..::'::.. ':~: .::::::':::::::. ...::. 7:..:::::. ~:~-: . ............................. ::::.:~:,r,¢, - - ~, , ~ ~.bl ~ 4~1.~. o=r,r, ~ ~:~ a,-, w 50 4 ~j4~4.74 ~4 :::::::::::::::::::::::: 90 ::::::::::::::::::::::::::::: : ::....:.::?...: ....... ... 2900 S 53 48 W 49 46 3000 S 53 24 W 49 49 .,~.~6 S 729 86 W 2581.41 =o¢, ~ . 2645.97 568.58 S 791.32 W 890.72 0.46 966.32 0.31 3400 S 55 36 W 52 8 2896,.95 749.37 3500 S o6 24 W 52 49 2957 86 793 71 1044.86 W 1275.28 0.48 1110.61W 1354.19 .0.93 SPERRY-~LIN I NCOJ~CLRATJED PAGE 2 '"~ ..... :'~'~COOIL AND G~S~'"'i'"'"::"S; ..... __;::: i~:. ':'~::' :' ....... - . ......... BOSS-I&952 .... A-12 (SEC 5 TllN RIOE) JANUARY 3, 1982 TOTAL DIRECTION ANGLE VERTICAL LAT I ]~UDE._ DEF~I~]CURE_~iC~L DOG__ 3900 S 58 18 W 56 12 3188.33 968.47 S 1386.75 W 1680.1~-J 0.48 4000 S 58 48 W 56 43 3243.59 1011.96 S 1457.86 W 1763.42 0.6.7 4100 S 59 0 W 56 26 3298.67 1055.07 S 1529.32W 1846....78 0,33 :::.~:.~i :..:: · i:: i. '-~. ~' "~ ' · ~ '::'::'~'~ ' '" '~' *~ '" I _~-_'r~ ~ :'], ' ....:~:~:...:.:. :.....:.:.::.~---00 o 5 ~ 0 .W ..56:..11 ::.~:~g~o54.,..15 : :.. .... 1097.9~ ~ 16c~ 3.64 W 1. ~9. ~ 9 .0. ~.5 . :::. .'.4300 ._:.._.~__5;~__ _6._~ ....... _~ ...... _0.__...'.',:':~_4..0.?.,..,'?__4 .... ::i.:~':! 1.._.4.0,..6_0..__$__L~_16.7!.. 81.._.._~ ...... _20._1.2,~._.9_ (~-{_2__0_ .... 4400 S 59 42 W 55 12 3466.43 1182.60 S 1742.8:3 W 2095.23 0.94 4500 S 5S.~ 42 W 54 48 3523.79 1223.93 S 1813.56 W 2177.10 0.40~ '4600 S 60 6 W 54 40 3581.53 1264,87 S 1884~1_9 W 2258.70 0.36 ....... :~.::~.~::~70c~ .... . .... ,.... 48 W ~,4.~5 .... ::.~::~::~:6~,.., ~,.~ ...~:..:..~.:~:,.~.~,0~,.66 .... . . :. ...:.:.:.:!., ~ 4.7c W ~-~4¢. 1~ ...... 0.::0.4 4900 S 60 0 W 54 2 3756.61 1386.99 S 2094. :99 W 2502.20 0.11 5000 S 60 12 W 54 11 3815.22 1427.37 S 2165.22 W 2583.1'B 0.22 5100 S 60 24 W 53 42 3874.08 1467.43 S 2235.45 W 2664.01 0.52 ~::::~:ii:~:~:i:~i:~.!!~i:i:~!i.ii::!:i:~ii~:!~:~!~i!~!~!~i~!~!~i~i~:~i:!~:::~i !:i :.i:i iiiii:ii~::ii!i':-ili::!i::i::i::iii:ii::::/:' :.:...<. i.:-:::i.i! ::::!::: i(.:.. :i:: :':.. i:. :::: ..i.:.i i: :i:. ii:!::iiii!ii::iii:.iii::i::!::i:.i::!ii::i::'!ii?::ii:::ii::iii:::i'iill :!??i::c. :.-:.:i: :iii::':!iii:::!:ii: ::::::::::::::::::::::::::::::: :i:ii/?. ::::::::::::::::::::: :i:::i:i:i'.::Y i:7:i :: ? :'i! ,ii:!i:'ili ii' ii!i':.!7,: L:':: i L :: · ~i. :! !::':.'.:. i.:il}: :i .: i:Y.: i :': :,.:i :ii.:is::f:iiii:!: 'i: .::i.:i.c:::-<Fiii::!iiiiiii:!i!iiii:::ii:::ilili:iiiiiii::ii:iiii:!i '"'"'::: '..':~00 ~6" W .5..3: ":~::':'":::::~:i~:::~':.~_2.Z8' ~ '::":~:':A~4. A,':"~9'"'S':":'"~::':~:.:~'~375.54 '~W '~82~">::~ 0:::?~ ': ..~. _ ,..: .. ~ _:~.~ ...... .. i ..... ~ ............ 3 ........ = ...... ~ ......... ~.. ~ ,.. .......... L_, · ' :' · ' .......... _ _ _ _ .. i __ ~4.0~] S 60 42 W 52 40 4053 12 15o~,.77 S . O. 46 _ . . ~,.05 W 2904 66 ~c,00 S 61 6 W 51 52 411.4.3:_~ 1624.'~"~' ~._~ S 2514.14 W ~9~:3.73 0.86 5600 S 61 36 W 50 32 4176. ~8 16~0 .:, '~ ~-~=A'~,~'~. W ~t61 .67 1 . ~: .................. · ~9 . :~.:..] ~ ...... .~ ~, · .~o ~.o 05 · ic?:~:~:..:'::~::.:.:.~:.::..::5700 S 6'1.~::30 W 4.~..:~ .:~.::,:.~.~41.~4 16..~,1c~ S...:...::...264..~0 W ................ ~ ~ ~ ~ ~ ~ ~ .:.:.:::~.:]~ :.~ 5900 S 61 48 W 48 28 4372.61 1769.77 S 2782.58 W 3289.08 0.46 6000 S 62 12 W 47 44 4439.3'~ 1804.71 S 2848.29 W 3363.51 0.78 6100 S 62 30 W 46 58 4507.14 1838.84 S 2_~_1.,_~L, 44_W_ 3437,05 0.8~_ iii::i:::i~i::,ii::::i, iii.i.::.i.iii!:!:ii!i::iii:"i:'~'~,' · .i ~..:''' '~ ' ~:~:.~:'. ::.:,:'' : ::::~:~::~:~:~K :';;, ~ : P : "~!~':~::"'"~ ~ ~::::'~.~,:::. ':~::.~:::::-:~ .... ~ ~ ::: ~:~:~:~:~:~:~:::~::~:~:~:::~:~ 0o.: ~..: :::.~: ~..6 3 I ~.::.::W :.. ~. :~:6.. ~.1... ~.: ~:::::..~:~:~:~5 ~5, .:~ 8 · :~:~ ::~.~.':~::~.~I 87~,.: 0~. ::. S.~.::. ~.:~.~: ~:~ :.~ 978 ...15 W · 0.50 ~. 76 . ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ....' c~ ..'.':::~,: ~' .... ?....~'." .....~:::.'.:.~:...~; ......... :::::::::::::::::::::::::::::::::::::::::::::: ============================== ..... : .... '.:'::' ....... :::':.'.-.:~:~.:.~: :.~.::.::~ ~.'.:. -T~ .... · ~ ~ .' · ~.:~.~:~:.~.:~:::~:~:~&~ ~0 -~ ::60 :,4.W ..:.~::~,...~5...::...:.~.~:~.:::~4~. 3~ 6400 S 64 6 W 44 27 4716.18 1934.97 S 3105.90 W 3652.07 0.97 6500 S 64 36 W 44 13 4787.71 1~65.22 S 3168.8~ W 3721.88 0..42 . 6600 ...... S 65 ~ W ~.3 2~. : .... ~859.85 1~94.65 .S 3231.57. W 37~1.02 ..... :::::::::::::::::::::::::::::::::::::::::::::::::::::::: .:::::'::S:: :65 48. W ..4:2.41:: '-..::::::~32.92 '.: :~::~::::::.:~'::'2023.:'02 · S.: ..:.:.~:::..::..:~:~::32~3.67 W 385~. 14 0:~:89 ., ........... · .......... ~00_...._&7..~~_-:A1.__47._._. 5006._9~_.. .':....'.~0_4~..55.__.~ - .' .... o55.41---.-~ .... 39~6.0o.. 6900 S 67 48 W 40 55 5082.04 2074.57 S 3416.55 W 3991.77 0.87 7000 S' 67 54 W 39 34 5158.37 20~8.92 S 3476.37 W 4055.'B~ 1.35 · ~:~::~:~:~:~:::~.::~.::~:~ ~20:o.~':~'~:S ,.67 .~.2'~.~:W ..:c~7 ':59 ~:~'::~::SS ~4 ;~s2. ~:~214~:-::7~::' s.? :~~. .~:~:: :::::~s5~2.07 :. w 4 ~ ~0.54 " 7400 S 67 30 W 36 13 5474 03 2193 08 S 3703 17 W 4300 31 0.70 7500 S 67 12 W 34 25 ~ ~_,~,. 63 2215.34 S 3756.52 W 4357.84 1.80 ..... 7~00 S 66 42 W 33 1~ ...5638:.65. 2237~!~ $ ..... 3807~0 W .._4413~33 1.!3 :::. ]:~: ..~ : ~ ~ :.L~ ~ ~!:::.::. -- . ,~":~::"~' · .:..'.' A-12 (SEC 5 T11N RIOE) JANUARY 3, 1982 TOTAL D ! RECT ! ON ANGLE . VERT ! C~]"UDE~_DERAR-T_UF-,IE__ VER~T/~G__ ' . .... '-- - ~';J="-' 27 W 4569.98 I O0 7900 S 66 30 W 30 13 5894 08 22~¢J ';,8 S ,.,-~.~. · 8000 S 66 0 W 29 50 c,~,~,.,='~R"'. 662~1~.42_ S 39~8.07 W 461~.85 0.45 8]~00 S ~ 54 W 2~ 52 6067.40 2~4~. 10 S: 4~..~~_. 466~.50 0.55 ............ ~,..:~.:.._~:,.....~ ......~z..._~ ...... ..'~..:o · ..... =_::.'.:.~o.z~...~o ._ S .............. ~ 130, ~0 N ..... _~.765.30 . 8400 S 70 48 W 25 13 6332 45 '~"~"-'~. . ~.:~._, 68 S 4172.14 W 480'~. 26 2.86 ~._,o0 S 71 24 W 24 10 6423.31 24.09.zl S 4211.66 W 4850.47 1.08 ._~ 8~.00 S 72 .0" ~' '~ '~' '" ~'~' '~"'~' ~ o'=, .-' ........ ............. . ~ ~. ?~.~ .... ...=?~l~,fo ........... z~zz .... ~, ~. 425.0~~_ 48~0.A 0.60 · ~::8700 ::~S '..74 .:E:6..:W :~ :::.22:: ~26. :.:::.~606.76.::.~:::::,::;i 2433..19..S · ::.:...: 4287. .57.. ::W,~ ~928.67.::::::.:~t THE DOGLEG SEVERITY IS IN DEGREES PER ONE HUNDRED FEET. LD ISF LACEI~IENT....I.~ ...... 4. ~..~..~ .-FEET, .--,-IN .:T-HE..--:D I REt;TI.ON BOTTOM HOLE DISPLACEMENT I:_=: RELATIVE TO WELLHEAD. VERTICAL ::,EL. TION Io REL. ATI VE TO WELLHEAD. suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. /~#C~ #~,,p,~,,,-,,,, '/,,4- Operator, We~l Name and Number Reports and Materials to be received by: Date Required Date Received Remarks ,, Completion Report Yes ~ ..... ~- ,7/.._.00 Well History Yes ~.~" ~ ~--'~- Samples .MuS.~,o~ . ., ,4/~ ?f , · · Core Chips ~ . ., "~'~'~'~' Core Description', ' ,/'~/~ ,,,~,-e_.. . ~ .~. , , Registered Survey Plat,~,,~ _ __~_: ........... _~ ................ ~,~ Yes tl,-/~ ~/ dK' ,, Inclination Survey /~ ~ .. ,~.. DirectiOnal Survey V~'. ~ - ~,/ / --- / ~22.-' ~ / Drill Stem Test Reports ,,"~'"'d~¢- Production Test Reports ye .S' ~.-.~ ~Z--'~ ~ ., L~..~e. , Logs Run, Yes ~__.~_ ........ .~..~< ..~. ,-z--- ~,.~--.o°~- Digitiz~ ~ta ARCO Alaska, Inc. Post Office Bo~ Anchorage, Alaska 99510 Telephone 907 277 5637 Jan22ary. 25, 1982 Mr. Lonnie Smith State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Dear Si'r' DS 11-5 DS 14-12 DS 11-6 DS 14-26 DS 12-7A DS 15-14 DS 12-8B DS 15-15 DS 13-10 DS lA-12 DS 13-19 DS B-11GI DS B-8 Enclosed please find the. Well Completion Reports for the following drill sites' 11-5, 12-7A, 12-8B, 13-10, 14-12, 15-14, as well as an up-dated Completion Report for DS B-8. Also included are the Monthly Drilling Reports for drill sites' 11-6, 13-19, 14-26, 15-15, lA-12 and B-11GI. Sincerely, P. A. VanDusen District Drilling Engineer Enclosures PAV/GA:ss ARCO Alaska. Inc. Is a Subsidiary of AtlanticRichfieldCompany { ~ STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC( .~IISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 81-178 3. Address 8. APl Number P. O. Box 360, Anchorage, Alaska 99510 50-029-20688 4. Location of Well at surface 929' FSL 481 FWL Sec 5 TllN R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 100 ' R_EB 6. Lease Designation and Serial No. ADL 25647 ALK 465 9. Unit or Lease Name Kuparuk River Field 10. Well No. J_A-l?. 11. Field and Pool Kuparuk River Field Kuparuk Oil Pool For the Month of. December ,1981 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well @ 2330 hrs, 12/22/81. Ran & cmtd 10-3/4" casing. 8456' as of 12/31/81. Drilled 8-3/4" hole to See Attached Drilling History 13. Casing or liner run and quantities of cement, results of pressure tests 16" 65# H-40 conductor to 80'. Cmtd w/200sx Permafrost 10-3/4" 45.5# K-55 casing to 2721. Cmtd w/ll30sx Class "G" and 250sx Arctic Set 14. Coring resume and brief description N/A 15. Logs run and depth where run DIL/SP/GR/SFL/FDC/CNL/Cal to 8399'. 1 6. DST data, perforating data, shows of H2S, miscellaneous data 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. F /~'~2 nior Dr En ' SIG~ED , TITLE ~ illing gineer DATE NOTE--Report on this form is required f~ each calendar month, regardless of the status of operations, and must be filed in duplicate with ~he Alaska Oil and Gas Conservation Commission by t~e 15th of the succeeding month, unless otherwise directed. Form 10404 Submit in duplicate Rev, 7-1-80 lA-12 Drilling History NUhydril and diverter system. Spudded well @ 2330 hrs, 12/22/81. Drilled 13~" hole to 2755'. Ran 65 jts 10-3/4" 45.5#/ft K-55 casing w/shoe @ 2721'. Cemented 10-3/4" casing w/ll30sx Class "G" lead cement followed by tail of 250sx Arctic Set. ND hydril and diverter system. Instld 10-3/4" packoff & tstd to 2000 psi - ok. NU BOP£ & tstd to 3000.psi - ok. Tested casing to 2000 psi - ok. Drilled FC and cement. Tested casing to 2000 psi - ok. Drilled FS and 10' new form. Tested new form to 12.5 ppg, E~W - ok. Drilled 8-3/4" hole to 8400'. Ran DIL/SP/GR/SFL/FDC/CNL/Cal. Continued drilling 8-3/4"'hole to 8456'-, as of 12/31/81. Deeember 15, 1951 ~ir. D. S. Sm i lay Senior Drilling l/ngineer ARCO Alaska, Inc. P. O. i~,ox 3'60 Anchorat~e, Alaska 99510 l/uparuk River Field No. lA-12 ARCO Alaska, Ina. Pe~mi t No. 81-178 Sur. Loc.: 929~FSL, 491*FWL, Sec §, TIlN, R10E, ~. Bott~ole Loe.~ 1607'~, 695'F~, See 7, TllN, RIOE, ~. Dear I/Ir. Smi I ey~ Enclosed is the approved applieation for permit to drill the above re forehead wel I. Wel 1 samples and a mud lot~ are not required. A continuous directional survey is required as per 20 AAC 2§,§50(b)(5). If available, a tape containini~ the digitized lo1~ information shall be submitted on all lo//$ for copying except experimental lot~s, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainat~e systems have been classified as important for the spawnint~ or mi~ratton of anadromous fish. Operations in these areas are subject to AS 16.50.$?0 and the ret/ulations promult~ated thereunder (Title 5, Alaska Administrative Code). Prior to commeneint~' operations you may be contacted by the Habitat Coordinator*s office, Doper truant o f Fi sh and Game. Pollution of any waters of the State is prohibited, by AS 46, Chapter 3, Article ? and the re!/atlation8 promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~tr. D. S. Smi ley -2- Iluparuk River Field Bio. 1A-12 December 16, 1981 commencing operations you may be contacted by a representative of the Department of Bnvironmental Conservation. To aid us in scheduling field work, we would appreciate your ,notifyinl~ this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the Commission may be pz'esent to witness testin~ of blowout preventer equipment before surface casing shoe is dr i I 1 ed. In the ewent of suspension or abandonment, please i~ive this office adequate advance notification so that we may have a witness present. Very truly you~,s, Ii, ltami i ton Chairman of BY ORDER OF. THE CO~MISSION tlaska Oil a (las Censer-cation Commission Department of l~ish · Game, Itabttat Section w/o encl. Departtae'nt of l/nviron~ental Conservation w/o/encl. It[Iii ~.be SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-51 ! 1 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 December 11, 1981 CC #40,276 (B12) Mr. P. B. Norgaard, President Arco Alaska Inc. P. O. Box 360 Anchorage, AK 99510 Letter of Non-Objection ADL-25647 Kuparuk Project - Drill Site A, North Slope, Alaska Dear Mr. Norgaard: Arco Alaska Inc., by letter of December 7, 1981, has requested concurrence from Sohio Alaska Petroleum Company for the drilling of deviated well Kuparuk lA-12 (SeCtion 5, Township 11 NOrth, Range 10 East, Umiat Meridian, 929 ft. FSL, 491 ft. FWL) with targeted bottom hole location at 1607 ft. FNL, 695 ft. FWL, Section 7, T~wnship 11 North, Range 10 East, Umiat Meridian. ~ne letter of non-objection has been requested pursuant to 20 AAC 25.050. This is to advise y~u that Sohio Alaska Petroleum Company does not object to the drilling of the proposed well, Kuparuk lA-12. Sohio's concurrence to the drilling of well Kuparuk lA-12 is with the understanding that Arco Alaska, Inc., Sohio Alaska Petroleum Company and other effected Working Interest Owners will proceed in good faith toward an equitable unitization of the Kuparuk reservoir and that such unitization will be achieved prior to the commencement of production from this well. PJM:PR:ip Sincer ely, Paul J. Martin Assistant General Manager (Operations] cc: Mr. P. Hardwick Mr. J. 'Pawelek RECEIVED DEC 1 5 1981 Ahska Oil & Gas Cons. Cornmissiort Anchorage · BP Alaska Exploration Inc. One Maritime Plaza, San Francisco, California 94111. Telephone (415) 951-2332 ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 December 8, 1981 BEG 1~ O.'E',Ti-I ALAS~-~k Attn: Mr. Sylvester R. Jaime, Landman Re: Letter of Non-Objection ARCO Alaska Lease ADL 25647, ALK 465 Gentlemen: We refer to your letter of December 7, 1981, in which you advised us of your intention to drill Kuparuk Well lA-12, on Kuparuk Drill Site A, with the following locations: Surface Hole Location: 929'FSL, 491'FWL ,, Sec. 5, TllN, R10E, U.M. Bottom Hole Location: 1607'FNL, 695'FWL Sec. 7, TllN, R10E, U.M.~ BP Alaska Exploration Inc., as an affected Lessee of Record, hereby confirms that it has no objections to the application for Permit to Drill or Deepen the above well. This Letter of Non-Objection is, however, written on the understanding that timely and bonafide mea- sures to unitize the Kuparuk Reservoir in a fair and equitable manner are adopted by the parties involved, such that said parties may agree upon the terms'of such unitization and their respective rights and ob- ligations therein, prior to the c~mmencement of any production from the Kuparuk Reservoir. You~ve ry truly, P. Hardwick President PH:sm cc: Mr. G...J. Abraham, Sohio, SF RECEIVED DEC 1 5 1981 Oil & Gas Cons. Commissi0~ Anchorage ARCO Alaska, Inc.( Post Office B~,,, 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 14, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Sir' Subject' DS 11-2 DS B-8 DS 13-8 DS B-10 DS 14-15 DS lA-12 DS 14-16 Enclosed please find the following' 1.) The Completion Gyroscopic Surveys for DS 11-2, DS 13-8, DS 14-15, DS 14-16, DS B-8 and DS B-10. 2.) The letter of 'Non,Objection" for the Permit to Drill appli- cation on Kuparuk well lA-12. Sincerely, P. A. VanI~sen District Drilling Engineer PAV:ss Enclosures ARCO A~aska, Inc. is a subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office B~, ~60 Anchorage, Alaska 99510 Telephone 907 277 5637 November 24, 1981 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Kuparuk 1A-12 Dear Sir: Enclosed please find the following: · 2. 3. 4. 5. 6. 7. The application for Permit to Drill Kuparuk lA-12 and a $100..00 check for the application fee. A diagram showing the propos.ed horizontal and vertical projections of the wellbore. An as-built drawing of "A" pad indicating the proposed surface location. A proximity map indicating the relative locations of Kuparuk wells lA-4, lA-5, lA-6, and lA-11. A determination of maximum pressure to which BOP equip- ment could be subjected. A diagram and description of the surface 'hole diverter system. A diagram and description of the BOP equipment. In addition, please note that this well's bottom hole location will require letters of Non-Objection from BP Alaska Exploration Inc. and Sohio Alaska Petroleum Company. A copy of the replies from the affected operators will be forwarded to your office as soon as possible. If you should have any questions, please do not hesitate to contact me at 263,4272. Si ncerely yours, D. S. Smiley Sr. Dril 1 ing Engineer DSS:TJB: 1 tc Enclosures RECEIVED NOV ? 198! Oil & Gas Cons. Commis$ior~ Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA ,L AND GAS CONSERVATION C MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [] lb. Type of well EXPLORATORY []o SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL [] SINGLE ZONE~rl DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P.O. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 9. Unit or lease name 929'FSL, 491'FWL, Sec. 5, TllN, RIOE, UM RE~EIVED Kuparuk River Field At top of proposed producing interval 10. Well number 1320'FNL, 1228'FWL, Sec. 7, TllN, RIOE, UM lA-12 At total depth NOV 2 7 1981 11. Field and pool 1607'FNL, 695~'FWL, Sec. 7, TllN, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation~r~i~.r~i ~:>..~aS. ~,0,'~$. COl,- m~oo,.K, upa ruk Ri v er F i el d 61'GL, 66'PD, IO.O'RKB I ADL 25647 ALK 46~ncn°rage '~°'V~uparuk River Oil Pool 12. Bond information (see 20 AAC 25.025) Type Statewide Suretvand/°rnumberFed Ins Co 8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 30 mi NW Deadhorse miles at TD 695 feet 1A-I~eu is 120' Fa .~urfac¢_ .feet · 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 8894' MD/6563 'TVD feet 2469 12/19/81 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures ~2~))'0 psig@ ~)[}O~- Surface KICK OFF POINT 1050 feet. MAXIMUM HOLE ANGLE' 49 oI (see 20 AAC 25.035 (c) (2) 3067 ..psig@ 5(}05 ft. lX~K(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SETTING DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) 24" 16" 65# H-40 Welded 80' Pad I Pad 114' ~ 114' +200 CF 13½" 10-3/4 45.5# K-55 BTC 2967' Pad , Pad 3002' , 2700' l134sx Fondu + 250sx ' ' Pad 8894' 16463 996sx Class "G" 8~4" 7" 26# K-55 BTC 8859 Pad I ~ I I I ~ I 22. Describe proposed program: ARCO Alaska, Inc. proposes to drill a Kuparuk River Field, Kuparu.k River Oil Pool devel- opment well to approximately 8894'MD, 6563'TVD. Selected intervals will be logged. A 20" x 2000 psi annular, diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4'.' surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will 'be 3000 psig. Expected maximum surface pressure will be 2570 psig based on cooling of a gas bubble risi.ng.at constant volume. The .well will be completed with 3½" 9.2# J-55 buttress tubing Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. 23. I hereby certify that the foregoing is true and correct to the best of my knowledge TheSIGNEDspace belowS' <~for~_ TITLE SR Drill lng Engineer CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number I--lYES ~NO []YES ~i~.N O ~.YES Permit number Approval date ~1-/~ 8 12/16/81 I SEE COVER LETTER FOR OTHER REQUIREMENTS BY_~ ,COMMISSIONER DATE lle_-c_m~_be.r 16, 1981' APPROVED by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 Iff ............. I L~GLND ~ N,.,TE3 '~' PERMAN~N3 5t;~VEY L.C,~"~N M~h ~MENTS ELEVAIlONS ARE BASEL ON SOHf~-BP VERTIC~. DATUM ;;'N, UC:~ , -E' .N ~E~..S 4-7 NtT ~ET TH,q KUPARUK PROJECT DRILL 31TE "A': ,, .',b/HI .vF ANCHORAGE , ALASKA 9/6/8~ LMH DATE: ,~N 19BO' ! SCALE: 1', lO0' 'l~'''"/'' I .... Io"A"" """" ' '''" I c.~,,, .,, ..,. ATLANTIC RICHFIELD COMPANY NORTHAMERICAN PROOUCING DIVISION GROUP ENGINEERING GENERALDA/LAS I TEXAS BOMHOFF 8 ASSOCIATES, INC. -..j ANTICIPATED PRESSURES Expected reservoir pressure in the Kuparuk interval has been determined to be 3067 psig from RFT & pressure buildup~date. This pressure @ 5805' SS = 5905'TVD will be balanced by 9.99 ppg mud wt. Normal drilling practice calls for 10.5 ppg wt prior to penetration and during drilling of the Upper Kuparuk and remaining intervals. This will result in a 157 psi over- balance. It is anticipated the surface BOPE equipment could be subjected to a maximum of 2570 psi during drilling operations. Derivation assumes a gas kick at reservoi'r temperature and pressure (160OF, 3067 psi), gas migration to the surface w/o expansion, and cooling to 60OF cellar temperature. This is well below the 5000 psig BOPE worki.ng pressure and less than the 3000 psi weekly test pressure. Pi = pressure initial (reservoir) Ti = temperature initial (reservoir) Vi : volume initial (.reservoir) Pf = pressure final (surface) Tf = temperature final (surface) Vf: volume final (surface) P~'V* =PV Since Vi : Vf ie no expansion Pf = 2585 Psia = 2570 psig NOV£ ? i98t Oil &.Gas Cons. A~C~orage ! Surface Div~:r System 1. 16" Bradenhead. 2. 16" x 20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. lO" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that 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 over- ride and close, ball valve to upwind -diverter line. Do not shut in well under any circumstances. 16" Conductor oil ~ p~. Cons. Co . '-. ~aCflor~#o ~r~issior~ · 5/S" :.gOO PSI ,~?,RA -]eP ~TAC;-( IRNNUL~ PP,~'v'~NTCR . [) , BLIND RRHS --~ ,)8 ) .---= RR~S ) 7 ( J-~PiPE RRM$ J 5 ( , ) e 1. 16" Bradenhead 2. 16" 2000 PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. lO" 3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI pipe rams 6. 13-5/8" 5000 PSI drilling spool w/choke and kill lines 13-5/$" 5000 PSI pipe rams 13-5/8" 5000 PSI blind rams 13-5/8" 5000 PSI annular ~e Je ., 4. 5. 6. 7. 8. ACCL?:ULATQ.I CAP~C!TY T-_ST CHEC:< AND FILL ACCUMULATOR RE-~ERVOI2 TO PROPER LEVEL WIPe( HYD.",AULIC FLUID. ~C~,,ULAICR PRESSURE IS 3000 PSI ASSURE THAT ....... - WITH 15CO PSI CO'~/~;STREAI.I OF THE REGULATOR. OBSERVE TiNE THEN CLOSE ALL UNITS SI~.!ULTANE- OUSLY AND RECgRD THE TIME AND PRESSURE RE~-tA[~I- I~G AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECSRD ON IADC REPORT. THE ACCEPTASLE LO'JER LIMIT IS 45 SECC::DS CLOSI;',G TI~IE AND 1200 PSI RFJ4AJ,II,,~ PRES£~JRE. 13-5/8" BOP STAC:< TEST ,,,D MANIFOLD '~ITH ARCTIC DIESEL. FILL BOP STAC:< '" CHEC:< THAT ALL HOLD. CC'JN SCREXS ARE FULLY RE- TRACTED. PRECETE.::,II~IE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLXEAD. RUN IN LOC,~ DOWN SCF, E'~iS IN HEAD. CLOSE ANNULAR PRE?ENTER AND C:qOKES AND BYPASS VALVES 0:I MANIFOLD. TEST. ALL CC:.~PO:JENTS TO 250 PSI AND HOLD FOR l0 MI~;UTES. INCREASE PRESSURE TO 1500 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. OPEN A,i,,UL,,R PREVENTER AND CLOSE TOP SET OF PIPE INCREASE PRESSURE TO 3000 PSI AND HOLD FOR lO MINUTES. CLOSE VALVES DIRECTLY UPSTRE;J.i OF CHOKES. BLEED D0~NSTRE,t~.! PRESSURE TO ZERO PSI TO TEST VALVES. TEST REJ. IAINING UNTESTED :.!ANIFOLD VALVES, IF ANY, ',~ITH 3000 PSI UPSTREA:'I OF VALVE AND ZERO PSI O0,,,STr~r.A,'t. BL£ED SYSTEM TO ZERO PSI. -. OPEN TOP SET OF PIPE P, ANS AND CLOSE 80TTO:'I SET OF PIPE .IAMS. INCREASE PRESSURE TO 3000 PSI AND HOLD FaR MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTC~.I SET OF PIPE RAniS. BACK OFF NING JOINT AND PULL OUT OF HOLE. CLOSE .~LIND RA;.IS AND TEST TO 3000 PSI FOR 10 BLEED TO ZERO PSI. 12. OPEN BLIND RA;'IS ANO RECOVER TEST PL~. MAKE SURE HANIFOLD AND LINES ARE 'FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN ~RILL~NG POS I T I ON. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCXS A~ID INSIDE BOP TO 30~0 PSI WITH KGC;:EY PU.NP. 15. RECC'RD TEST I:;FO.~.~TIO:I 0:1 BLC'~OUT P~EVE:ITEI~ TEST FOPJ. I SIGN A:;D SEND TO ~RILLING SUPE.t- VISOR. 16. PERFCP~I CC;'.PLETE BOPE TEST 0;~CE A '4EE'.4 FUNCTIONALLY CPE.~ATE BOPE C, AILY. 7 · I GoAI..D': i"'- ~00~ ,T :WELL A1 Y = 5,971,467.25 x = 540,~78.17 LAT = 7~°19'58.741'~ LONG =_ 149°40'26.679'' : WELL A2 ~ = , .5,971,34'6.82 X = 540,178.32 LAT = 70°19'57.557'' LONG = 149°40'26.693'' WELL A3 Y = 5,971,227,31 x = 5~0,178.51 LAT = 70°19'56.381'' LONG = 149°40':26. 707'' \ WELL A~' Y = 5,971,906-83 X = 540,1'78,52 LAT = 70°19'55 196'' LONG = 149°40'26.725'' o WELL A5 Y = 5,970,986.86 X = ~40,178.61 LAT = 70o19'54.016'' LONG = 149°40'26.741'' · WELL A6 Y = 5,970,866,70 x = 540,17-8.71 LAT = 70019'52-834'' LONG = 149°40'26-757'' ( TI INll .:::-~,~'-...,r '~,,! .. ','! HERE'~Y CERTIFY THAT I AM .' ',,- ,. ...%.~..~. PROPERLY REGISTERED AND LICENSED .... .;, ".'~::,. TO PRACTICE LAND SURVEYING IN '.. '.'] ~'_ ' ,', ·THE STATE OF ALASKA AND THAT ............ :,: ........... THIS PLAT REPRESENTS AN AS- ~C4- . ..... -' BUILT SURVEY MADE BY ME, AND ~/ ,~. ;. : ..... :,..,~,. ~ .~ THAT ALL DIMENSIONS AND 0THE~ .' ·., . -... -~ .. ~'. ,.' DETAILS ARE' CORRECT, .AS OF- . '.' ..-.' '? "' ' ' ~ . 'k .- ° ' ~.~'~ .~.- .. WELL A7 Y = 5,970,746.73 X = 540,178.55 LAT = 70°19' 51.654'' ......... LONG = 149°40' 26-781'' WELL A8 Y =- 5,970,626.78 x = 540,178.59 LAT = 70°19' 50. 475'' ~.~. ~OJ~G = 149°40'26.798' ,::r-/Fo ' NORTH AMERICAN ~RODUCING Dl¥1,.%lO~ ALASKA DISTRICT-- b ooA-I' I o'N A6- t~ bll I..T6 __ i i DATE: tDRA,,wiNG No: 10.2.60. · i _ _ I iii1! i ,'-- FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) L$c ,, ,)~ thru 8) le (3) Admin ?/~' %7'~/ thru 11) ? Company (4) .Casg ~ l/ 7~..7J8,1: (12 thru 20) Lease & Well No. (21 thru' 24) 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 .... 4. Is well located proper distance from Other wetls ............. 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 w~i; .. 2.2 .... 2252... e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20.' REMARKS 21. 22. 23. 24. (6) Add: ~~ ,~-7~&C 25. · · e· · · ® 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 b~rst. Is. this well to be kicked off from an existing wellbore ......... Is old wellbore abandonment procedure includ:d, on 10-403 .i. i i '[' Is adequate well bore separation proposed .~ .............. ~ . Is a diverter system required .................. . ~~.~ Are necessary diagrams of diverter ~d ~;~ ;~ip~;~; ~t;~h;~ ...: " Does BOPE have sufficient pressure rating - Test to ~90~ psig~~ Does the choke manifold comply w/API RP-53 (Feb.78) ................... ,., 2Very ~ Additional requirements ............................................. Additional Remarks: Geology: Engin~e/er ing: JAL ~ rev: 03/10/81 INITIAL ..... ' "GEO. UNIT bN/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No 'special'effort has been made to Chronologically organize this category of information. LI6 TAPE YE~IfICATION LISTING LvP OOq.~{05 '¢ERIFICATION LISTING PAGE SERVICE !'~AME :SER¥IC DATE :,~2/03/ % ORIGIM : REEL !q~%~,lE ;REEL ID CONTIfi'UATION ~ :01 PREVIOUS REEL : C05;aENTS :REEh COMMENTS ,~ q,~o~~ HEADER SERVICE NAME :SERVIC DAT~i; :~J2t03/ ORIGIN :1070 TAPE ~,iA~aE :62447 CONTINUATIO~ ~ PREVIO~IS TAPE : CO~g)q~$ :TAPE COMMENTS FILE ~!A~E :SERVIC.O01 SER~'ICE NA~E : VERSIO~ # : DATE : MAXI~Uq LENGTH : 1024 FILE fYPE : PREVIOUS FILE ** i~'~7<]R~4ATION RECORDS CN : ATLANTIC RICHFIELD CO. Wk : A-12 FY : K(lPARUK RANG: TOWN: SECT: 5 COUN: NORTM STAT: ALASKA CTRY: USA M~';'a CO~,iTENT$ PRES: N ~.~01T47 RECORD TYPE 047 ** UNIT ~YP~ CATE SIZE CODE 000 000 022 065 000 000 004 065 000 000 008 065 000 000 003 065 000 000 003 065 000 000 001 065 000 000 012 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 OO7 O65 PAGE ** R~CORD TYP~ 9~7 ~$ RECORD TYPE 047 *<>*<>*<>*<>*<>*<>*<>$<>*<>*<>*<>*<>*<>*<>$ * PACIFIC COAST CO~PtJTI~G CENTC~ * , *<>*<>*<>*<>*<>*<>*<>,<>*<>,<>*<>,<>,<>,<>* COmPAnY WELL FIELD COUNTY STATE ATLANTIC RICHFIELD CO. KUPARUK N. SLOPE ALASKA *<>*<>*<>*<>*<>*<>*<>~<>~<>,<>*<>~<>,<>$<>* JOB # 10707,62447 OIL RJ:~ ~O : ONE LOGG6D D~T~ : 30-DEC-81 CASING DRILLER : 2721" BIT $IZ~ : 8.75 FLUID TYPE : DEXTRiD DENS. : 10.3 vISC, : 39 Ph : 10,5 FLUID 5086 : 6.4 ML R~ ~ MEAS. TEMP. : 4.050 g 70 F LVP 009.i{05 VERIFICATION 5£STING PAGE RMF e 14gAS. TEMP. : 4.400 ~ 70 R~C ~ ~EAS. TEMP. : 3.550 ~ 70 R~ ~ ~HT ~ 2.196 ~ 135 MATRIX : SANDSTONE ** OATA FORMAT RECORD ** ENTRY ~5OCKS TYPE SIZE 4 8 4 9 4 0 DATU~ SPECIFICATION MNE~ SERVICE SERVICE UNI% API ID ORDER ~ DEPT FT 0 SFLU OIL OHMM 7 IL~ OIL O~M 7 ILO OIb OH~M 7 SP OIL ~V 7 GR :)IL GAPI 7 NPHi ~DN PU 42 RHO~ ~DN G/C~ ~2 GR ?DR GAPI 42 CALI ~DN IN DRHO 7D~ G/C~ 42 NRAT FDN 42 NCNb ~DN 42 FCNL ~'DN 42 AP TYP REPR CODE 73 65 66 I API API FILE E CLASS NOD NO. 0 0 0 0 0 0 0 0 0 0 0 0 12 46 0 0 9. o o 3! 3z 0 0 68 2 0 0 35 I 0 0 31 32 0 0 2~ 3 0 0 44 0 0 0 42 1 0 0 34 92 0 0 34 93 0 0 ENTRY 1 60 .lin 0 SIZE 4 4 4 4 4 4 PROCESS SAMPLE REPR bEVEL CODE 0 1 68 0 ~ 68 0 68 0 1 68 0 i 68 0 i 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 i 68 4 0 i 68 4 0 1 68 4 0 I 68 4 0 1 68 DATA DEPT 8413.000 SF[,U SP -13.016 GR GR 97.375 CALI NCNb ]944.000 FCNU DEPT 8400.000 SFLU SP -t8.547 GR GR 97,375 CAbl NCNb 1944.000 FCNL DEP~ 8300.000 SFLU $~ -19.969 GR GR 84.188 CALI 9 5O g 50 2.750 7.375 NPHI 9.180 DRMO 3.750 2 754 IbM 7:375 NPHI 9. 180 DRHO 3,750 6.570 4.188 NPHI 9.969 DRHO 2.303ILD 2.225 42.871 RHOB 2.406 o,IgO .' NRAT 3.52i 2,303 ii~D 2.205 42~871 RHOB 2.406 0.190 NRAT 3.521 5.512 ILO 5 051 30.029 RHOB 2:455 0.101 NRAT 2,863 NCNb 2528.000 DEFT 8200.000 SFLO SP -9,039 OR GR 81,3t2 CALI NCNb 2660.000 FCNb DEFT 8100.000 8FLU SP -21,953 GR GR 75,000 CALI NCNb 2972.000 FCNL DEPT ~000,000 SFLU SP -55,~44 GR GR 55,406 CALI NC~L 3U72.000 FCNL DEP~ 7900,000 SFLU SP -16.016 GR GR 105.625 CALl NCNb 1867.000 FCNL DEFT 7800,000 SFLU SP -28.891 GR GR 109.875 CALI NCNb 1987.000 FCN5 DEFT 7700.000 SFLO SP -35,250 GR GR 181.875 CALl NCNL 2134.000 FCNL DEFT 7600.000 SFLU SP -23,266 GR GR 153,i25 CALI NCNL 2104.000 FCNb DEFT 7500.000 SFL~ SP -2i,609 GR GR 131,875 CALl NCNb 2100.000 FCNL DEFT 7400.000 SFL~ SP -41.281 GR GR 94.188 CAbI NCNb 2692,000 FC~L D~PT 7300.000 SFLU NCNb 2200.000 FCNb DEFT 7200.000 SFLW SP -18,~69 GR 85 1 9~ 5.000 4,961 1,312 0,266 3,500 75 000 t0~250 916,000 25 55 9 8~5 i 105 418 2 109 11 5O5 3 181 tO 605 3 11 654 3 131 10 544 4 94 835 2 116 10 491 3 118 .875 ,.~06 ,96i .000 .702 ,625 .398 .500 ,174 ,875 .727 .000 .066 .875 ,961 .500 ,734 ,125 .289 ,500 158 2875 .758 ,500 ,5!7 .188 ,523 ,500 .9q8 .688 .297 .000 ,348 .500 DR~O IbM DRHO NPHI NPHi DRb~O DRHO NPHI D~HO DRHO !LM NPHI DRMO !L~ NPHI NPHi 3,932 IbP 29,980 RHOB 0,100 NRAT 6,594 ILl) 30,420 RHOB 0,023 NRAT 25,188 ILL 32,422 RHOB -0,:039 NRAT !.498 48.779 RHOB 0,036 NRAT 2,037 -999,990 RMOB 999000,000 NRAT 2.645 -999,990 RHOB 999000,000 NRAT 2,947 '999' 990 RHOB 999000..000 NRAT 2.389 IbP -999.990 RMDB 999000.000 NRAT 3,416 ILD -999,990 999000.000 NRAT 2.211 -99~.990 999000,000 ~RAT 2,660 '999,990 PAGE 3.705 2,445 2.885 6.527 2.410 2.912 32.531 2.494 3.02i 1,425 2.309 3.994 2.010 999000.000 3.508 2.559 999000.000 3,281 2,82~ 999000,000 3,273 2.361 999000,000 3.789 3,172 999000.000 2,898 2 018 999000:000 3,754 2.bll 999000.000 LqP 009.,'~05 VERIFICATiO'.',~ LISTING PAGE 5 DEPT NCNb SP G~ SP GR DEPT SP GR NCNb G~, DEPT GR NCnb DEPT SP GR DEPT S? GR OEPT SP GR ~CN L DEPT SP G~ NCNb DEPT 118,500 CAbI 247~.000 FCWL 7100.000 SFLO -22.469 GR 119.312 CAbI 2226.000 NCNb 7000.000 SFbO -21.~22 GR 180.250 CALl 1943,000 FCNb 6900.000 SFbU -31.094 GR 169.375 CAbi 2418.000 FCNL 6800.000 SFLU -3~.719 GR 206.875 CALI 2208.000 FCNb 6700.000 SFDU -17.469 GR 190,375 CAbI 2264.000 FCNL 6600.000 SFLO -14.609 GR 91.125 CAbI 271~.000 FCNO 6500.000 -20,406 GR 84,188 CALl 2686.000 FCNL 6400.000 SFbU -33.719 GR 91.750 CALX 2666.000 FCMb 6300.000 SFLJ -38.656 GR 95.813 CALI 2526.000 FCNb 6200,000 SFbD -30.750 GR 79.063 CAbI 2998.000 FCNb 6],00.000 I0 634~ , 119. 12. 666. , 1~0. 10, 4~5. . 169, 10. 709. 206. 54.4. 190. 12, 570. 91. 11. 725. . 84. 10. 795. . 91. 11. 784. . 95. 11. 670. . 79. 1i. 804. · 859 50O 3!2 586 5O0 510 25O 641 750 12i 375 219 500 465 875 57O 0 O0 449 375 367 000 078 125 500 854 188 992 000 516 750 461 000 309 813 172 500 811 063 016 50O 314 ORHO 999000,000 NRAT 3,289 IL~i 2,990 iLD 2.951 MPHI -999.990 R~OB 999000.000 DR~O 999000,000 NRAT 3,i62 IbM DRMO IbM NPHI IbM NPHI DRHO Ib~ NPHi DRHO IbM DRHO 1,98i ibD -999.990 RHOB 999000.000 NRAT 2,105 999000,000 3,668 . 1.813 ILl) 1,938 999.990 RHOB 999000,000 999000.000 NRAT 3.223 2,781 '999,990 999000.000 NRAT 2,:723 999000,000 3,543 3,191 IbP 3a 135 -999,990 RHOB 99900u : 000 999000;000 NRAT 3.75~ 2,375 IbD -999,990 ~HOB 999000,000 NRAT 2.373 999000.000 3,236 IbM 2,719 ILD 2.678 NPHI -999.990 RHOB 999000.000 DRHO 999000,000 NRAT 3.068 IbM NPHI DRHO IbM NPHI DRMO ~PHI DRHO IbM 2.523IBD 2.473 -999.990 RHO~ 999000.000 999000.O.OOMRAT 2.965 2.355 IbD 2.287 -999.990 RHOB 999000.000 999000,000 MRAT 3,260 2,855 -999,990 RHOB 999000.000 NRAT 9990002:818 000 3,193 2.354 ILD 2,389 LVP DEPT SP GR DEPT SP GR NCNL DEPT SP GR DEPT SP GR NCNL SP GR SP GR DEPT SP NCNb DEPT SP GR NCNb D=PT SP NCNL DEP? SP GR NCNb ~ VERIFICATIOf'J -22,64i GR 89,063 CALl 2~B6,000 FCNL 6000,000 SFLU -23.06B GR 90,125 CALl 2336.000 FCNL 5900.000 SFLU '27.094 GR 75,063 CADi 2506,000 FCNL 5800,000 8FbU '28,q53 GR 75.000 CALl 2596.000 FCNb 5700,000 SFLO -33.719 GR 85,500 CALl 2400,000 FCND 5600,000 SFLU -29,0!6 GR 98.250 CADI 2330.000 FCNL 5500.000 SF~U -35'156 GR 100,625 CALl 2470,000 FCNL 5400.000 SFLU -36,938 GR 88.688 CAbI 2634.000 FCNL 5300,00o SFDU -28.453 GR 80.438 CALl 2602.000 FCNb 5200,000 $F50 -29,641 Ga I27,938 CALl 2320.000 FCXL 5100.000 SFbti -33.094 GR 99.250 CA~I 231o.000 FCNL 89.063 11.273 637.000 2.3~6 90.i25 11.250 704.000 2.230 75 ~63 11:66 690.500 2.699 75.000 11.156 701.000 2.725 85.5OO 1i 3~4 752:000 2.102 98.250 11.266 654.500 3,125 100.6~5 I~.320 68 .000 4 91 11,203 800,000 3.379 80.438 11.~13 662.500 3.633 127,938 i3.250 632,500 2,591 99.250 13.23~ 589.000 DRHO NPHI DRHO IbM ~PHI NPHI DRHO IbM NPHI DRBO ILM NPMI ORHO NPHI DR~{O NPHI DRMO NP~iI DRHO DRHO -999.990 RHOB 999000,000 NRAT 2,449 -999,990 R.HO8 999000,000 NRAT 2,496 IbP -999.990 RHOB 999000~000 NRAT 2,816 ILl) -999,990 RHOB 999000,000 NRAT 2,793 ILP '999,990 RHOB 999000,000 NRAT 2,06i '999,990 999000,000 3,311 IbP -999.990 RHOB 999000.000 NRAT 4,258 -999,990 RHOB 999000,000 NRAT 3,830 IbP -999,:990 RHOB 999000.000 NRAT 3,611 -999.990 999000.000 NRAT 2.B3g -999,990 RHnB 999000,000 NRAT PAGE 999000.000 3.559 2 457 999000:000 3~203 2 596 999000:000 3.336 2,814 999000.000 3.381 2.803 999000.000 3,072 2.088 999000.000 3.453 3.307 999000.000 3.227 ~.227 999000.000 3.277 3,896 999000,000 3.629 3.68b 999000.000 3.148 2.971 999000.000 3.564 5VP 009.H05 VER1FICATIO~'~I 5iSTING PAGE 7 DEPT SP N C ~'~ L DEPT SP GR NCNL DEPT SP SP GR DEPT SP OEPT NCNL DEPT SP GR NC~L DEPT DEPT SP N C N 6 DEPT SP GR NCN[, DEPT SP GR NC~.~L 5000. 000 SFLU -43.375 GR 108.813 CALl 2344.000 FCigL 4900.000 $FLU -41.969 GR 96.250 CALl 2152.000 FCN5 4800.000 SFLU -39.969 GR 94.563 CALi 2194.000 FCNL 4700.000 SFLU -37.375 GR 89.375 CAbI 2050.000 FCNL 4600.000 SFbO -40.063 GR 83.625 CALl 2960.000 FC"4b 4500.000 SFLU -39.938 GR 75.688 CALl 2378,000 FC~b 4400.000 SFLU -3~.750 GR 79.188 CALl 2424.000 FCN5 4300.000 SFLd -5%.688 GR 63.09~ CALl 2444.0n0 FC~5 420O.000 SFLU -48,o25 GR 73.500 CAbi 2178.000 FC~L 4100.000 SFLO -57.469 GR 69.125 CALl 2~2q.000 FCNL 4000.000 SFbU -53.156 GR ~4.250 CALI 2272,000 FC~L 3.020 108.813 ~3.344 6O5.5O0 2.727 96.250 13 66~ 5'23'.000 3.330 94.563 13.578 583.000 2.975 89.375 13.$09 594.500 4.563 83.625 13.406 775.000 4.258 75.688 12.766 b48.500 5.2!5 79.i88 12.70~ 626.500 6.617 63.094 13.203 707.000 5.520 73.500 13.!09 537.000 10.906 ~0,500 12.6~8 629.500 7.063 88.312 12.4~4 652.500 I'LM ~PHi MPHi 3.289 ILL 3.473 -999,990 RHDB 999000 000 999(')00,000 NRAT 3' :414 2.828 ILD 2.902 -999.990 RHOB 999000,000 999000.000 NRAT 3.365 IbM 3.631 IbD 3.754 NPHI -999.990 RHOB 999000.000 DRHO 999000.000 NRAT 3.$9! IbM ~PHI IbM ~PHI DRMO . ~3.!17 ILL 3 44 ooo:§oo 4.910 ILL -999.990 RHD6 999000.000 MRAT 5.168 999000.000 3.311 [bM 4.371 ILL 4.488 NPHI 34.668 RHOB 2.219 DRHO 0.028 NRAT 3,244 NPHI DRHO ILM NP~I DRFO 5.875 ILL 5,828 ,941 RHO~ 2,205 3~.036 ~RAT 3.535 328 RNOB 40 0,005 NRAT 3,348 ILN 6.180 : IbP 6.547 NPHI 39,453 RHOB 2,346 DRMO 0,04i NR:AT 3.520 IbM NPHI DRHO Ib~ NPHI DRHO 3.000 ILL 14.172 9,355 RHOB 2.225 -0.008 NRAT 3.502 8.i02 !DD 8.711 35.889 RHOB 2.355 0.023 NRAT 3.305 LVP oOi~.~ 3 VERIFICATION LISTING DEPT 3900.000 SFL[3 SP -65.063 GR (;R 66.625 CALl NC~L 2478.000 FCNh DEPT 3800.000 SFLU SP -52,469 GR GR 80,813 CALI NCNL 2244,000 FCNL DMPT 3700.000 SFbU SP -54.344 GR GR 61.938 CALl ~CNL 2108,000 FCNL DEPT 3600,000 SFL0 SP -56.719 GR GR 67.938 CALI NCNb 2250.000 FCS(~ Ds?17 3~o.ooo sr~,u GR 61,719 CALl NCNb 2362.000 FCNL DEPT 3400.000 8FLD SP -52,656 GR GR 72.688 CALl NCNb I964.000 FCNL DEPT 3300.000 SFB0 SP -64.813 GR GR 48.813 CALI NCNb 222ai000 ~CNb DEPT 3200.000 8FbU SP -64,250 GR GR 54,i56 CALl NCNB 2452.000 FCNL DEPT 3100,000 SFLU SP -67.875 G~ GR 37.312 CALI NCNb 2474.000 FCNL DEPT 3000.000 SFLU SP -45,188 GR GR 73.563 CALl NCNb 2002.000 FCNL DEPT 2900.000 SFLU SP -55,594 G~ GR 41,469 CALl 7~ 766 64 14 612 6 57 474 6 65 1i 9 13 812 7 71 528 17 35 12 666 10 5~ 1! 609 34 12 56I 7 Il 470 16 48 .922 .000 .~20 .000 .89i .938 .000 .121 .188 .547 .500 .566 .500 .125 .00O O55 i688 203 .000 .441 .500 .711 .500 .719 .5 00 .344 .03J{ i070 .000 .781 .500 .945 .813 .711 .000 .969 ,469 NP~I DRHO Ib~ NPHI DR~O IbM NPHi DRHO Ib~ NPHI DRMO NPHI DRHD ~PHI DRMO IL~ IbM DRHO NP~I D R H O Ib~ ~PHi NPHI DRH~ 11.969 ILD 34.668 RMOB 0.024 NRAT 9.641 39.111 0.034 NRAT 7.738 47.852 0,027 NRAT 7.848 44.189 0,003 NRAT 10.594 IbD 39.551 ~OB -0.007 NRAT 8.586 ILD 42.480 RHOB 0.026 MRAT 12.453 32,i29 RHOB 0.078 N~AT 12.680 IbD 44.922 RHOB 0,006 MHAT 13,641 ILl) 45,947 RHOB -0,004 NRAT 8,602 49.854 RHO~ 0..016 NRAT 11,703 IbD 29,980 RHO5 0.030 ~RAT PAGE 13.742 2.342 3.244 i0.422 2,328 3.529 8.625 2.232 3.945 8.625 2.213 3.729 il.422 2,139 3.527 9.195 2.271 3.650 13.227 2.252 3.115 13.289 2.139 3.770 14.438 2.020 3.854 9.547 2.172 4.059 12.727 2.074 2,947 LVP 009,H05 VERIFICATIOi,_{ 5iSTiNG PAGE 9 NCNL 2384.000 FCNb 744.500 DEPT 2800.000 SFL[! SP -55.688 GR GR 56,531 CALf NCNL 2194,000 FCNL 9,2!i 53.594 13,133 546,500 DEPT 2700,000 SFLU SP -6,793 GR GR 36.875 CALI NCNL 1445,000 FCNL 19,000 41.375 10,563 294,000 DEPT 2693.500 SFLU SP -999,250 GR GR -999,250 CALl NCNL -999.250 FCNL 20.047 46.563 -999.250 -999.250 ** FiLE TRAILER FIhE NA~1E :$ERVIC.O01 SERVICE NAME VERSIU!~ ~ DATE : MAXIMU~ LENGTH FILE TYPE : NEXT F.~LE NAME I~ 10.711 ILD il,789 NPHI 45,508 RHOB 1.998 DRHO 0,001 NRAT 3,857 NPHI DRHO ooo.ooo -0,532 NRAT 4,191 2000,000 ILD 15,078 -999,250 RHOS -999.250 -999.250 NRAT -999.250 ** TAPE TRAILER *~ SERVICE NAaE :SERVIC DATE :82103/ 1 ORIGIN :1070 TAPE NA~E 16~447 CONTINUATION ~ :01 NEXT TAPE NAME : CO~E~TS :TAPE COMMENTS ** REEL TRAILER ** SERVICE NAME :SERVIC DATE ;82/03/ 1 ORIGIN : REEL NA~E :R~EL ID CONTINUATION ~ :01 NEXT REEL NANE: COM~EiqTS :REEL COM~ENTS
