Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
189-130
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 2K-24 (PTD 189-130) Possible Charging OA Date:Monday, December 9, 2024 2:19:05 PM Attachments:AnnComm Surveillance TIO for 2K-24.pdf From: Well Integrity Specialist CPF2 <n2549@conocophillips.com> Sent: Monday, December 9, 2024 1:10 PM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 2K-24 (PTD 189-130) Possible Charging OA Hi Chris, KRU 2K-24 (PTD 189-130) is a water injection well currently on produced water injection that is showing signs of a charging OA. The build up rate is currently 3 psi/day and the OA pressure is currently sitting at 325 psi. CPAI intends to conduct surface casing diagnostics to confirm the integrity of the OA. Please let me know if you have any questions or disagree with the plan. Warmest regards, Jaime Bronga Well Integrity – CPF2 – ConocoPhillips Alaska Cell: 907-229-8282 2K-24 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 2K-24 2024-10-07 950 600 -350 OA 2K-24 2024-10-29 620 241 -379 OA 2K-24 2024-10-31 310 200 -110 OA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: RKB 9,508.0 12/2/2019 2K-24 fergusp Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Tag 12/2/2019 2K-24 fergusp Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 36.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 35.0 Set Depth (ftKB) 3,969.8 Set Depth (TVD) … 2,998.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 33.0 Set Depth (ftKB) 9,827.3 Set Depth (TVD) … 6,620.8 Wt/Len (l… 26.00 Grade J-55 Top Thread BTC Tubing Strings Tubing Description TUBING String Ma… 2 7/8 ID (in) 2.44 Top (ftKB) 31.1 Set Depth (ft… 9,262.1 Set Depth (TVD) (… 6,236.9 Wt (lb/ft) 6.50 Grade L-80 Top Connection EUE-mod Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 31.1 31.1 0.05 HANGER FMC GEN IV TUBING HANGER 2.875 1,814.9 1,707.6 47.16 SAFETY VLV OTIS FMX SAFETY VALVE (LOCKED OUT 8/1/2006) 2.313 9,197.8 6,195.0 49.61 PBR BAKER 80-32 w/10' STROKE w/3.25" SEAL BORE 2.430 9,211.7 6,204.0 49.49 PACKER BAKER HB RETRIEVABLE PACKER 2.430 9,249.6 6,228.7 49.16 NIPPLE CAMCO D NIPPLE (EQ PRONG PULLED 9/11/2016) 2.250 9,261.3 6,236.3 49.06 SOS BAKER SHEAR OUT SUB 2.441 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 9,352.0 9,368.0 6,296.2 6,306.8 C-4, UNIT B, 2K -24 6/7/1997 8.0 APERF 180 deg. Phasing; 2 1/8" EnerJet 9,422.0 9,436.0 6,342.7 6,352.0 A-5, 2K-24 6/7/1997 8.0 APERF 180 deg. Phasing; 2 1/8" EnerJet 9,465.0 9,495.0 6,371.5 6,391.8 A-4, 2K-24 5/16/1990 4.0 IPERF 180 deg. Phasing;4.5" HLS Casing Guns Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,865.1 2,338.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/12/1991 2 5,909.3 4,114.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/10/1991 3 7,937.9 5,390.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/11/1991 4 9,150.1 6,164.2 MERLA TGPD 1 1/2 GAS LIFT DMY BK 0.000 0.0 9/11/2016 Notes: General & Safety End Date Annotation 11/5/2010 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 2K-24, 12/3/2019 11:16:12 AM Vertical schematic (actual) PRODUCTION; 33.0-9,827.3 IPERF; 9,465.0-9,495.0 APERF; 9,422.0-9,436.0 APERF; 9,352.0-9,368.0 SOS; 9,261.3 NIPPLE; 9,249.6 PACKER; 9,211.7 PBR; 9,197.8 GAS LIFT; 9,150.1 GAS LIFT; 7,937.9 GAS LIFT; 5,909.3 SURFACE; 35.0-3,969.8 GAS LIFT; 2,865.1 SAFETY VLV; 1,814.9 CONDUCTOR; 36.0-115.0 HANGER; 31.1 KUP INJ KB-Grd (ft) 40.09 Rig Release Date 1/6/1990 2K-24 ... TD Act Btm (ftKB) 9,870.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 501032012200 Wellbore Status INJ Max Angle & MD Incl (°) 56.67 MD (ftKB) 5,600.00 WELLNAME WELLBORE2K-24 Annotation Last WO: End DateH2S (ppm) DateComment SSSV: LOCKED OUT MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-24 KUPARUK RIV UNIT 2K-24 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-24 50-103-20122-00-00 189-130-0 W SPT 6204 1891300 1551 2789 2789 2790 2790 90 100 100 100 4YRTST P Brian Bixby 6/27/2023 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-24 Inspection Date: Tubing OA Packer Depth 250 2000 1960 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230627151921 BBL Pumped:2 BBL Returned:2 Thursday, July 27, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2 7l DATE: Wednesday, June 26, 2019 P.I. Supervisor R , e Z SII 1q SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-24 FROM: Lou Laubenstein KUPARUK RIV UNIT 2K-24 Petroleum Inspector Ste: Inspector Reviewed By.:: P.I. Supry �I UF— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-24 Insp Num: mitLOL190611075200 Rel Insp Num: API Well Number 50-103-20122-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-130-0 Inspection Date: 6/8/2019 Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-24 Type lnj W'. VT D 6zo4 jTubing M30 X6"0 2nsc a630 Well — -- — - PTD 1891300 Type Testi-SPT ;Test psi! 1551 IA 1iso 19ei ro6n - BBL Pumped- 'BBL Returned 1 1 OA 530 620 - 620 _ 620 _ --T _ .. Interval / 4varsT P/F P -- Notes: Wednesday, June 26, 2019 Page I of I • • lab4-1 "SO (c)5 �Y WELL LOG TRANSMITTAL# To: Alaska Oil and Gas Conservation Comm. December 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 DATAOGOG ED M.K.BENDER RE: Static Bottom Hole Pressure Record: 2K-24 Run Date: 11/13/2015 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 2K-24 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20122-00 Static Bottom Hole Pressure Record(Field Print) 1 Color Log 50-103-20122-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari ittAfINED . 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:(4,A,S0,474kdckteigalfreeet yOF T� • • I//77 THE /77THE STATE Alaska Oil and Gas of i j\ Conservation Commission =_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OFALASAr ,, Fax: 907.276.7542 `--a� . www.aogcc.alaska.gov Andrew T. Beat 3 0 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-24 Sundry Number: 315-719 Dear Mr. Beat: 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, ,;Le-g4C14- Cathy P. Foerster Chair DATED this /cy of December,2015 Encl. RBDMS DEC Ii 2015 • • RECEIVED NOV 2 3 2015 STATE OF ALASKA 1Z/i'gl(S ALASKA OIL AND GAS CONSERVATION COMMISSION w U O^CC APPLICATION FOR SUNDRY APPROVALS /y 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well Operations shutdown❑ Suspend 0//tv Perforate ❑ Other Stimulate ❑ Pull Tubing Q� Change Approved Program r❑ Plug for Redrill Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: C.1. .'f-'.-�' qci 2.Operator Name:, 4.Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 189-130 3.Address. Stratigraphic ❑ Service E , 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-103-20122-00 • 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 2K-24 Will planned perforations require a spacing exception? Yes ❑ No 0 9. Property Designation(Lease Number): 10. Field/Pool(s): ADL 25605 x 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): 9,870' 6,650' 9702' 6534' 4170 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,935' 12" 3,970' 2998' Intermediate Production 9,794' 7" 9,827' 6620' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9352'-9495' • 6296'-6392' 2.875" L-80 9,262' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB RETRIEVABLE PACKER MD=9212 TVD=6204 12.Attachments: Proposal Summary 2 Wellbore schematic E . 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0• 14. Estimated Date for 1/25/2016 15.Well Status after proposed work: �/ Commencing Operations: OIL ❑ WINJ WDSPL ❑ Suspended El 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew T. Beat @265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew T. Beat 265-6341 Title Sr.Wells Engineer Signaturect1? AnDate 5zt I. 11/23/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ,/ 3 5—`719 Plug Integrity CI BOP Test 1 Mechanical Integrity Test ❑ Location Clearance ❑ Other: PJ UG 1Y5 f- 7,-. 4 5U0 /2 5 i`y (A+PS P 1-5 4i :7 p 5.5 ) 4-11,h t,l a P /2 re-✓e vi.t-rte i--t"5 f to 2-57,0 n s p3 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No 2/ Subsequent Form Required:• 1o_I/0 70-7 (J APPROVED BY Approved by: P9COMMISSIONER THE COMMISSION Date:/z—/y-/5� v C. /2/4/f; RIIMAIY&rS 1112'� f �y. Sand Angn ateForm 10-403 Revised 11/2015 p� Jed a liCaoiSllLSor 12 / ths the-date of approval.RBDMS • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 20,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to work over Kuparuk Injector 2K-24(PTD# 189-130). 2K-24 was originally drilled and completed in 1990 as an 'A' and'C' sand injector in Kuparuk.The well is currently online and passed an MIT-IA in July but has been identified as a candidate for our 2016 CTD program. The proposed workover scope for 2K-24 will cover pulling the existing 2-7/8"completion and installing a new 3- 1/2"completion with a 4-1/2"cemented liner set below the production packer. ✓ If you have any questions or require any further information,please contact me at 265-6341. Sincerely � An ew Beat Wells Engineer CPAI Drilling and Wells • 2K-24 Rig Workover • CTD Setup-3-1/2"Tbg w/4-1/2"Cmtd Liner (PTD#: 189-130) Current Status: Online. Scope of Work: Pull the existing 2-7/8"tubing and install new 3-1/2"completion with a 4-1/2"cemented liner. General Well info: Well Type: Injector MPSP: 4,170 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 4,806 psi/6,362'TVD(14.6 ppg EMW)measured on 11/13/2015 Wellhead type/pressure rating: FMC Gen IV,7"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TxIA PASSED-07/10/2015 Earliest Estimated Start Date: January 15,2016 Production Engineer: David Neville Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards.Complete the PJSM. 2. Pull dummy valve from GLM#4. e 9t SO Al D 3. Cut the tubing att:MVPRI.Eftr=106-paekerj: ? 4. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV.Reverse circulate KWF.Obtain SITP&SICP,if still seeing pressure at surface, calculate new KWF, weight up,and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/3 psi. 45-00/251y' V 7-c- a. La. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 2-7/8"tubing. 6. MU and RIH with 2-7/8"spear. Spear the PBR and jar the packer free. POOH with packer. 7. MU cleanout assembly and cleanout to PBTD. 8. RIH with 4-1/2"liner and liner top packer. 9. Pump cement around liner and set liner hanger and liner top packer. 10. Swap the well over to seawater and POOH. 11. RIH with new 3-1/2"tubing and sting into SBE until fully located. Space out and MU hanger. 12. Pump corrosion inhibited fluid around and re-engage seals. 13. Land the tubing hanger,RILDS. 14. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 15. Pull the landing joint,install BPV.Pressure test the BPV from below. 16. ND BOPE. 17. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 18. Freeze protect well with diesel. Set BPV. 1 • 2K-24 Rig Workover• • CTD Setup—3-1/2"Tbg w/4-1/2"Cmtd Liner (PTD#: 189-130) 19. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline to pull SOV and run gas lift design. 3. Reset well house(s)and flowlines of adjacent wells. 4. Turn well over to operations. 2 2K-24 ConocoPhillips KR Injector Inhector CTD Setup w/ 4.5" Well Details: / Cemented Liner API: 50-103-20122-00 PTD: 189-130 PROPOSED S ED Wellhead: FMC Gen IV 5M COMPLETION Tree: WKM 3" 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 115' KB Baker Orbit Valve — 3,800' 9-5/8" 36#J-55 Surface to 3,970' KB 7"26#J-55 Production to 9,827' KB 3-1/2" 9.3#L-80 Tubing to–9,210' KB 4-1/2" 11.6# L-80 Liner to 9,450' KB Misc Details: Max Inclination: 56.67° Max Dogleg: 6.37 °/100' Last Tagged Fill. 9,512' KB — Camco 3-W x 1-1/2" MMG GLM's Total Depth: 9,870' KB Perforation Details: 4b.1 ) 9,352'-9,368' KB–C-4 Sand 1,°\ 9,422'-9,436' KB–A-5 Sand 9,465'-9,495' KB–A-4 Sand 2.813" X Nipple Baker 80-40 PBR Baker ZXP Liner Top Packer C Sand Perfs A Sand Perfs G _ Date: November 20,2015 Drawn By: Andrew Beat KUP INJ 2K-24 ConocoPhillips ;i, awl Well Attributes Max Angle&MD TD Alaska,,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm IftKB) Corvxol'M.- 501032012200 KUPARUK RIVER UNIT INJ 56.67 5,600.00 9,870.0 ,.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-24,1/7/201554212 PM SSSV.LOCKED OUT Last WO: 40.09 1/6/1990 Vertical schemal.(actual)..... Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag ELM 9,512.0 12/30/2015 Rev Reason TAG lehalif 1/7/2015 I Casing Strings • HANGER 31.1Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread -Ill; CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread E' SURFACE 9518 8.921 35.0 3,969.8 2,998.2 36.00 J-55 BTC lr Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread 1 a PRODUCTION 7 6.276 33.0 9,827.3 6,620.8 26.00 J-55 ETC s Tubing Strings . t w., a,auu.Tubing Description Shiny-Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING / 2 7/8 'i 2.441 31.1 9,262.1 6,236.9 6.50 L-80 EUE-mod ,/_/�/CONDUCTOR;36.0-115.0 ,,,..?..A/�A.r!/-- Completion Details // Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 31.1 31.1 0.05'HANGER FMC GEN IV TUBING HANGER 2.875 1,814.9 1,707.6 47.16 SAFETY VLV OTIS FMX SAFETY VALVE(LOCKED OUT 8/1/2006) 2.313 ?(( / 9,197.8' 6,195.0 49.61-PER BAKER 80-32 w/10'STROKE w/3.25'SEAL BORE 2.430 SAFI1TY VLV;1,814.9 - 9,211.7 6,204.0 49.49 PACKER BAKER HE RETRIEVABLE PACKER 2.430 t3 y,� 9,249.6 6,228.7 49.16 NIPPLE CAMCO D NIPPLE 2.250 9,261.3 6,236.3 49.06-505 BAKER SHEAR OUT SUB 2.441 GAS LIFT,2,865.1 Perforations&Slots Shot y Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB( Zone Date t) Type Com 9,352.0 9,368.0 6,296.2 6,306.8 C-4,UNIT B, 6/7/1997 8.0 APERF 180 deg.Phasing;2 1/8" 2K-24 EnerJet 9,422.0' 9,436.0 6,342.7 6,352.0 A-5,2K-24 6/7/1997 8.0 APERF 180 deg.Phasing,2 1/8" EnerJet 9,465.0 9,495.0 6,371.5 6,391.8 A-4,2K-24 5/16/1990 4.0 IPERF 180 deg.Phasing;4.5" SURFACE,35.0-6969 8- HLS Casing Guns Mandrel Inserts St GAS LIFT;5,909.3 ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 2,865.1 2,338.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/12/1991 GAS LIFT;7,937.9 2 5,909.3 4,114.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/10/1991 3 7,937.9 5,390.8 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/11/1991 4 9,150.1 6,164.2 MERLA TGPD 1 1/2 GAS LIFT DMY BK 0.000 0.0 11/12/1991 GAS LIFT;81501 Notes:General&Safety End Date Annotation A 11/5/2010 NOTE VIEW SCHEMATIC w/Alaska Sehematic9.0 r ✓Y• 4-I9), PBR;9,197.8 --- cm PACKER;9,211.7 m NIPPLE;9,249.6 SOS,9,261.3 APERF;9,352.0-9,368.0-- APERF,9,422.09,436.0 --- (PERP;9,465.0-9,496.0 - -- i ) i t PRODUCTION;33.09,827.3 . • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,July 14,2015 P.I.Supervisor � Z�1 S SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-24 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-24 Petroleum Inspector SCANNED ! ��+"� Src: Inspector Reviewed By: P.I.Supry 113 -- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-24 API Well Number 50-103-20122-00-00 Inspector Name: Chuck Scheve Permit Number: 189-130-0 Inspection Date: 7/10/2015 Insp Num: mitCS150713095428 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min WeIi 2K-24 Type Inj j W TVD 6204 Tubing 2675 2675 - 2675- 2675 PTD 1891300 Type Testl 5PT Test psi 1551 IA 560 1940 , 1870 ' 1870 - --- ---- Interval 4YRTST PAF P ✓ OA 200 320 - 320 320 Notes: Tuesday,July 14,2015 Page I of 1 V6q-130 2.5300 WELL LOG TRANSMITTAL DATA LOGGED 1 /2015 K ENDER To: Alaska Oil and Gas Conservation Comm. January 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 "' T V E FEB 0 =5 Z015 AOGCC RE: Multi Finger Caliper(MFC) : 2K-24 Run Date: 12/30/2014 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 2K-24 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20122-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LEITER TO THE A'1"1'FNTION OF: Halliburton Wireline & Perforating Attn: Chris Gullett 6900 Arctic Blvd. RAM Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: 6.e6east ! Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. I~(~_ i~) File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: ~'~ren TO RE-SCAN Notes: Vincent Nathan Lowell Date:5.~ 0~.' Is/ ,~ Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is~ NOTScanned,wpd WELL LOG TRANSMITTAL C...X10) To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: InjJection Profile: 2K-24 Run Date: 7/23/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-24 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20122-00 Injection Profile Log 1 Color Log 50-103-20122-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline& Perforating Attn: Klinton Wood sctitiEG UL 12 2 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 klinton.wood@halliburton.com Date: k7- l3 X‘ Signed: afit • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg P.I. Supervisor kpJ (5. 71 2°1 I1 SUBJECT: Mechanical Integrity Tests r7 CONOCOPHILLIPS ALASKA INC 2K -24 FROM: John Crisp KUPARUK RIV UNIT 2K -24 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 24 API Well Number: 50 103 - 20122 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110627155130 Permit Number: 189 - 130 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -24 'Type Inj. N TVD r 6204 ' IA 2200 2390 ' 2360 2360 - P.T.D 1891300 • TypeTest SPT Test psi 1551 OA 20 30 30 30 Interval 4YRTST P/F P " Tubing 1640 1640 1640 1640 Notes: .5 bbls pumped for retest. Had a problem with the gauge or just looked at the gauge wrong on the first pressure up. , e5t s'Z e+ : , b . . RJL 201 s Tuesday, June 28, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission I DATE: Tuesday, June 28, 2011 TO: Jim Regg } � 7 21 �0 P.I. Supervisor l SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -24 FROM: John Crisp KUPARUK RIV UNIT 2K -24 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K -24 API Well Number: 50- 103 - 20122 -00 -00 Inspector Name: John Crisp Insp Num: mitJCrl 10628111414 Permit Number: 189 -130 -0 Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well F 2K -24 1Type Inj. N I TVD 6204 - IA 740 2380 -I 2370 2360 ' 2230 P.T.D 18913 °° l iTypeTest SPT Test psi L 1551 - OA 20 — 30 30 30 30 Interval 4YRTST pjj P - Tubing 1640 1640 — 1640 1640 1640 Notes: 4.2 bbls pumped. I can't explain this dramatic drop in pressure other than I was reading the gauge wrong. This gauge was replaced & checked for accuracy & was OK. Retest MIT. co Tuesday, June 28, 2011 Page 1 of 1 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 h .~ ~ ~(~ ~~ ~ August 1, 2010 \, k Commissioner Dan Seamount }~~~~Q Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 } ~~ ~~a ~.~~~~ Anchorage, AK 99501 ~ ~~nssiun .. _... , , ~ ~ ~? ~~ ~ C ~~. ~ ~~~ +~~ ~+~' e ~~~~t3 ,r~E~~i~~ ~~'=: Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tt', 31St 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, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 7D sir 7T DAII Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2B-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7!31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31!2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7!30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7!30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7!30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7!30/2010 2T-204 50103203270000 2000160 SF n/a 24" n!a 5.1 7/31/2010 2T-209 50103202810000 1982430 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~~ s~;;r~isorí<11' ¿!~ (ù? DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-24 KUPARUK RIV UNIT 2K-24 8rc: Inspector \~q~ \3D FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2K-24 API Well Number: 50-103-20122-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS07060 I 182314 Permit Number: 189-130-0 Inspection Date: 6/112007 "./ Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-24 Type Inj. w TVD I 6204 IA 1350 2260 2240 2240 P.T.D 1891300 TypeTest SPT Test psi I 1551 OA 650 700 700 700 Interval 4YRTST PIF P ./ Tubing 2500 2500 2500 2500 Notes: Pretest pressures were observed and found stable. We" demonstrated good mechanical integrity. ./ NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm 5CANNED JUN .2 0 2007 Wednesday, June 06, 2007 Page I of 1 RECEIVED ~G-I) 81~ 08/01/06 Scblumbel'gel' ~ Oit & Gas Cons. Comrr.~ Anchorage NO. 3899 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth UTC- ¡7JC) - ¡3D Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ ~. "¡nr~ç1 6C^NNEÐ [\US .:. 'i: L"'· ~ Field: Kuparuk Well Job # Date Log Description BL Color CD 1J-101 (REDO) 40012836 MD & TVD VISION RESISTIVITY 12/20/05 2 1 1D-125A (REDO) 11213778 INJECTION PROFILE 07/17/06 1 2K-24 (REDO) 11213781 INJECTION PROFILE 07/20/06 1 1 G-05 11249932 INJECTION PROFILE 07/28/06 1 3A-08 11249933 PROD PROFILE W/DEFT 07/29/06 1 1 D-117 11216305 INJECTION PROFILE 07/08/06 1 3F-18 11235384 SBHP SURVEY 07/25/06 1 3F-17 11235383 BHP SURVEY 07/25/06 1 1Y-32 11213707 SBHP LOG 07/25/06 1 3G-25X 11216313 PROD PROFILE W/DEFT 07/31/06 1 1Y-24A 11216315 GLS/FBHP SURVEY 08/01/06 1 1R-36 11249931 LDL 07/27/06 1 2V-10 11216311 SBHP SURVEY 07/28/06 1 1D-107 11216309 INJECTION PROFILE 07/12/06 1 1 D-130 11249928 INJECTION PROFILE 07/09/06 1 31-03 11213788 PROD PROFILE W/DEFT 07/26/06 1 1Y-05 11216310 LDL 07/27/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . RECEI\/ED 07/25/06 Scblumbel'gel' Ai¥f 0> $1IJ» .. ¿ 2.n\.tS '.'-í .."' !\Nt--\E!J l\U(; j -::;'v, . NO. 3895 ~ Oit & ~ cor.s. CommÍ$$iCrn ,~ Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: UI C, life¡ - {30 Field: Kuparuk Well Job# Color CD Log Description Date BL 3K-32 11213780 SBHP SURVEY 07119/06 1 2K-28 11235380 INJECTION PROFILE 07/22/06 1 2K-24 11213781 INJECTION PROFILE 07/20/06 1 2U-15 11213782 PROD PROFILE W/DEFT 07/21/06 1 1Q-16 11213873 PROD PROFILE W/DEFT 07/22/06 1 1 G-13 11213784 PROD PROFILE WIDEFT 07/23/06 1 1J-101 PB1 40012836 MD & TVD VISION RESISTIVITY 12/17/05 2 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . 11/26/03 Schlumberger NO. 3053 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk " Well Job # Log Description Date BL Color CD ( 3H-13A ,0 {o'" J<f9- PRODUCTION PROFILE 11/08/03 1 3A-09 (;~ \ ... \ c~ L\ PRODUCTION PROFILE 11/09/03 1 2K-24 ?; c¡ ... ~ SBHP SURVEY 11/10/03 1 2K-25 qn -ê'¡{~ SBHP SURVEY 11/10/03 1 1D-12 qq ~ f)('5L.1 PLUG SET & SBHP SURVEY 09/11/03 1 , ( ........... .~¡"..,- ~...- ~ ~ ,- W--. ~...~ i:ì-o.~ ~ ~~\-ÆF. ~ '. H .~vrL.~ V .-:~ ... SIGNE~r")\',t '''~~.~..}.......^'/~ DATE: DEC 22 2002 '- /~j~13k~ Of! & Gd~ LiJ¡I~. ,",V'I/¡¡íi8ðIOL Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. AI¡chorage ~ ~"-.. ".\ ~. ~~A~~~jE[. JAN 2@2004 ~ ~ ~ \ \ '-¿--=:> MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg ,,~. ,, ., P.I. Supervisor" State of Alaska Alaska Oil and Gas Conservation Commission ?I,~,'7//Z)~ DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2K Pad FROM: John Crisp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. I s i I [Interval I Type test] P ]Test psi[ 3000 ICasing[ 400 I 2900[ 2875[ 2850I P/F I P 2K-20 1891'180 Notes: OA 0 psi. during test. 4 BBL. Pure 2K-24 Type Inj. 1891300 Notes: OA 300 psi during test. 5 BBL. Pumped. WellI I Type Inj. P.T.D. I I Type test Notes: P.T.D,I Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Attachments: Number of Failures: 0 Total Time during tests: 2 hrs. cc,' MIT report form 5/12/00 L.G. 2003-0614_M IT_KR U_2 K-24_jc.xls 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuld KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12K-05 P.T.D.II88t180 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Imypelnj ,I S I T.V.D. I ITub .gl 22001 2200I' 22001 22001Interval I Type TestI P I Test psiI 1500 I Casing I 13801 29801 29401 293OI P/F P.T.D.I't890820 ..Typ.,e Test Test psiI 1502 I Casing I 13201 30101 29801 29751 P/F Notes: P:T.D.I,tS9o590 TypeTest Test psiI 1500 I Casing I 4101 29601 29101 29751 P/F Notes: P.T.'D. It890950 TypeTest Test psiI 1535 I Casing I 12201 29401 28751 28601 P/F Notes: We"I2K' S I' Typelnj I Sp I T.V.D. 15900I Tubing I 25501 25501 25501'25501 Interval}iI P~T,D:11891080 TypeTest Test psiI 1500 I Casing I 13201 29801 29201 2900J P/F Notes: P.T:D,:I~89'I'IS0 Typ..e Test Test psiI 1536 I Casing I 4001 29001 28751 28501 P/F Notes: P.T:D,(1891300 .TypeTest Test psiI 1551 I Casing'l 13001 28801 2,8201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 2003-0614_MIT_KRU_2K-05 06 10 13 18 20 24.xls 6/25/2003 KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) I Name: MIT KRU 2T 06-14-03.xls [~MIT KRU 2T 06-14-03 .xls il Type: EXCEL File (application/msexcel)l IEncoding: base64 ] Name: MIT KRU 2K 06-14-03.xls [~MIT KRU 2K 06-14-03.xl.st Type: EXCEL File (application/msexcel) , iEncoding: base64 I of I 6/25/2003 1:45 PI STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS~51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development __ Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 344' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 1188' FNL, 1719' FEL, Sec. 13, T10N, At effective depth 1432' FNL, 1802' FEL, Sec. 13, T10N, At total depth 1520' FNL, 1826' FEL, Sec. 13, T10N, R8E, UM R8E, UM R8E, UM 6. Datum elevation (DF or KB) RKB 154 feet 7. unit or Property name Kuparuk River Unit 8. Well number 2K-24 9. Permit number/approval number 89-130 10. APl number 50 - 103-20122-00 11. Field/Pool Kuparuk River Field/Oil Pool 12. Present well condition summary Total Depth: measured 9 8 2 7 true vertical 6 6 2 0 feet feet Plugs (measured) None Effective depth: measured 9 7 0 2 true vertical 6534 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' I 6" Surface 3 935' 9 - 5 / 8" Intermediate Production 9794' 7" Liner Perforation depth: measured 9352'-9368', true vertical 6296'-6307', Cemented 170 Sx AS II 1300 Sx AS III & 450 Sx Class G 300 Sx Class G 9422'-9436', 6343'-6352', 9465'-9519' 6372'-6408' Tubing (size, grade, and measured depth) 2.875", 6.5#/ft., L-80 @ 9262' Packers and SSSV (type and measured depth) Packer: Baker HB @ 9212'; SSSV: Camco TRDP-1A-SSA @ 1815' Measured depth 115' 3970' 9827' True vertical depth 115' 2998' 6620' ORIGINAL 13. Stimulation or cement squeeze.summary Perforate well on 6/7/97. Intervals treated (measured) 9352'-9368', 9422'-9436' Treatment description including volumes used and final pressure Perforated using HSD charges w/DP charges, 4 SPF, 90° phasing, fp was 2700 psi. 14. Representative Daily Average Production or Injection D~t~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 749 1400 27O9 Subsequent to operation 0 0 864 1400 2687 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service X W/'~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /.)~,:~.,~, Title Wells Superintendent Form 10~'4- ~R~,v '{)~)¢-1~5f8~ - ~ Date /j- .~.~,-~- ~:~'"~ SUBMI~IN D'"O P L[CATE ARCO Alaska, Inc. KUPARUK RIVER UNIT '~ WELL SERVICE REPORT ~' K1(2K-24(W4-6)) WELL JOB SCOPE JOB NUMBER 2K-24 PERFORATE, PERF SUPPORT 0423971540.2 DATE DAILY WORK UNIT NUMBER 06/07/97 RE PERFORATE UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes O NoI (~) Yes O No SWS-BAILEY BLACK FIELD AFC,~ 0C4¢ DAILY COST AOOUM COST S~~- ESTIMATE KAWWRK 230DS28KL $1 7,522 $18,887 Initial Tbcl Press Final Tb.q Press Initial Inner Ann' Final Inner Ann I Initial Outer Ann I Final Outer Ann 2700 PSI 2700 PSI 1 300 PSI 1 300 PSII 1500 PSI 500 PSI DALLY SUMMARY IPERFORATED F/9352-9368' ELM & F/9422-9436' ELM W/2-1/8" EJ DP @ 4 SPF & 90 DEG ORIENTED ( 8 SPF TOTAL 180 DEG PHASED). TIME 07:30 08:30 11:30 15:00 17:00 LOG ENTRY MIRU SWS (BAILEY & CREW). MU GA#1 (2-1/8" EJ/CCL/WT) TL-22'. PT BOPE TO 3500 PSI. TGSM. RIH. COULD NOT GET DOWN DUE TO WELLHEAD PRESSURE. POOH & ADD MORE WEIGHT. RIH W/ADDITIONAL WEIGHT. RIH SLOW DUE TO WELLHEAD PRESSURE. AT 9480' ELM. SWS COMPUTER DIFFICULTIES. ATTEMPT TO FIND KEYBOARD & TROUBLE SHOOT PROBLEM. ABLE TO REBOOT & CONTINUE W/JOB. TIE IN TO 2/13/90 HES PET & 1/4/90 SPERRY EWR-DGR & PERFORATE F/ 9422-9436 W/2-1/8" EJ DP @ 4 SPF & 90 DEC ORIENTED. GOOD INDICATIONS. MAKE JEWELRY LOG & POOH. AT SURFACE. ALL SHOTS FIRED. MU GA#2 (SAME AS ABOVE WITH 90 DEC CCW ORIENTATION). RIH. AT 9480' ELM. TIE IN & PERFORATE F/9422-9436' ELM W/SAME GUNS AS ABOVE ORIENTED 90 DEC CCW F/LAST RUN. PERFORATED 9422-9436' ELM W/TOTAL OF 8 SHOTS / FT. POOH. 18:30 AT SURFACE. MU GA#3 (SAME AS ABOVE BUT 16' GUNS). RIH TO 9480' ELM. TIE IN & PERFORATE W/ABOVE GUNS F/9352-9368' ELM W/2-1/8" EJ DP @ 4 SPF & 90 DEC ORIENTED. POOH. 21:00 AT SURFACE. MU GA#4 (SAME AS ABOVE). RIH TO 9480' ELM. TIE IN & PERFORATE F/9352-9368' ELM W/SAME GUNS AS ABOVE ORIENTED 90 DEC CCW F/LAST RUN. POOH. 23:15 AT SURFACE. BEGIN RD. 01:00 FINISH RD. RETURN WELL TO INJECTION. TURN OVER TO PRODUCTION. ,, SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $42.00 APC $250.00 $250.00 HALLIBURTON $0.00 $708.00 LI'FI'LE RED $0.00 $615.00 SCHLUMBERGER $17,272.00 $17,272.00 TOTAL FIELD ESTIMATE $1 7,522.00 $1 8,887.00 STATE OF ALASKA ALAoKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate Other 2. Name of Operator /~RCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 344' FSL, 95' FEL, SeC. 11, T10N, R8E, UM At top of productive interval 1188' FNL, 1719' FWL, Sec. 13, T10N, At effective depth 1460' FNL, 1783' FWL, Sec. 13, T10N, At total depth 1520' FNL, 1826' FWL, Sec. 13, T10N, R8E, UM R8E, UM R8E, UM 12. Present well condition summary Total Depth' measured 9 8 2 5' true vertical 6 6 0 6' feet Plugs (measured) f e e t None 6. Datum elevation (DF or KB) 154' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-24 9. Permit number/approval number 89-130 10. APl number 50-103-20122 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 9 7 3 9' true vertical 6 5 4 7' feet Junk (measured) f e e t None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 3970' Cemented 1300 Sx AS III & 450 Sx Class G 300 Sx Class G 9 5/8" 9827' 7" measured 9465'-9495' true vertical 6372'-6392' Tubing (size, grade, and measured depth) 3.5" J-55 set at 9262' Packers and SSSV (type and measured depth) Brown HB @ 9212', Otis FMX @ 1815' 13. Stimulation or cement squeeze summary 4.5" Casing Gun @ 4 SPF Measureddepth 115' 3970' 9827' True vertical depth 115' 2939' 6608' RECEIVED JAN 2 8 t992 Alaska 0il & Gas Cons. (~0mmission Anchorage Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 162 68 2 1275 221 - 0 - 0 - 2462 1400 21 04 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil __ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Form 10-404 Rev 09/12/90 Date '/Z. ~'/?~.- SUBMIT IN DUPLICATE ......... ~.~. ..... ...?, ?:~.?, ._ ~tD~, DRNINQ WELL REPORT FOR-t2,, _~/~1 ~..~ ...... .. W Z S 'Eo T L N A L E T I A PR 2 B PR 3 .A PR 4 A PR 7 A PR 8 A PR 11 APR 14 A PR 15 A TS 16 A PR 17 A PR 21 APR >22 A PR ~5 A PR 26 A PR TOTALS: . W Z S E 0 T L N A L E T 5 A SW 6 B SW 10 A SW 1~ A SW 13 B SW !8 A SW "~0 A SW 23 B SW 24 B SW TOTALS~ PRODUCTION WELL STATUS - %" 10" t'6' ' TT WC H2S CS~ ~ CS~ · · PSI CHK DEQ~ % . PPM PSI PSI 176 76 1 ~10 ~.~OQ 700 ~76 1~1 ~9--3o 13oo ~oo I76 45 0 -5-1100~ 600 1~6 48 o- "i~ ~oo 300 176 53 0~:~.42 800, 300 175 51 ' 5 15 I000 300 260 176 71 261 176 46 0 261 176 35 2 287 176 64 0 256 176 43 0 260 176 4I 0 261 176 50 0 259 176 43 1 261 176 33 0 259 !76 19 0 261 176 48 0 15 800 600 40 800 700 40 600 400 15 1200 600 0 1000 550 5 800 750 5 1100 6O0 5 1100 6O0 5 950 700 5 1000 150- 5 800 400 INJECTION WELL STATUS ALLOW ACT ' 7" 10" INJ INJ TT CSQ CSQ PSI PSI DEQ CHK PSI .PSI gAS LIFT STATUS S,"I !~'~P~S. rT ,S '[ C N ,-AS INJ AH H M [J TEMP METER RATE LI.., R I., O EPL DE~ READIN~ MSCF EB $ .N E.BI]LB 68 30- .50 60 50 65 50 45 44 60 50 40 65 60 50 50 45 ~o2o 97~ o oooo o o ~o~m ,. 0 0 eooo 0 0 78.~O- 340 0 oo0o o 0 2270 634 o oooo o o 187o 962 o oo0o 0 "o 3500 1628 o oooo o o 3400 426 0 0000 O 0 160 '611 0 OOOO n 0 7640 267 0 OOOO © 0 8200 1257 0 0000 0 0 1700 711 0 0000 0 0 21~0 735 0 0000 0 0 100 94-9 0 0000 0 0 3700 475 0 0000 0 0 9400 527 0 0000 0 0 8930'\ 203 0 0000 0 0 250 909 0 0000 0 0 11613 INJECTION RATE S/[ C INJ INJ H M 0 METER RATE RATE R I D READINQ BPD MMSCFD S N E 2500 197~ 67- 25 1600 600 . .. 2500 1.796. 67 14 I100 600 2500 2307"'66'"55. 1100 0 2500 2332 6~ 176 14.00 500 2500 234~'"i:767'.176'"-800 900 25oo aaa?'; 67 17~ ~6oo 500 2500 2328~- 67' 176 1000 550 2500 tBOe 63 27 1000 2500 ~104 60 i02 1400 800 -. SWI' 14132 + PWt' . · .... 2600 1609 0.000 7230 1494 0.000 6640 1505 0.000 3990 1859 0.000 350 ~17 0.000 3825 1417 0.000 8640 864 0.000 215 2005 0.000 2830 2462 0.000 0· 14132 0.000 0000 0 0000 0 0~30 55 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 · ~.L~ .... ' -- I I Il I Il II [lllr [ I-"l]i[' ' i i I [ Ilr[ll lit[ -lllt--~ '1~1'1 .............. STATE OF A OILAND GAS ~RVATION COMMI APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Alter casing _ Change approved program_ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 344' FNL, 95' FEL, SEC 11, T10N, R8E, UM At top of productive interval Suspend _ Operation Shutdown _ Re-enter suspended well Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubln~l _ Variance _ Perforate _ Other X 5. Type of Well: 6. Datum elevation (DF or KB) Development .~. Exploratory _ Stratigraphic _ Service _ 1188' FNL, 1719' FWL, SEC 13, T10N, R8E, UM At effective depth 1460' FNL, 1783' FWL, Sec.13, T10N, R8E, UM At total depth 1520' FNLr 1826' FWLr Sec. 13r T10Nr R8Er UM 12. Present well condition summery Total Depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: true vertical measured 9 7 3 9 true vertical 6 5 4 7 Length Size 115' 16" 3970' 9 5/8" 9827' measured 9465'-9495' 98 25 feet Plugs (measured) 6606 feet None feet Junk (measured) feet Nolle . 1300 Sx AS III & 450 Sx Class G 300 Sx Class G 4.5" Casing Gun @ 4 SPF F{KB 154 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-24 feet true' vertical 6,372'-6,392' Tubing (size, grade, and measured depth) 2.875" J-55 set at 9,262' Packers and SSSV (type and measured depth) Brown HB ~ 9212'~ Otis FMX ~ 1815' 13. Attachments Description summary of proposal _ Convert well from oil producer to water injector. (Wellbore 14. Estimated date for commencing operation 15. · November 1991 9. Permit number 89-130 10. APl number so-103-201 22 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3970' 2939' 9827'6608' ,, IVFD Detailed operation program .~ schematic attached). Status of well classification as: Oil m Gas __ BOP sketch_ Suspended _ 16. If~s~proposall~o~,~ I~, ~,->was .verbally approved 10/31/~1 ~ Name of appro~ Date a~rov~ Service Water Injector I i 17. I hereby ~i~ ~at ~ f~oi~ is ~e and ~ to ~ ~st of my knowledge. Si~ C'-~-~ Title Omrafl~sEn~in--r F~ ~~ ~E ~LY Conditions of a~roval: No~fy Commissi~ ~ re~e~nta~ve ~y ~ Plug integrity ~ ~P, Test _ L~fl~ ~aran~ ~ Mechani~l Int~ri~ Test~. Subsequent form require 10-//d/{ ORIGINAL SIGNED BY LONNIE C, ~r~ITH Date IApproval No. ~..~ Date /1// ~, / ?/ SUBMIT IN TRIPLICATE Approved b)f order of the Commission Form 10-403 Rev 09/12/90 Commissioner Messrs. Fontenot and Wild~''-~' 10/26/91 Page 2 1) 2) 3) Wells 2K-13, 2K-23 and 2K-24 Water Injection Conversions Charge Code: Downhole 994901; Surface 994928 10/23/91 If possible, obtain final 12' hour weiltest and SI well for 72 hours. This will enable an accurate static BHP measurement which is important for waterflood surveillance analysis. Notify G. Targac(x6849) to insure that the sundry notices for converting the wells to water Injection have been approved by the State. MIRU slickline unit and diesel pump truck. RIH and set SV in Otis 'XN' or 'D' nipple. Well 2K-24 has 2-7/8" tubing and a Camco 'D' nipple. 4 ) Pump diesel down casing while taking return from tubing. volumes shown below: s) 6) 7) 8) 9) Annulur Volume WelJ to Btm Mandrel 2 K- 1 3 239 bbls 2 K- 2 3 258 bbls 2 K- 2 4 276 bbls Fill annulus with diesel 3 1/2" tubing X 7" casing 3 1/2" tubing X 7" casing 2 7/8" tubing X 7" casing RIH to replace GLV's and OV's with DV's (see attached wellbore schematics for depths). Ensure the casing/tubing annulus is filled with diesel. Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure lesting Io prevent tubing buckling, RIH and pull SV. RIH w/Panex gauge or Amerada gauge to mid A Sand perforation for 15 minute static pressure. POOH and take static pressure measurement in the lubricator. RDMO Slickline. Notify the State of the Mechanical Integrity Tests (MIT's). Conduct MIT tests. Packer depths and 7" annular pressures necessary are shown below. Bleed the annulus to 1000 psi after completing the test. TVD Depth Required Casing .~ ~ Pressure for MIT 2 K- 1 3 61 2 5' 3333 PSI 2K-23 6081' 3330 PSI 2K-24 6204' 3340 PSI The above pressures were calculated assuming a surface tubing pressure of 2300 pal. If a different surface tubing pressure exists at the time of the test, the required test pressure should be recalculated using the following equation: MTP = Ptbg + ((Tubing gradient - Annular gradient) * TVD of Packer) MTP= Minimum Test Pressure on Tubing/Casing Annulus ~';; Ptbg = Pressure in the tubing at lhe wellhead Tubing gradient is assumed to be seawater with a gradient of 0.44 psi/fl Annular gradient is diesel with a gradient of 0.353 psi/ft Messrs. Fontenot and Wild 10/26/91 Page 3 10) Prior to Initiating water Injection, a spear should be Injected to clean up the perforations. Depending on the outcome of the tag and bailer samples obtained, the next step will Involve a xylene/mutual solvent spear that will be either bullheaded down the tubing or placed across the A Sand perforations with coiled tubing. A separate procedure will be prepared for the CTU cleanout/placement if necessary. For the spear recipe, the following volumes should be pumped at matrix rates (roughly 1-2 BPM) not to exceed 1450 pei surface treating pressure and displace with specified amount of diesel. Displacement volume to top perf is critical since a soak is involved and it is important that SW not be the displacing fluid as the fluids would swap during the soak. Approximately half of the xylene mix will be displaced into the perfs and the remaining half left in the wellbore. Volume of Volume of Mutual Solvent Displacement Volume Well ~ Chemlink - 8603 of Diesel to to.D .Derf 2K-1 3 16 bbis I bbl (6%) 84 bbls 2 K- 2 3 7 bbls 0.5 bbl (7%) 93 bbls 2 K- 2 4 14 bbls I bbl (7%) 61 bbls Allow to ~oak for 1 hour and overdisplace with SW at approximately 500 BWPD and gradually increase the injection rate to maximum injection pressure. WELL 2K-24 PRODUCER APl # 501032012200 SURFACE LOCATION: 344' FNL, 95' FEL, SEC 11, T10N, R8E, UM TOP KUPARUK: 1188' FNL, 1719' FWL, SEC 13, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB TREE: FMC GEN IV 5000 PSI 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3969' · L SPUD: 12/28/89 COMPLETION: 5/17/90 SSSV: OTIS FMX ID 2.313" @ 1815' GLM1: 2865' GLM2: 5909' GLM3: 7938' / 1.0" TMPD / 1/4" Port / 1.0" TMPD / 1/4" Port / 1.0" TMPD / 1/4" Port GLM4: 9150' /1.5" TGPD / 3/16" Port BAKER PBR: 2.500" ID @ 9198' BROWN HB PKR: 2.375" ID @ 9212' CAMCO 'D' NIPPLE: 2.25" ID @ 9250' SHEAR OUT: 2.441" ID @ 9261' C B A5 A4 A3 7": 2~ J-55 @ 9827' PBTD: 9702' 2.875" 6.5# L-80 EUE ABMOD IPC TUBING TAIL @ 9262' HOLE ANGLE ACROSS KUPARUK = 47 DEGREES MAX HOLE ANGLE = 56 DEGREES @ 5600' VOLUME TO TOP PERF = 61 BBLS 9465' 4 SPF ~ 180° PHASING ORIENTED 171° CCW 9495' FILL TAGGED AT 9511' MD-RKB (8/14/91) REVISION: 10/22/91 STATE OF ALASKA AL~bKA OIL AND GAS CONSERVATION COMMISSION "?" WELL COMPLETION OR RECOMPLETION REPORT AND LOG ... , 1 Status of Well Classification of Service Well GAS I---1 SUSPENDED I--1 ^BANDONED r-1 SERWCE I--'! 2 Name of Operator 7 permit Number ARCO Alaska, Inc 89-130 ..... 3 Address 8 APl Number P.O. Box 100360, Anchoracje, AK 99510-0360 50-103-20122 4 Location of well at surface 9 Unit or Lease Name 344' FNL, 95' FEL, SEO 11, TION, RSE UM ~~ "'-,~'.(~T.%CT= KUPARUK RIVER AtTop Producing Interval ~_~"'~~.,... 'DATE . j' ii~ u,..,'~..~.,t_~j~¢3VERj~jED 10 Well Number At1188'FNL'TotalDe,~ 1719' FEL,SEO ,3, T10N, R8EUM ,, 5 Elevation in feet (indicate KB, DF, etc.) J 6 Lea D~ig~,~'7~l Serial No. KUPARUK RIVER OIL POOL RKB 154'J ADL: 25605 ALK: 2679 12 Date Spudde~,l 2/28/9e?, 13 Date T.D. Reached1/4/90. 14 Date Comp., Susp. or Aband. ~,,%/..1"7'~J0. J lS Watar Depth, if offshOreNA feet M SL J,6 No. of Completions. 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9702' MD & 6534' TVD YES [~] NO r'-I 1815, feet MD 9827' MD & 6620' TVD 1400' APPROX 22 Type Electric or Other Logs Run DIL/SFI./GR/SP/FDC/CN L/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 170 SX AS II , 9 5/8" 364f J-55 SURF 3970' 12-1/4" 1300 SX AS II1~ 450 SX CLASS G 7" 26~ J-55 SURF 9827' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+-I'VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SE.T (MD) 2-7/8" 9262' 9212' 9489' - 9519' W/4-1/2" Csg gun @ 4 SPF MD 6388' ~ 6408' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AM.OUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I iDate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIo I TEST PERIOD m- Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ,~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None ~ ~CE JVED '.)'.-,i U ].. Fractured 8/4/90 ....... iJ :i;;[,'i, ~jJ ~ ..... cho aga 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 recoverd and gravity, MEAS. DEPTH TRUE VERTo DEPTH GOR, and time of each phase. KUPARUK C TOP 9350° 6295' NA KUPARUK C BO'I-rOM 9367' 6306' KUPARUK A TOP 9402' 6329' KUPARUK A BO'lq'OM 9582' 6451' 31. LIST OF ATTACHMENTS GYRO, Frac addendum, Daily Operations .... 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL 2~24 8/4/90 Frac Kuparuk "A" sand perfs 9465'-9495' 180 deg oriented 171 deg ccw in nine stages as follows. Stage 1: Stage Stage Stage Stage Stage Stage Stage Stage Pmp 250 bbls Gel H20 w/HyBor @ 15-20 bpm 3500-6500-5100 psi 45 bbls Gel H20 w/HyBor @ 15 bpm 4150-3900 psi 30 bbls Gel H20 w/HyBor @ 10 bpm 6700-5800 psi 2:59 bbls Slick Diesel flush @ 3000-5250 psi 3:100 bbls meter check reduced flush 1.04 EFF @ 20 bbls 5600-5800 psi 4:1003 bbls Gel H20 w/HyBor @ 20 bpm 5500-5800 psi 5:47 bbls Gel H20 w/HyBor & w/2ppg 16/20 Carbolite @ 20-18 bpm 5800-5600 psi 6:61 bbls Gel H20 w/HyBor & w/4ppg 16/20 Carbolite @ 18-17 bpm 5600-6000 psi 7:65 bbls Gel H20 w/HyBor & w/6ppg 16/20Carbolite @ 16 bpm 6000-6200 psi 8:64 bbls Gel H20 w/HyBor & w/8ppg 16/20 Carbolite @ 15 bpm 6200-6600 psi 9:36 bbls Slick diesel flush @ 15 bpm 6600-6800 psi Fluid to recover: 1754 bbls Sand in zone: 40,174 lbs Sand in csg: 2,760 lbs Avg pressure: 5800 psi Date ARCO O. and Gas Company Daily Well 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 ii space is available. I Accounting cost center code District County or Parish /State I NORTH SLOPE I AK ARC(% ALA~qKA INC. Field KUPARUK RIVER UNIT Lease or Unit ADL: 25667 ALK: 2588 T tie COMPLETION Well no. 2K+24 Auth. or W.O. no. AK3790 Operator Spudded or W.O. begun Date and depth as of 8:00 a.m. 05/18/90 (12) A.R.Co. W.I. Date ,,~5. 8533 12/28/89 Complete record for each day reported NORDIC RIG #1 Iotal number of wells (active or inactive) on this dst center prior to plugging and bandonment of this well our I Prior status if a W.O. I 00:00 RIG RELEASED 7"@ 9827' MW:10.0 NaC1/Br TD: 0 Pa: 9739 SUPV:DEB Old TD Released rig Classifications (oil, gas, etc.) Producing method Potential test data CONT. RUNNING 2.875" COMP. ASSEMBLY, TST SS CNTL LINE, SET PACKER, SHEAR PBR@ 81K9, TST SSSV, OK, SDLJ, SET BPV, NU FMC GEN IV TREE, TST PACKOFF TO 5000PSI, SHEAR SOS @ 4000PSI, REVERSE CIRC. 6 BBLS DIESEL INTO ANNULUS, INJECT 1 BBL DIESEL DOWN TUBING, RD AND BLOW DOWN LINES, SECURE WELL, RELEASE RIG @ 16:30 17-MAY-90 DAILY:S133,308 CUM:$1,189,207 ETD:S1,189,207 EFC:$1,511,800 New TD PB Depth Date K nd of rig IType completion (single, dual, etc,) Official reservoir name(s) Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C,P. Water °/o GOR Gravity Allowable Effective date corrected The above is ~.rrect · e~.,~ ~ Date. .4 I T i.t I e ,~..,....~ For form preparatio~d dis;ribution, ~ / ' / see Procedu~s Man~, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively I Page no. as they are prepared for each wail, I DlvlNon of AllanflcRIchfleldComl:~lny ARCO Oil a,,d Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Rel~rt" on the first Wednesday after a well is spudded or wort(over operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County. parish or borough I A~O_~ AT.AS;fA INC I NORTH SLOPE Field Lease or Unit WT~PARUK RIVF~R UNIT ADL: 25605 Auth. or W.O. no. ITitle AW~TqO I COMPLETION ALK: 2679 IState AK no. K-24 Operator IARCO W.I .cn J J I$5. 8533 Spudded o~ W.O. begun JDate JHour Prior status if a W.O. sp~m 12/25/$9 00:00 Date and depth Complete record for each day reported as of 8:00 a.m, 05/17/90 (11) TD: 0 PB: 9739 SUPV:DEB RIG ~1 RUNNING 2.875 COM. ASS. 7"@ 9827' MW:10.0 NaC1 ACCPT RIG FORM 2K-23, NU BOP, TST BOP, RU HLS E-LINE, HLS E-LINE, PERF GU #1, 9499-9519, RIH GUN #2 9489-9499, ASF, RD HLS E-LINE, RU FLOOR TO RUN 2 7/8" COMPLETION ASS. DAILY:S53,456 CUM:$1,055,899 ETD:S1,055,899 EFC:$1,511,800 The above is correct S,gnature Pot form preparstion ~ distribution, ,~ see Procedures Manu~J/Section 10 Drilling, Pages 86 and"87. J Date / J T'~ ~ t- i ~ I ' AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. jPage no. SURVEY REPORT ARCO ALASKA INC.. KUPARUK FIELD, PAD 2K WELL NO. 24 NORTH SLOPE, ALASKA FEBRUARY 23, 1990 MICROFILMED Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77224 713/'461-3146 Fax: 713/461-0920 February 23, 1990 Mr. Tim Billingsly Arco Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk Field, Pad 2K Well No. 24 North Slope, Alaska Dear Mr. Billingsly: Enclosed please find one (1) original and nine (9) copies of the completed survey of Well No. 24. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the furore. Sincerely, Gary Uttecht Vice President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura. CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia / Buenos Aires, Argentina/Bergen, Norway A Gyrodata Directional for ARCO ALASKA INC. KUPARUK FIELD, PAD 2K, WELL NO. 24 NORTH SLOPE, ALASKA Survey Date Run: 13-FEB-90 05:55:24 Job Number: AK0290G206 Surveyor: MIKE HOWATT Calculation Method: RADIUS OF CURVATURE Survey Latitude: 70deg 14min 30sec N Sub-sea Correction from Vertical Reference: 118.0 ft Bearings are Relative to TRUE NORTH Proposed Well Direction: S 19deg 49min 0sec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 24 ORTH SLOPE, ALASKA ob Number: AKO290G206 A Gyrodat a Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 N 0 0 E 100.0 200.0 300.0 400.0 500.0 600.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 0 10 N 32 7 W 0 14 N 57 8 W 0 33 S 31 30W 1 29 S 0 31E 2 50 S 2 47 W 4 33 S 3 14 E 6 42 S 7 30 E 10 46 S 14 9 E 11 12 S 14 22 E 12 21 S 16 56 E 15 30 S 17 18 E 18 46 S 14 10 E 21 52 S 12 45 E 25 24 S 15 32 E 29 54 S 16 46 E 34 7 S 15 31E 40 25 S 14 53 E 46 42 S 13 26 E 49 46 S 13 17 E 53 47 S 12 28 E 54 22 S 10 40 E 54 13 S 13 24 E 53 54 S 12 36 E 54 12 S 12 52 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/100' ft ft CLOSURE DISTANCE BEARING ft deg min .00 .0 .0 .0 N 0 0 E MULTI SHOT SURVEY IN 7 INCH CASING ALL DEPTHS ARE REFERENCED TO KB ELEVATION KB TO GROUND = 36 FT. ( KB ELEVATION = 154 FT. ) .17 100.0 -.1 .1 N 32 7 W .10 200.0 -.5 .5 N 40 54 W .60 300.0 -.5 .9 N 75 38 W 1.06 400.0 .9 2.0 S 43 31 W 1.36 499.9 4.4 1.76 599.7 10.5 2.17 699.2 20.0 4.18 798.0 34.9 .43 896.2 53.9 5.4 S 15 32.W 11.7 S 6 58 W 21.4 S 1 22 W 36.4 S 3 41 E 55.2 S 7 19 E 1.26 994.1 ,74.2 3.17 1091.1 98.3 3.38 1186.7 127.6 3.14 1280.5 162.1 3.70 1372.1 202.0 75.4 S 9 34 E 99.3 S 11 23 E 128.7 S 12 23 E 163.4 S 12 37 E 203.5 S 12 55 E 4.54 1460.6 248.3 4.26 1545.4 301.2 6.31 1624.9 361.5 6.37 1697.4 430.1 3.07 1764.0 504.2 249.8 S 13 31E 302.8 S 13 58 E 363.3 S 14 11E 432.2 S 14 10 E 506.7 S 14 3 E 4.06 1825.8 582.1 1.56 1884.5 662.3 2.22 1942.9 742.7 .73 2001.6 823.1 .36 2060.3 903.4 585.3 S 13 54 E 666.2 S 13 37 E 747.3 S 13 27 E 828.3 S 13 24 E 909.2 S 13 20 E HORIZONTAL COORDINATES feet .00 N .00 E .12 N .08 W .37 N .32 W .23 N .91W 1.45 S 1.38 W 5.21 S 1.45 W 11.66 S 1.42 W 21.41 S .51 W 36.30 S 2.34 E 54.76 S 7.03 E 74.40 S 12.53 E 97.39 S 19.61 E 125.74 S 27.60 E 159.50 S 35.68 E 198.36 S 45.47 242.92 S 58.37 E 293.82 S 73.10 E 352.22 S 88.97 E 419.00 S 105.82 E 491.56 S 123.05 E 568.13 S 140.56 E 647.46 S 156.80 E 726.86 S 173.74 E 805.75 S 191.95 E 884.72 S 209.79 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 24 ORTH SLOPE, ALASKA ob Number: AK0290G206 A Gy rodat a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 2500.0 53 46 S 14 9 E 2600.0 53 32 S 13 50 E 2700.0 52 51 S 13 27 E 2800.0 52 35 S 14 6 E 2900.0 52 31 S 13 46 E 3000.0 52 56 S 12 43 E 3100.0 52 58 S 13 4 E 3200.0 53 7 S 13 9 E 3300.0 53 9 S 12 45 E 3400.0 53 3 S 12 43 E 3500.0 53 17 S 12 22 E 3600.0 53 39 S 12 14 E 3700.0 54 14 S 11 52 E 3800.0 53 51 S 11 19 E 3900.0 53 41 S 11 9 E 4000.0 53 16 S 10 52 E 4100.0 53 47 S 11 5 E 4200.0 53 50 S 11 43 E 4300.0 54 0 S 11 17 E 4400.0 54 13 S 11 53 E 4500.0 54 20 4600.0 54 36 4700.0 54 47 4800.0 55 5 S 10 6E S 11 26 E S 11 48E S 11 35 E S 11 41E 1.13 .35 .74 .59 .27 .93 .27 .16 .32 .10 .36 .38 .66 .60 .20 .48 .55 .50 .38 .52 1.45 1.11 .36 .36 .44 VERT DEPTH ft 2119.1 2178.4 2238.3 2298.8 2359.6 2420.2 2480.4 2540.6 2600.6 2660.6 2720.5 2780.1 2838.9 2897.6 2956.7 3016.3 3075.7 3134.8 3193.7 3252.3 3310.7 3368.8 3426.6 3484.1 3541.0 VERT SECTION ft 983.8 1064.0 1143.6 1222.7 1301.7 1380.7 1459.9 1539.3 1618.7 1698.1 1777.5 1857.2 1937.3 2017.4 2097.1 2176.5 2256.0 2335.8 2415.8 2496.0 2576.2 2656.5 2737.3 2818.3 2899.7 CLOSURE DISTANCE BEARING ft deg min 990.1 S 13 21E 1070.7 S 13 24 E 1150.7 S 13 25 E 1230.3 S 13 27 E 1309.7 S 13 28 E 1389.3 S 13 28 E 1469.1 S 13 26 E 1549.0 S 13 25 E 1629.0 S 13 23 E 1708.9 S 13 21 E 1789.0 S 13 19 E 1869.3 S 13 17 E 1950.1 S 13 14 E 2031.1 S 13 10 E 2111.7 S 13 5 E 2192.0 S 13 1E 2272.4 S 12 56 E 2353.0 S 12 53 E 2433.8 S 12 50 E 2514.8 S 1~ 48 E 2595.9 S 12 45 E 2677.3 S 12 41 E 2758.9 S 12 39 E 2840.7 S 12 37 E 2922.9 S 12 36 E HORIZONTAL COORDINATES feet 963.36 S 228.68 E 1041.51 S 248.15 E 1119.32 S 267.04 E 1196.59 S 285.99 E 1273.65 S 305.10 E 1351.11 S 323.34 E 1428.91 S 341.15 E 1506.74 S 359.27 E 1584.70 S 377.20 E 1662.71 S 394.83 E 1740.84 S 412.20 E 1819.35 S 429.31 E 1898.42 S 446.19 E 1977.71 S 462.45 E 2056.83 S 478.16 E 2135.71 S 493.51 E 2214.65 S 508.82 2293.76 S 524.75 2372.95 S 540.88 E 2452.31 S 557.14 E 2532.00 S 572.62 E 2611.94 S 587.82 E 2691.88 S 604.25 E 2772.02 S 620.84 E 2852.55 S 637.42 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 24 DRTH SLOPE, ALASKA ob Number: AKO290G206 A Gyrodat a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 5000.0 55 43 S 11 5 E 5100.0 55 56 S 11 29 E 5200.0 56 13 $ 10 50 E 5300.0 56 15 S 11 6 E 5400.0 56 15 S 10 46 E 5500.0 56 21 S 10 57 E 5600.0 56 40 $ 10 54 E 5700.0 53 33 $ 12 16 E 5800.0 52 50 S 15 31 E 5900.0 52 20 S 17 25 E 6000.0 52 34 S 18 16 E 6100.0 52 44 S 18 7 E 6200.0 53 4 S 18 16 E 6300.0 53 15 S 18 40 E 6400.0 50 41 S 19 19 E 6500.0 50 53 S 19 10 E 6600.0 50 28 S 18 57 E 6700.0 50 44 S 19 41 E 6800.0 51 2 S 19 25 E 6900.0 51 3 S 19 45 E 7000.0 51 26 S 19 34 E 7100.0 51 32 S 19 38 E 7200.0 50 11 S 20 48 E 7300.0 50 16 S 20 22 E 7400.0 50 53 $ 20 46 E .54 .40 .61 .22 .28 .19 .32 3.31 2.71 1.58 .72 .20 .35 .37 2.61 .24 .46 .62 .36 .27 .42 .11 1.64 .35 .68 VERT DEPTH ft 3597.5 3653.7 3709.5 3765.0 3820.6 3876.1 3931.3 3988.4 4048.4 4109.1 4170.1 4230.7 4291.1 4351.0 4412.6 4475.9 4539.2 4602.7 4665.8 4728.7 4791.3 4853.5 4916.7 4980.6 5044.2 VERT SECTION ft 2981.3 3063.2 3145.2 3227.3 3309.5 3391.7 3474.1 3555.2 3634.9 3714.1 3793.4 3872.8 3952.6 4032.6 4111.3 4188.8 4266.1 4343.4 4421.0 4498.7 4576.7 4655.0 4732.5 4809.4 4886.6 CLOSURE DISTANCE BEARING f t deg min 3005.4 S 12 34 E 3088.1 S 12 32 E 3171.1 S 12 30 E 3254.2 S 12 27 E 3337.3 S 12 25 E 3420.4 S 12 23 E 3503.8 S 12 21 E 3585.8 S 12 20 E 3665.9 S 12 22 E 3745.1 S 12 27 E 3824.0 S 12 34 E 3903.1 S 12 40 E 3982.5 S 12 47 E 4062.2 S 12 54 E 4140.5 S 13 1E 4217.5 S 13 8 E 4294.5 S 13 14 E 4371.3 S 13 20 E 4448.4 S 13 27 E 4525.8 S 13 33 E 4603.3 S 13 39 E 4681.1 S 13 45 E 4758.2 S 13 52 E 4834.6 S 13 58 E 4911.3 S 14 4 E HORIZONTAL COORDINATES feet 2933.44 S 653.71 E 3014.57 S 669.90 E 3095.97 S 685.96 E 3177.59 S 701.78 E 3259.23 S 717.55 E 3340.94 S 733.22 E 3422.83 S 749.03 E 3503.17 S 765.51 E 3580.88 S 784.73 E 3657.04 S 807.24 E 3732.51 S 831.52 E 3808.03 S 856.34 E 3883.80 S 881.24 E 3959.71 S 906.58 E 4034.18 S 932.21 E 4107.33 S 957.75 4180.45 S 983.01 4253.37 S 1008.57 4326.48 S 1034.52 4399.74 S 1060.58 4473.18 S 1086.82 E 4546.89 S 1113.07 E 4619.67 S 1139.87 E 4691.62 S 1166.89 E 4763.94 S 1194.02 E RCO ALASKA INC. UPARUK FIELD, PAD 2K, WELL NO. 24 ORTH SLOPE, ALASKA ob Number: AKO290G206 A Gyrodat a Directional Survey Page , MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 7500.0 51 26 S 20 31 E 7600.0 51 5 S 21 8 E 7700.0 49 13 S 23 57 E 7800.0 48 36 S 24 29 E 7900.0 48 23 S 24 52 E 8000.0 48 48 S 25 15 E 8100.0 49 13 S 25 9 E 8200.0 49 43 S 25 8 E 8300.0 50 9 S 25 14 E 8400.0 50 39 S 25 15 E 8500.0 50 33 S 25 51 E 8600.0 50 41 S 25 42 E 8700.0 50 53 S 25 42 E 8800.0 51 6 S 26 24 E 8900.0 51 24 S 26 9 E 9000.0 50 53 S 27 2 E 9100.0 50 33 S 25 45 E 9200.0 49 35 S 23 17 E 9300.0 48 43 S 20 35 E 9400.0 48 21 S 19 17 E 9500.0 47 17 S 19 27 E 9600.0 46 27 S 18 37 E 9700.0 46 17 S 15 54 E 9720.0 46 8 S 15 45 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/lO0' ft ft .58 5106.9 4964.5 .59 5169.5 5042.5 2.86 5233.5 5119.1 .73 5299.3 5194.3 .36 5365.5 5268.9 .51 5431.7 5343.6 .41 5497.3 5418.7 .50 5562.3 5494.4 .45 5626.6 5570.6 .50 5690.4 5647.3 .47 5753.9 5724.2 .18 5817.3 5801.1 .19 5880.5 5878.1 .58 5943.5 5955.4 .36 6006.1 6032.9 .85 6068.8 6110.2 1.05 6132.1 6187.1 2.13 6196.3 6263.5 2.21 6261.7 6339.1 1.04 6327.9 6414.0 1.07 6395.1 6488.1 1.03 6463.4 6561.1 1.98 6532.4 6633.4 .91 6546.3 6647.8 CLOSURE DISTANCE BEARING ft deg min 4988.7 S 14 10 E 5066.1 S 14 17 E 5142.1 S 14 24 E 5216.4 S 14 32 E 5290.1 S 14 41 E 5363.9 S 14 50 E 5438.2 S 14 58 E 5513.0 S 15 7 E 5588.4 S 15 15 E 5664.3 S 15 23 E 5740.3 S 15 31E 5816.4 S 15 39 E 5892.7 S 15 47 E 5969.2 S 15 55 E 6045.9 S 16 3 E 6122.5 S 16 11E 6198.7 S 16 19 E- 6274.6 S 16 25 E 6349.9 S 16 29 E 6424.7 S 16 31 E 6498.7 S 16 33 E 6571.6 S 16 35 E 6644.0 $ 16 35 E 6658.4 S 16 35 E HORIZONTAL COORDINATES feet 4836.82 S 1221.47 E 4909.72 S 1249.19 E 4980.61 S 1278.62 E 5049.35 S 1309.54 E 5117.39 S 1340.81 E 5185.33 S 1372.58 E 5253.63 S 1404.71 E 5322.43 S 1437.00 E 5391.68 S 1469.56 E 5461.37 S 1502.42 E 5531.09 S 1535.74 E 5600.69 S 1569.35 .E 5670.50 S 1602.96 E 5740.31 S 1637.08 E 5810.24 S 1671.61 E 5879.88 S 1706.47 E 5949.22 S 1740.87 6018.98 S 1772.69 6089.15 S 1800.94 E 6159.59 S 1826.49 E 6229.49 S 1851.06 E 6298.47 S 1874.86 E 6367.59 S 1896.32 E 6381.48 S 1900.26 E Final Station Closure: 6658.4 feet South 16 deg 34 min 56 sec East by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 07/24/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK Well ...... : KRU 2K-24 Section at: S~19.'82 E Engineer..: MIKE HOWATT Computation...: RADIUS OF CURVATURE Survey Date...: 07/17/90 RKB Elevation.: 154.00 ft API Number .... : 50-103-20122 Job Number .... : AK0290G206 INTERPOLATED MARKERS REPORT Surface Location: 344 SNL 95 WEL Sll T10N R8E MARKER MEAS INCLN VERT-DEPTHS SECT DIRECTION REL- COORDINATES IDENTIFICATION DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD · KB 0 0.00 0 -154 0 N 0.00 E 0 N 0 E 9-5/8" CASING 3970 53.40. 2998 '2844 2153 S 10.95 E 2112 S 489 E TOP KUPARUK C 9350 48.53 6295 6141 6377 S 19.94 E 6124 S 1814 E BASE KUPARUK C 9367 48.47 6306 6152 6389 S 19.72 E 6136 S 1818 E TOP KUPARUK A 9402 48.32 6329 6175 6415 S 19.29 E 6161 S 1827 E BASE KUPARUK A 9582 46.60 6451' 6297 6548 S 18.76 E 6286 S 1871 E PBTD 9702 46.27 6534 6380 6635 S 15.88 E 6369 S 1897 E 7" LINER/TD 9827 46.13 6620 6466 6725 S 15.76 E 6456 S 1921 E HOI. JSTON INSTRtJMeNT AUSTIN, TEXA'~ CHART NO. I01 HOUqTON INST~{U~N ~ A~rl~. TEX · CHA~T NO. ~0 t RREO- '' t i ': :-' : ..... i_. N[!R~H'fiSL-0f~: -;-ff:::ll:flSF,,fl ...... j .............. : .... i ........... ............ I ...... [ .... 1. ;:'."t .... : ! .~:~Z~~:... 1.:: .'. i .... i .... 1 ........ iL: .... ~!: : ;. :_ :':z_~: !-:- :: : :-FiKI~2913E21:E : I :-:-'::I':-7:_:' _:-: ::: :::-z: !-:: _-.:-::-::::::l-":: :!:' .~ ::_--:::-i "_:- ' I' ! /:: -:]:i : ::! :'l'_ ::: t'': .......... 1 .*_: ~:-? ..... '"' I ............. ~ .... I .. ,I...:t .......... ~ ..... : .... ! ..... : ........ :.:l:.. ~ ..... .... 1~ ................ I ........... i ............. ~ ' ..................... i ' ........ ' ....... ............. ~ .................. ~ .................... ? .................. I .......................................................... '' ' I-' '._Li .... ~ .......... I ...... " .... , ..... ,::' ..... ~ ................. t ........ ~ .......... t ...... I .... t ........ t ........... : .... ~ .......... t ...... ...... , ........... .~ ............. ~_: ................. [ ................... l ..... _ ........ ~ :-~ '-'~:~'- ': :' ~:'":'-': :-: "~ :i :: ::-'~::!':: :::':.t::-':: :-::: :-:'::::-:'!' .::-::-! '::.-::::: :!:::i::':: :::~.:::! !!::i:::: :::: ::-: ........ t-:i-'- .................... ..... i--~i ..... : .... , ....... ' ............... i ............... ' .................... -:: ::.-: :'t'-: ::: .':: ::::::::::::::::::::::-: ::::::t ':-:::-:.::'::¥ .: ::¥::-'-:::.:: :::' ..... '-F-: .... t~.~ , .......... I ........ --':-~-----:-'- :-:- .... r-: .... T ......... i ..... T .... IT .................... ~"i -T ........... !.:.-:-::!::t:::::: ::::-i-¥::':!:i::-i:::i:f~!:-~ :: ;:-:'--:::t-::::-':- -::: :::: i-:"::.-:: :':'::-: I':::.:::::----:-:::',':"-:-'::-: :::-:':---:-?::::~: :: ::-:!:::"~:- I i'::-:--' i:::;--:::::t::--¥:t::i-.-'--.-.:;r-:::-::::Ft-:::.'::::-:::::'.:::~: ::: :::---' ::-:::::F:¥:::: ::::::; :!:-::::'::-:---~::::: - :-'~i'::-' ................. :.I ........... ,-- .... : .......................... : : ...... i..:~:.-: ..... :--' ...... '- ..................... ....... D,i -:--: ....... i ................. ---:-r--:-/ ............... i ........ ~ ................................ :-- -:- -~- ............... : ..... ~ --t---- ..... .-.-- ,- ........... : .... f .............. :-/ t ................. '- .... ............. J_:_- -.~:----:..~:_: ....... ::-:-,~::. ~::-: _.-_._~-:.~_-.. .............. .... ~!':"~:- ...... ,~ ....... 1 ....... I t ....... . . : ............. . . .' ~ ........... __ . ~.-,-----:-'.-:----:-..I~ .._, ..... : ' ............ -- ~. .... :! ................ .. I ~-I .... t-:---__ L:" ~!,-:-.I-: . ..... ; : ...... ! ...... !-. -: ..... ! ..... t ...... ': i: :.~:-.::-..~!..:: i.. :: :-:. ::..:::--i:!.:::.:'~-::i i'::'~.'! :.-:-i ::i:::: :-I::':: :::' :: :"~:: :': i i'i:::::',,,~ :'.' :-:::: :-::..--: :':':"!: :::: :':-'::-: '::!:~: i :: !': I!:::: -:::t::: ! : ::: ::: :. !l ii:! LL:_L~:LLt. L:-:.:i.::--::-.2:':-:'-::.! :!. ~: :::-; !':.L ::i': ! ': :':-!, :': :': t:: :_L_~~':':::-: ! ...... T_-:" :-i"'~ ........... :--:i:-:-: .... :. ........ i":: ~': I,,.;,/' :-~ ............. ;-.--~--.'. ..... .-'-::- ......... :-:~ :--:--t--~+ :--: .: ...... ':-- : ......... : .... : :-::-:::: :':'::: ':::: :'": ':'":: ::::;'": :::: '::: ':'.~:: ?:-:':-: :':":':::I-: :'::::-:-:-::: :: :.2:'::':.'. :::.:: . ::: -:': :~::: '-:~: :'1:: .::::: :::-:::i'. '; ::-:':i ir::.::: -::-'i: I: :':::-:'-:: ! :::'::-: -::'::-~ ::.: :'~ i.!.;-.::.:-:::-:'::~' ~,Z,z-:. ::::: ::t':: ::-:'i:: :::. :' ::.::::i_ ====================== · :¥ ';. ti::!'-:-'.:.: ::::'::-:-t :': :'::: ::;: :.'::. "~:-'; ~: ~ .:::: ~":: i:i.'::. ~ :-':-::::! :: ::::::::: :::::-..: ::::~:: :::::~:~::: ¥::::.:--~.;:t: --: :-! ,---.' 4.-: ........... !-: ..... '. ...... :- ':-: ~ i .... :--' -~ .... .'- ..................... ...... : : ..... , ~ ....... : -!'-:-'t-'!-'~ :.:::::: ::[~:~:_:: ::::::::::::::::::::::::: :-:::.::::::~ ~ ::.:~::: :.::::::::::_ :-:-::::::: :::i::: :::.: ::_-.. ::.~::~_::..-::::::::::::::::::::::: --'.~ :4: !::'l::::";::':: it'::: :- ~-::f-?--::4: :t:::::f:t::~ ::;::~:4--:.::: :::-: :f-!: ::-¥:::- -::.::.::-:: .,::~:t.: _: :.~ ::::t: t.-::::::':f: i4:-~t.:!.: i:-':-:.--':t: i:::::~::~ .~: ':'-::-~'. ::~:~::---: ::~_-:t_:-'i:i- :'-4---~--:~_-_.:-.-:::-:---:-:--4---.:4----;- :--~-? :':--~-"~-:-'t i-:-;-'- ~--:!:-'f.'::-!~:~ :-~'-:--'-i-;':~-:-:--:~_----7--!~-!'-:- :; '~-: ...... :--:---?-,--:-~---~-:--~ -~-+-¥-----~--!.-; ~--:: ~: ? ;-+~ :;: + ! i---: :-i:i--~-~-~---- ' +~4- 4~--: -:.----~--~- --~--!- ~-~--'.-.-~4-i-- -+-½-F.----.:-;-:- ~--.~- -~--- !-.:--~-" :-',,-+4- ~- -~- -:---¥----. ,44-:-:-,,,.? ~,-~- ~?~-:--:--~,~-~r-~,--~,,,---r~,-~-, -",---?-~- ~-~--~-~-~: .~, ~-,~--~- ,-~,?--~, -~-,~-~- ~44,'----~ .... ~- ~ ,~-~-~---r- ,,~-~-~--;-~ ~'~? ~--~'~ ...... '~--';-:--.- . ~:F --+ '- ' - ; i i l,ta~a;_~. I 'i-P~-~- --~,-f-t-~-', ,-~r-'-T-T-~--- b-~ ~:..z.~"t4~l F '-'-,--~' -i-F-FL, -~ , - I , I I ~ !'~r- ~ ~--~-.-- -I, i~ t --LL-~- ~.~.,_~.._ I lli ~.~-;-'4- -.- - - , ~, ,- ,,~,'- +~-~- :::f~ fi: ~__~___.__~_ ._-r_.LSJ 'L,~_z_-z_-r~ i~ r ,, .-,, ,--, ~ ,,, PERMIT &Y o0~ - /'..~ o WELL NAME ..- I AoGcc GEoLoGiCAL'MATERIALS INVENTORY LIsT [ check off orlist data as it is received ), 407 ! ' drilling history ~ survey l~--r ~,~ tests I core .Ksription cored intervals core analysis dry ditch into ,rvais digital data .... LOG TYPE ' RUN INTERVALS SCALE NO. i i i ..... ii ~ ~, ~ ~,~o ~,~/~,v ~'/~",~o /-.z.. 2~/- ~/' " " ~j , , 13] 14l , , ~ 'sl 19] , , ARCO Alaska, inc. Date: May 17, 1990 Transmittal #: 7760 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510'-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-24 2K-26 2K-23 2K-25 2K-13 KRU State #1 Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET · Pulse Echo Evaluaton PET 2-13-90 7800-9696 2-19-90 8300-10220 2-12-90 2-14-90 8146-10130 2-11 -90 6400-9464 2-27-90 559~-7140 Receipt Acknowledged' DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) STATE OF ALASKA ~-~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. BOX 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 344' FNL, 95' FEL, Sec. 11 T10N, R8E, UM At top of productive interval 1179' FNL, 1682' FWL, Sec. 13, T10N, RSE, UM (approx) At effective depth 1485' FNL, 1792' FWL, Sec. 13, T10N, R8E, UM (approx) At total depth 1545' FNL, 1835' FWL, Sec. 13,T10N, RSE, UM (approx) 12. Present well condition summary Total Depth: measured (approx) true vertical 9825' feet 6606' feet Plugs (measured) None Effective depth' measured (approx) true vertical 9739' 6547' feet Junk (measured) feet None Casing Length Structural 8 0' Conductor Surface 3 9 3 3' Intermediate Production 9 7 91 ' Liner Perforation depth: measured Size 16" 9 5/8" 7" None Cemented 1300 Sx AS III & 450 Sx Class G 300 Sx Class G true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-24 feet 9. Permit number 89-130 10. APl number 50-103-20122 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3969' 2930' (approx) 9827' 6608' (approx) RECeIVeD MAR - 1_ 1.990 Naska 011 & Gas com Ancliorage 13. Attachments Description summary of proposal _ Detailed operation program BOP sketch 14. 16. Estimated date for commencing operation March, 1990 If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas __ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed {~ ~ ~/,.~c.~ Title Area Drilling Engineer ( FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require ~IflGtNAL SIGNED ElY LONNIE C. SMITH Approved by the order of the Commission' 10- //ozf'' Commissioner lApproval No. Date '~' -%'- 70 Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ARCO ~.,,, and Gas Company Well History - Initial Report - Daily InSffU©tioP,~: Prepare and submit tile "l.~lt~i Re,oft" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to apuddln{~ shOUld be summarized on the form giving inclusive dates only. District ~County. parish or borough ARCO ALASKA INC. I NORTH SLOPE Field Lease or Unit KUPARUK I ADL: 25605 Auth, or W.O, no, JTitle AK3790 ~ DRILLING te ALK: 2679 KRU 2K-24 JWell no. Operator ~ARCO W.I. ARCO ~5. 8533 t Spudded or W.O. begun IDate IHour ]Prior status if a W.O. sPuD I 12/28/89 j 02:00 Date and depth Complete record for each day reported as of 8:00 a,m. DOYON 14 12/28/89 ( 1) TD: 472'( 472) SUPV:CD 12/29/89 (2) TD: 3282' (2810) SUPV:CD 12/30/89 (3) TD: 3990' ( 708) SUPV:CD 12/31/89 (4) TD: 5138' ( 1148 SUPV:CD 01/01/90 (5) TD: 7634'( 24961 SUPV:CD 01/02/90 ( 6) TD: 8929'( 1295 SUPV:CD RECEIVED 01/03/90 (7) TD: 9154'( 225 SUPV:CD 01/04/90 ( 8) 671 MAR-1 1990 TD: 9825,< Alaska,Oil & Gas Cons, CommtSst Pv: S° Anchorage DRLG 12.25" HOLE MW: 8.8 VIS:107 MOVE RIG FROM 2K-10 TO 2K-24,ACCEPT RIG 2000HRS AT 12/27/89,NU DIVERTER, PU BHA, DRLG F/l15' T/472'. DAILY:S37,446 CUM:$37,446 ETD:S37,446 EFC:$1,310M DRLG MW: 9.1 VIS: 98 DRLG F/ 472 T/ 983, BIT TRIP, DRLG F/ 983 T/ 3282. PULLED BIT BECAUSE IT WOULD NOT STEER PROPERLY. DAILY:S66,280 CUM:$103,726 ETD:S103,726 EFC:$1,310M DISPLACING CEMENT MW: 9.4 VIS: 65 DRLG F/ 3282 T/ 3990. CIRC., TRIP FOR HOLE OPENER, CIRC. POOH, LD BHA, RU & RUN 102 JTS 9.625" 36~,J55 BTC CASING SET AT 3969',CIRC CSG, PUMP 100 BBLS WATER SPACER, CMT W/ 1300SX ASIII + 4508X CLASS G CMT, DISP W/ MUD. DAILY:S57,014 CUM:$160,740 ETD:S103,726 EFC:$1,310M DRLG MW: 8.7 VIS: 32 FINISH DIS? CMT, ND DIVERTER, MU BRADEN HEAD, NU BOPE, TEST OK, PU 8.5"BHA LOAD RLL TOOL, TIH, TAG FC @ 3888', TEST CSG 2000#, DRLG FE AND TEST FORM. TO 12.8EMW, OK, DRLG F/4000' T/5138'. DAILY:S256,418 CUM:$417,158 ETD:S417,158 EFC:$1,310M DRLG MW: 9.1 VIS: 36 DRLG F/ 5138 T/7634. DAILY:S58,243 CUM:$475,401 ETD:S475,401 EFC:$1,310M DRLG MW: 9.3 VIS: 38 DRLG F/7634 T/8929 DAILY:S58,461 CUM:$533,862 ETD:S533,862 EFC:$1,310M CIRC. @ 9.625" SHOE MW: 9.8 VIS: 38 DRLG F/8929 T/9056',CIRC, POOH T/ 9.625" SHOE, CIRC, TEST FORMATION, POOH, CHANGE BHA, TAKE OUT RLL INFO, TIH, REAM 8920 T/ 9056, DRLG F/ 9056 T/ 9154', INCREASE MW T/ 9.8PPG, ADD LCM, POOH TO SHOE. DAILY:S55,163 CUM:$589,025 ETD:S589,025 EFC:$1,310M CIRC @ TD MW: 9.8 VIS: 37 TEST FORMATION, RIM, DRLG FROM 9185 TO TD, CIRC.. DAILY:S69,096 CUM:$658,121 ETD:S658,121 EFC:$1,310M The above is correct Signat~ ~ For fo%~ preparatio~md di~ibution, ~ see Procedures Me~u~l, Section 10, Drilling, Pages 86 ~ 87. IDate . / J Tt~ AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. Page no. ARCO OI, ~.,td Gas Company Daily Well History--Interim 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 Field ARCO ALASKA INC. I County or Parish State NORTH SLOPE AK Lease or Unit ADL: 25605 ALK: 2679 KRU 2K-24 Complete record for each day while drilling or workover in progress DOYON 14 KUPARUK Date and depth as of 8:00 a.m, 01/05/90 ( TD: 9825'( SUPV:SC RU AND RUN CASING MW: 9.9 VIS: 37 LOG W/ RLL, POOH LD DP, RIG UP TO RUN CASING, DAILY:S54,312 CUM:$712,433 ETD:S712,433 EFC:$1,310M RECEIVED MAR - ! 1990 Alaska 0il & Gas Cons. CommissiOn Anchorage JWell no. The above is correct Drilling, Pages 86 and 87 Date AR3B-459-2-B JNumber all daily well hislory forms consecutively JPage no. as they are prepared for each well. ARCO ..,il and Gas Company Daily Well 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. I Accounting cost center code District ~te ARCO ALASKA INC. County or Parish NORTH SLOPE Field Lease or Unit I Well no. I KUPARUK ADL: 25605 ALK: 2679 KRU 2K-24 Auth. %N.O. or no. Title AK3790 DRILLING Operator A.R.Co. W.I. ARCO Date55. 8533 Spudded or W.O. begun SPUD 12/28/89 Date and depth as of 8:00 a,m. 01/06/90 (10) TD: 9825 PB: 9739 SUPV:SC Complete record for each day reported DOYON 14 I otal number of wells (active or inactive) on this dst center prior to plugging and bandonment of this well our Prior status If a W,O. 02:00 MOVE TO 2K-21 7"@ 9827' MW: 9.9 NaC1 RUN 7" CSG, CMT CSG W/ 300 SX CLASS G, ND, SET SLIPS & PACKOFF,NU LOWER TREE,TEST 3000 OK, MOVE. DAILY:S290,010 CUM:$1,002,443 ETD:S1,002,433 EFC:$1,310M MAR-'l 1990 Alaska 0il & (;as Cons. C0mmlssl0~ Anchorage Old TD New TD PB Depth Released rig Date Kind of r Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest 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 For form prepara~,u¥ and distribution, see Procedures/Nla)~ual, Section 10, Drilling, Pages &~."and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. Page no. DIvlNon of AtlsntlcRIchfleldCompany ARCO Alaska, Inc. Date: January 30, 1990 Transmittal #: 7654 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith is the following items. signed copy of this transmittal. 2K-21 2K-21 2K-24 2K-24 Electromagnetic Resistivity/Dual Gamma Ray Dual Gamma Ray/Compensated Neutron Porosity/ Simultaneous Formation Density Electromagnetic Resistivity/Dual Gamma Ray Dual Gamma Ray/Compensated Neutron Porosity/ Simultaneous Formation Density Please acknowledge receipt and return one 1-16-90 3700-10031 £~-10800 1-16-90 1 - 0 4- 9 0N?,~-7'50- 9 82 6 1 04 90..3~'~7'50 9826 Receipt Acknowledged: DISTRIBUTION: RECEIVED BP(+sepia) Susanne Baxter Chevron(+sepia) D&M Drilling Drill Site Foreman File Doyon 14 Rig Supervisor Franzen Johnston(+sepia) NSK State of Alaska(+sepia) James Trantham ,,EMORANDOM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION _ / TO: Lonnie C Smit~?'~--/~g DATE: January 4, 1990 Commissioner / F.E NO: D. BDF. 101 TELEPHONE NO: Sr Petroleum Engineer Bobby D Petroleum Inspector FROM: BOP Test AAI KRU 2K-24 Permit #89-130 Kuparuk Rv Fie 1 d ~aturday, December 30, 1989: The test began at ll:00am and was completed ~'~'" f":."00pm', A~ 'the attached BOP test report shows, there were no failures. A new kill line hose with' welded connections is on location and will be installed during the next rig move. In summary, I witnessed the BOP test on Doyon Rig 14 on AAI 2K-24. Attachment 02-001A (Rev. 8~85) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report Inspector , . Operator Well ,L~~ Drlg contrctr _ Location (general Rig ~ General housekeeping Reserve pit ~ MUD SYSTEMS: Audio Visual Trip tank ~/~ ! Pit gauge ~' ..... ! Flow monitor ~/ ..... I Gas detectors ~" I Test Pressure BOPE STACK: Annular preventer Pipe rams Blind rams Choke line valves HCR valve Kill line valves Check valve DATE ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump i ncr clos press 200 ps ig -- Full charge press attained ...~__ Controls: Master Remote(~,~' Blind switch cover~ KELLY AND FLOOR SAFETY VALVES: Upper Kelly Lower Kelly / Ball type / Inside BOP / Choke manifold / Number valves Number flanges Adjustable chokes / Hydraulically operated choke ft psig psig mi n ~sec min ~(~ sec psig Test pressur~_7~ pressure ,~0 Test Test pressure Test pres,ur~ TEST RESULTS: Failures, 0 Test time ~ hrs Repair or replacement of failed equipment to be made within days and Inspector/Commission office notified. Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) December 26, 1989 Telecopy No. (907) 276-7542 P J Archey Area Drilling Engineer ARCO Alaska inc P O Box 100360 Anchorage, AK 99510-0360 Kuparuk River Unit 2K- 24 ARCO Alaska Inc Permit # 89-130 Surf Loc 344'~, 95'FEL, Sec 11, T10N, R8E, UM Btmhoie Loc 1632'FNL, i766'FWL, Sec 13, T10N, RSE, UM Dear Mr Archey~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. ~nere a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~~ truly yours, Chairman Alaska Oil and Gas Conservation Commission BY O~ER OF THE CO~4iSSION Department of Fish & Game, Habitat Section - w/o encl Department of Environmental Conservation - w/o encl ARCO Alaska, Inc. December 12, 1988 Mr. C. V. Chatterton Commi ss i oner State of A1 aska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat - 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM- hf Enclosure RECEIVED Alaska Oil & O, as [;ohs. CorrlllqissJoit ^nchorage GRU13/010 ~\i~ ?(] :'~.~.;,'-:~ ~;, ifc. is ~ :_',i~;~i~i.ii ,:~ , ~i:: ~? ::iii~ i: , · ~: c~ ~ WELLS 1-12 ARE LOCATED IN ~I i SECTION 2, T I0 N., R. 8 E., ss UMIAT UE'RIDIAN. .~ ~' UUIAT UERIDIAN. S~Cr~ON ~ 0~ S~C*mON ~ D.S. ~K .~s ~tes: ~/ ~:~ SECTION CORNER I. CO0~INAT[S ARE ~$R ZONE 4. S~CT~O~ ~ 1~:~9 ~ SECTION ~2 2. ALL DISTANC~ SNOWN ARE TRUE. ~· ' ~:~ 3. ELEVATIONS ARE B.P.M.S.L. : ~:z~ ~ 4. O.G. ELEVATIONS FROM CED-RIXX-3~II re~4. ~ U ) ~988 6. 58REFERENCE, 59, 65 8 66. FIELD BOOK: L 88-40, pc. 55,56 I 5,938,600.18 498,310.1~ ' 70°14'36.519" 150°00'49.133" 296' 94' 114,0 118.5 2 5,938,575.14 498,310.~8 70°14'36.273 150 °00'49.130 271, 3 5,938,550.30 498,310.35 70°14'36.029'' 150°00'49.128" 246 113.8 4 5,938,525.46 498~310.06 70014' 35.784 150°00'49. 1 2~Z' 113.8 5 5,9 38,500.19 498,310.1Z 70014' 35.536" 150°00'49.134'' 196' 113.8 6 5,938,475.14 498,310.33 70014'35.289'' 150° 00' 49.1Z8'' ' 171' 113.8 7 5,938,450.36 i 498,310.36 70014'35.0~'' 150°00'49.1~7'' 146' 113.8 8 5~938,425.30 498~310.18 70°14'34.799'' 150o00'49.132" ~ 121' 113.8 I I 5,938,350.22 , 498,310.14 70014' 34.061" 150o00 49.133" 46 ' I 113.9 12 5,938,325.20 498,310.17 70°14'33.815'' ~ 150°00'49.131'' 21' 94' 113.9 118.5 ! EN.L. ! 13 5,938,235.31 498,310.37 70°14'32.930'' 150°00'49.1Z5'' ' 69' 94' 113.7 118.5 14 5,938,210.14 ~ 498,310. t6 70°1~'3Z.683'' 150°00'49.131" ~ 94' 113.7 15 5,938,185 IZ~ 498 310.16 70°1~' " )20 5,938,060.14 498,310.22 ~ 70°14'31'2074 150°0049.128" 244 ~ 114.1 I 21 5,938,035.t6 . 498,310.)6 170Ol4,30.96~" 150o00'49.130" 269' ) 114.0 22 5,938,010.40 ~ 498,5)0.19 70°1 30.718" 150° 00'49.1Z9" 294' 94' 114.0 m 23 5,937,985.32 498,310.13 70o14 30.471 150o00, 32, 95' 114.0 Z4 .5...)937,960.29 498,310.08 70°14'30. ZZ5" ~150o0 49.1 344' 95' .1 113.9 118.5 PLAT REPRESENTS A SURVEY MADE ~ ~ ~ I DRILL SITE 2'K BY ME OR UNDER MY DIRECT SUPER- ~. ~- VISION AND THAT ALL DIMENSIONS · ' · CONDUCTOR AS-BUILTS AND OTHER DETAILS ARE CORRECT ~ ". ~'5~g ,." Welll ,y ASP's , , Alas~la Ul! & Oa~ Cu,~$. ~j0,,m,m;aa;u:: Dist. Dist. O.G. Pod I~. ' X, L~t;"[(~li;~ ~NGITUDE RS.L. EEL. Elev. Elev. I 5,938,600.18 498,310.1~ 70°14'36.519" 150°00'49.133'' 296' 94' 114,0 118.5 2 5,938,575.14 498~310.28 70° 14' 36.273" 150°00'49.130'' 271' 113.9 3 5,938,550.30 498,310.35 70° I~' 36.029" 150°00'49.128" 246' 113.8 " 36" 4 5~938~525.46 498~310 .OB 70014' 35.784 150°00'49. 1 222' 113.8 5 5,938,500.19 498,310.1Z 70o14' 35.536" 150°00'49.134'' 196' 113.8 6 5,938,475.14 498,310.33 70014'35.289" 150°00'49.128'' 171' 113.8 7 5,938,450.36 ~ 498,310.36 70014'35.0~'' 150°00'49.127" 146' 113.8 8 5 ~938,425.30 498~310.18 70° 14' 34.799'' 150o00'49.132" 121' 113.8 9 5,938,400.30 498,309.98 70°14' 34.553" 150°00'49.137', 96' 113.8 I0 5~958~375.19 498~ 510 14 70014 ..... . ,, I I 5~938~350.~2 , 498~310.14 70014' 34.061 " 150o0 49.135" 4 ,. 113.9 12 5,938,325.20 498,310.17 70014' 33.815" 150°00'49.131" 21' 94' 113.9 118.5 EN.L. 13 5,938,~35.31 498,310.37 70°14' 32.930" 150 °00' 49.1Z5'' 69' 94' 113.7 118.5 14 5,938,210.14 J 498,310. i6 70°14' 3~.683'' 150° 00' 49. 131'' 94' 113.7 15 5,938,185 IZ~ 498,310.16 70°14' " " !13.8 . 32.437 150° 00' 49.131 II 9' 16 5,938, t60.11 ! 498,310.20 70°14' 3~. 191" 150°00'49.130'' 144' 113.8 17 5,938, 135.21 ~ 498,310.18 70014' 31.946" 150°00' 49.130'' 169' 113.9 I ,oo,,.,,.,oo.. ,,,.o t9 I 5,938,085.~0 , 498~310.Z7 70°14' 31.454" 150o00'49.127" 219' 114.0 ~0 5,938,060.14 498,310.~2 ~ 70°14'31.207'' 150o00'49.128'' 244' 1'14.1 . 21 5,938,035.t6 . 498,310.t6 I 70Ol4'30.96~'' 150°00'49.130'' 269' ~ 114.0 22 5,938,010.40 ~ 498,510.19 70°14' 30.718" 150° 00'49. 129" 294' 94' 114.0 I 2~ i~ill) 9 ~) 9 ~ O, 29 ~98,3~0.08 70 °I~' 30.225'' 150°0 49. i 344' 9 ~Im~ i i3.9 iIS.~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSI~JN PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill ~ I lb. Type of Well Exploratory~ Stratigraphic Test _ Development Oil Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, In(;:, RKB 154. Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25605 ALK 2679 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 344' FNL, 95' FEL, Sec. 11 , T10N, R8E, UM KuDaruk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 1400' FNL, 1700' FWL, Sec. 13, T10N, R8E, UM 2K-24 #U630610 At total depth 9. Approximate spud date Amount 1632' FNL, 1766' FWL, Sec 13, T10N, R8E, UM 1-01-90 $200,000 12. Distance to nearest 13. Distance to nearest well ,, 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2K.3,.j-.~.~. p=~ ,¢~ ~,,~ 9788 MD 1632' @ TD feet'-'~= ~ at SURFACE feet 2560 6539 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400 feet Maximum holean?le 52° Maximum surface 1744 psig At totaldepth (TVD) 6539' 3400 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin? Weight Grade Coupling Lan?th IVD TVD IVD TVD linclude sta?e data/ 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 CF 12.25 9.625 36.0# J-55 BTC 3854' 35' 35' 3854' 2947' 1100 Sx AS III & HF-ER~ 450 Sx Class G 8.5 7" 26.0# J-55 BTC 9788' 35' 35' 9788' 6539' 250 Sx Class G & HF-ER~ Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth !'ii!!!:cai R ECElV E Intermediate ProductionDEC 121989 Liner Perforation depth: measured J~l, Sk~0ii & Gas Cons. true verticalAnchorage 20. Attachments Filing fee ~ Property plat __ BOP Sketch ~ Diverter Sketch ~ Drilling program ~ i Drilling fluid program ~ Time vs depth plot ~ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Si?ned ~~ -'~. ~--~~-'~r'" Title Area Drilling Encjineer Date Commission Use Only _ ~ ~.~--__/'".~,,'~ 50-/o $ -- 2. o / 2. ~ 12 / 2 0 / 8 9 other requirements Conditions oJ approval Samples required __Y es ~ N o Mud Icg required__ Ye s~N o Hydrogen sulfide measures__ Yes .~ N o Directional survey required ~'Yes __ N o Required working pressure for BOPE ~2M; ~ 3M' ~ SM' ~ 10M' ~ 1 5M by order ol Approved b Commissioner the commission Date Form 10-401 Rev. 7-24-89 Subm" in triplicale HORIZONTAL PROJECTION SCALE ! IN. = 1000 FEET ARCO ALASKA. I~e. f Il ~ Pad 2K, Well ~o~ 24 Revised Pro?ossl Kupsr'ul( F!eld North Slope, Alaaza 1000 1 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ 7000 _ WEST-EAST 000 0 1000 2000 3000 I I I I SURFACE LOCATION= 344' FNL. 95' FEL SEC. !1. TION. RSE SURFACE ~ S 15 DEC; 49 kilN E 6585' (TO TARGET) RECEIVED DEC 121989 Alaska Oil & Gas Cons. commission Anchorage TARGET CENTER TVD=6356 THD=9485 DEP-6585 SOUTH 6336 EAST 1795 TAROET LOCATION, 1400' FNL, 1700' FWL SEC. 13. TION. RSE TD LOCATION' 1632' FNL. 1766' FWL SEC. 13. TION'. RSE ARCO ALASKA, Ino. Pad 2K. We l I No'~ 24 Revised Proposal Kuparuk F~eld. Nor{h Slope. Alaska 0 _ RKB ELEVAT[ON~ 154' 1000 _ 2OOO _ 3000_ 4000_ 5000 _ 6OOO _ 7000 .,, KOP TVD=400 THD=400 DEP=O 3 9 BUILD 3 DEG PER lO0 FT 15 21 27 33 B/ PERHAFROST TVD=]424 THD=148] DEP=298 39 T/ UGNU SNDS TVD=1544 THD=1627 DEP=381 45 51EOC TVD=1920 THD=2158 DEP=754 T/ W SAK SNDS TVD=2164 THD=2561 DEP=1074 B/ W SAK SNDS TVD=2747 TMD=3524 DEP=1841 9 5/8" CSO PT TVD=2947 THD=3854 DEP--2104 K-lO TVD=3200 THD=4272 DEP=2436 RECEIVED K-5 TVD=4633 THD=6639 DEP=4320 DEC 1 2]00o A V E R A O E A N O L E ~ Oil & Gas Cons. Commissiq~ 52 DEO 44 H[N T/ ZONE C TVD=6254 THD=9317 ~[~=~1= ~ T/ ZONE A TVD=6293 THD=9381 DEP=6503 ~;, ~-., TARGET CNTR TVD=6356 THD=9485 DEP=6585 ~ B/ KUP SNDS TVD=6418 THD=9588 DEP=6667 TD (LOG PT) TVD=6539 THD=9788 DEP=6826 1 000 2000 3000 4000 5000 6000 7000 VERTICAL SECTION 250 200 I 150 I 100 50 0 50 I I I I 100 150 200 250 300 350 400 450 5OO 000 I j 2000 250 200 / / / / 400 I 2OO 6Boo / / / 200 1400 '400 I 1200 400 1 200 ~00 40O I 400 )00 ,' 400 /"800 ~0 600 800 ~o~- ¢~' 11~1i100 ~600 ~ 800 1800 ~ '~ 1000 RECEIVED Alaska Oil & Gas Cons. Commissiq~ 'Anchorage 150 100 I I 50 0 50 _ 100 150 200 _ 250 _ 300 _ 350 _ 400 _ 450 _ 5OO · DRILLING FLUID PROGRAM (2K-24) Spud to 9-5/8" Drill out to Weight up surface casing weight uo to TD Density 8.8-9.0 8.6-9.4 10.0 PV 15-30 8-10 12-16 YP 20-40 5-8 8-1 2 Viscosity 70-80* 35-40 35-50 Initial Gel 5-15 2-4 4-6 10 Minute Gel 1 5- 30 4 - 8 5 - 1 2 APl Filtrate 10-1 5 7- 9 4- 5 pH 9- 1 0 8.5-9 9.0-10 % Solids 10 +/- 4- 7 <12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED Alaska .0JJ .& l~as C0J35. ¢._o. mmiss[m~ ~ch'0mge Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 2K-24 is 2K-23. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. GENERAl. DRZI.I.ZNG PROCEDURE: KUPARUK R ! VER F !ELD DEVELOPHENT HELLS S HZRU. Znsta11 FI4C dtverter system. 0rtll IZ-U4' hole to g-5/8" surface castng potnt according to directional plan. Run and cemnt g-$/8' casing. Znsta11 and test 80PE. Test casing to ZOO0 pstg. Drill out cement and ZO' new hole. Perform leak off test. Dr111 8-1/2' hole to loggtng potnt according to directional plan. Run open hole logs. · Continue drt111ng 8-Z/2" hole to provtde 100' be~een I~TI) and bottom of Kuparuk sands. Run and cement 7' castng. Pressure test to 3500 pslg. Do~nsqueeze Arcttc pack' and cement tn 7' x 9-S/8' annulus. ND BOPE and tnsta11 temporar~ Xmas tree. 13) Secure vel1 and release rtg. Run cased hole logs. Hove tn ldQrkover rtg. NU BOPE. PU 7' castng scraper and tubtng, TZH to PBTD. Ctrculato hole with clean brtne and TOH standtng tubtng back. 17) Perforate and run completion assembly, set and test packer. ND BOPE and tnsta11 Xmas tree. lg Change over to dtesel. Flow well to tanks. Shut In. Secure well and release rig. Fracture stimulate. RECEIVED o 'c I 1989 Alaska.Oil & ~as Cons. Commissi~ ~chorage OEOASSEII MUO SHALl SHAKIFI8 STIR STill 'rvof~AI Ulln .civ.qTKM ~(:HIrMATIC KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC .I L 6 DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~)N WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1116' 2000 PSI BALL VALVES 4. 20" 2000 PSI DRIM. ING SPOOL W/10' OUTLETS 5. 10' HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVEN3T=FL VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) M^INTE~NANCE & OPERATION 2 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. 3. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. D.O NOT SHUT IN WELL 1989 ^IasEa 0il a Gas Cons. Commissi0~ JG 4/26/88 Anchorage -7 6 DIAGRM gl 13-6/8' 5(II) P~I );~ BOP STACK I. i6' - 21:X30 I:~I T~ ~I~ ~ 4. 1~/8' - ~ ~I PI~ ~ KZ~ LZ~S ^O~t,M,LATCR CAPACITY TEST I. OEO( ~ FILL ~TCR RESERVOIR TO PRCPER LEVEL WITH HYOR.NJ. IC Ft. UID, 2. ASSI,.I~ THAT ACO.M,J.ATI~ ~ I$ ~ PSI 15OO PSI ~~ ~ TIE REGLLATCR. 3. CBSERVE TIIk~ TI-EN ~ AIL UNZ'P3 SIkU. TAI~:CUSI. Y A/~ ~C~ 'T1-E TII~ AN3 ~ RE'I~INING AFTE~ 4. RECORD (IN ~ ~. TI~ ACCRUABLE L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 1:~r"5/8' BCP STACK TEST 4 2 CEIVED I. FILL Bllp STACK ~ ~ MINIFCI.D WITH ARCTIC DIESEL. 2. O=IECK THAT ~ LOCX II]lllll SCREWS IN IlELLI. EAD A~E F1.LLY I~rT~ SEAT T~T R~ IN ~ ~ ~I~ JT ~. ~ IN L~ ~~ LI~ V~~~~~~ ~~ 4. ~~ ~TO~~I ~~F~ I0~ I~ ~ ~~ TO~~I ~~~ I0~ ~O ~~ TO 0 ~l. LI~ V~& ~ T~PI~ ~~~ V~ ~ KI~ ~ ~ LI~ ~ ~ TO ~~Z ~~~Z ~ ]N~ 4. 8. CPEN TCP PIPE RAk~ AI~ CLC~ BOTT(IM PIPE RAkEL TI~T ~OTTC~ PIPE; RAM~ TO 2~0 PSI ~ 3000 PSI. ~. ~ BOTTOM PIPE RAM~ BAO¢ OUT ~ ,Jr A~D I0. CLOSE BLIND ~ ~ TEST TO 2~0 PSI ~ 30C0 PSI. MN~F'I3.D AN3 LII~.5 ~ FLI..L CF M~N.-FR~ING FLUI~ SET AU. VALVES IN CRILLIN6 P(:~ITIC~ 12. TEST ffI'AM~IPE VALVEI%, KELLY, KELLY COO<S. C~ILJ. PIPE SAFETY VALVE, mM) 11~8I!~ BOP TO 250 PSI ~ t000 PSI. FORI~ SIGN, AM3 SEM) TO ERILLIN~ SLI=F. RVI~. VEEKLY THEREAFTER F~ICNN. LY OPERATE BEPE C~ I c,. DEC 19B9 Oil & Gas Cons. Gom issiq Anchorage 5100~4~ L CHECK LIST FOR NEW WELL PERMITS Company ITEM APPROVE DATE YES ./2~g/~9~ ,~. / i 1. Is the permit fee attached ...... -. ................................... ~ (1) Fe.e ' 2. 4. 5. 6. 7. - 8. (8) (9 thru 13') 10. (10 and 13) 12. 13. (2 thru 8) (4) Casg ~,~K /2-/0'=~'~ (14 thru 22) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Lease & Well No. /~L NO ,, , Is well to" be located in a defined pool ............................. ~_ Is well located proper distance from property line .................. ~_ ......... Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat included ................ /~ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... ~ Does operator have a bond in force .................................. ~ · Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~_ Does the well have a unique name and number (23 thru 28) Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrams and descriptions of diverter and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. · (6) (6) Add: ~~,~/~-l~-~ Geology: Engijneering: . rev: 01/30/89 6.011 For 29. 30. 31. 32. · INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE '-/ ?°I"° /-- °,7 1// o,o exploratory and Stratigraphic wells: Are data presented on potential overpressure zones~ · eeeeeeeee®eeeeeee Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. -'~ Additional Re arks~ /- / ~Z
