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Home My WebLink About190-121MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-15 KUPARUK RIV UNIT 3G-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/22/2025 3G-15 50-103-20139-00-00 190-121-0 W SPT 5728 1901210 3000 2629 2629 2628 2628 440 600 600 600 REQVAR P Adam Earl 8/6/2025 MIT-IA tested as per AIO 2C.011 to MAIP 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 3G-15 Inspection Date: Tubing OA Packer Depth 800 3300 3230 3225IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250808085635 BBL Pumped:2.6 BBL Returned:2.1 Monday, September 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-15 KUPARUK RIV UNIT 3G-15 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-15 50-103-20139-00-00 190-121-0 W SPT 5728 1901210 3000 2832 2832 2832 2834 590 820 840 840 REQVAR P Adam Earl 8/1/2023 MIT IA tested as per AIO 2C.011 to max ant. Inj. Psi 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 3G-15 Inspection Date: Tubing OA Packer Depth 1150 3460 3410 3400IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802194408 BBL Pumped:2.2 BBL Returned:2.2 Wednesday, September 20, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 99 9 9 AIO 2C.011 James B. Regg Digitally signed by James B. Regg Date: 2023.09.28 12:17:43 -08'00' MEMORANDUM TO: Jim Regg P.I. Supervisor e 1 , �Z FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3G-15 Insp Num: mitBDB210825102107 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-15 KUPARUK RIV UNIT 3G-15 Src: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-103-20139-00-00 Inspector Name: Brian Bixby Permit Number: 190-121-0 Inspection Date: 8/24/2021 Packer Well 3G-15 (Type Inj w TVD_- .- - _.-_--- PTD 1901210 �iType Test SPT'4est psi BBL Pumped: 2.6 BBL Returned: Interval) REQVAR IP/F Notes: MITIA as per AIO 2C.01 1 ✓ Depth Pretest P Initial 15 Min 30 Min 45 Min 60 Min 5728 Tubing 2750 2750 2750 2750 3000 '� IA 690 3480 " 3430 3420 - I 2.6 OA 500 800 - 800 800- 00 - P V Thursday, August 26, 2021 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg�06I— DATE: Wednesday, October 9, 2019 PJ. Supervisor SUBJECT: Mechanical Integrity Tests ConocoPhiltips Alaska, Inc. 3G-15 FROM: Jeff Jones KUPARUK RIV UNIT 3G-15 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry --02- NON-CONFIDENTIAL l IZNON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-15 API Well Number 50-103-20139-00-00 Inspector Name: Jeff Jones Permit Number: 190-121-0 Inspection Date: 9/16/2019 Insp Num: mitJJ191009072934 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Type lnj TVD 5728 Tubing 2591 - 2591 - 2579- 2606- — Type Test SPT Test psi FPumped: 3000 IA 680 3300 - 3220 - 3200 - 2s ' BBLReturned: 2 OA 590 850 - 850 850_ REQVAR p/F P — i Notes: T x IA communication; 2 yr MIT -IA to MAIP AID 2C.011. 1 well inspected, no exceptions noted Wednesday, October 9, 2019 Page I of 1 Ke" 3q -IS PrU (Rohl, Regg, James B (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, August 17, 2019 10:11 AM To: Wallace, Chris D (CED); Brooks, Phoebe L (CED); Regg, James B (CED); DOA AOGCC Prudhoe Bay VC / Cc: NSK DHD Field Supervisor C� 8 ul �� Subject: KRU 3G Pad SI MIT's Attachments: MIT KRU 3G PAD SI TESTS 08-15-19.xlsx MH Please see the attached MIT test forms for shut in wells 3G-15, 3G-20, & 3G-23 in Kuparuk on 3G pad. Sincerely, SarcoCcwUg& (Neskd v) /2acheLKaatk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549@cop.com Cell: 907-331-7514 1 sara.e.carlisle0cop corn AOGCC REP Well 313-16 STATE OF ALASKA Pressures: Pretest ALASKA OIL AND GAS CONSERVATION COMMISSION 15 Min. 30 Min. 45 Min. Mechanical Integrity Test 4=Four Year Cycle Submit to iim.rean0alaska.00v: AOGCC.InsoectorsAalaska.aov' phoebe.brookstMalaska aov s.wlallacetMalaska.aov Tubing 1560 - 1560 - (/�c'hhi 'F�'J OPERATOR: ConorgPhillips Alaska Inc, Type Test FIELD / UNIT / PAD: Kuparuk / KRU / 3G Pad 5727 BBL Pump 2.8 - DATE: 08/15/19 3300 - 3260" OPERATOR REP: Duffy / Caudle Interval AOGCC REP Well 313-16 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 4=Four Year Cycle F=Fail PTD 1901210Type Inj N Tubing 1560 - 1560 - 1560 ' 1560 — N = Not Inlectin9 Type Test P Packer TVD 5727 BBL Pump 2.8 - IA 200 3300 - 3260" 3250' Interval V Test psi 3000 BBL Return 2.7 - OA 20 20 20 20 Result P Notes: MITIA to maximum anticipated injection pressure per A10 2C.011 Well 3G-20 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901230 Type Inj N Tubing 1245 1260 1245 1245 Type Test P Packer TVD 5796 BBL Pump 2.0 IA 280 2225 2160 2160 Interval 4 Test psi 1500 BBL Return 2.0 OA 0 0 0 0 Result P Notes: Well 3G-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320 Type Inj N Tubing 1810 1810 1810 1810 Type Test P Packer TVD 5745 BBL Pump 3.6 IA 260 3300 3195 3175 Interval V Test psi 3000 BBL Return 3.6 OA 150 575 600 600 Result P Notes: MITIA to maximum anticipated injection pressure per A10 2C.004 Well 3G-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320 Type Inj N Tubing 1810 1810 1810 1810 Type Test P Packer TVD 5745 BBL Pump 1.0 IA 260 260 260 260 Interval V Test psi 1800 BBL Return1.0 OA 750 2000 1960 1940 Result P Notes: MITOA to 1800 psi per AIO 2C.004 Well Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi EEEBBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codas INTERVAL Codes Result Codes W = Water P=P .... to Test I = Inial Test P=P... G=Gas O= Other(descroe in Notes) 4=Four Year Cycle F=Fail S=slurry V= Required by Variance 1=Inconchnros I = Industrial Wastewater O = Other (describe in notes) N = Not Inlectin9 Form 10426 (Revised 01/2017) 2019-ca15_MIT _ KRU_3G-pad3wells RECEIVED STATE OF ALASKA ALADA OIL AND GAS CONSERVATION COMMI•N OCT 2 7 2017 REPORT OF SUNDRY WELL OPERATIONS � �� 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ OperatiorSs sTfutdbwn ❑ Performed: Suspend ❑ Perforate E Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: DAD Acid Trtmnt 2 2.Operator 4.Well Class Before Work: '5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 190-121 3.Address: P. O. Box 100360,Anchorage, Alaska Stratigraphic❑ Service E 6.API Number: 99510 50-103-20139-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3G-15 ADL 25547 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,991 feet Plugs measured None feet true vertical 6,057 feet Junk measured None feet Effective Depth measured 7,876 feet Packer measured 7,531 feet true vertical 5,974 feet true vertical 5,727 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16" 115' MD 115'TVD SURFACE 3,440 feet 9-5/8" 3,475' MD 3001'TVD PRODUCTION 7,930 feet 7" 7,965' MD 6038'TVD Perforation Depth Measured Depth7688-7736 feet S �� True Vertical Depth th 5838-5873 feet DEC 1 8 0 Tubing(size,grade,measured and true vertical depth) 2-7/8" L-80 7,610' MD 5,783'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-CAMCO HRP-1-SP PACKER 7,531'MD 5,727'TVD TRDP-CAMCO'TRDP-IA-SSA' 1,814'MD 1791'ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7688-7736 MD,5838-5873 ND Treatment descriptions including volumes used and final pressure: 100 bbls DAD Acid pumped across Perfs 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 878 1101 psi 2673 psi Subsequent to operation: 0 0 953 1300 psi 2671 psi 14.Attachments(required per 20 AAc 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory ❑ Development p ❑ Service E Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG Q GINJ ❑ SUSP❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-265 Authorized Name: Jason Burke Contact Name: Jason Burke Contact Email: Jason.Burke©cop.com Authorized Title: A&.Staff Wells Engineer /Y' /7- Contact Phone: (907)265-6097 (/ Authorized Signature: Date: 4 Ir7-i- 1717//? PI Plili7 RBDLIS L ' NC' - 2 2617 Form 10-404 Revised 4/2017 Submit Original Only KUP INiii 3G-15 ConocoPhillips ` Well Attribut Max Angle 0 TD A188kii,lilt;. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btre(ftKB) CorlocaPhillipz 501032013900 KUPARUK RIVER UNIT INJ 49.67 3,400.00 7,991.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3G-15.1025/2917944:29 PM SSSV:TRDP Last WO: 36.78 10/18/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,679.0 6/14/2014 Rev Reason:ADD WAIVER NOTE hipshkf 1/20/2015 HANGER;31.4 Casing Strings Casing Description OD(in) ID(in) TopftKB Set Depth(ftKB) Set Depth(TVD).,. Wt/Len(I...Grade Top Thread P 1 ( ) 1 P I ) CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED "- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,474.5 3,001.0 36.00 J-55 BTC L ,,,"Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD(... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,965.1 6,038.5 26.00 J-55 BTC Tubing Strings Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft.Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 27/8 2.441 31.3 7,609.9 5,783.0 6.50 L-80 EUE8rdABMOD IICompletion Details .�y� TopftKB (TVD)ftKB Top Incl l') Item Des Com Nominal ID ` l I Top ( ) (in) CONDUCTOR;36.0-115.0 31.3 31.3 0.07 HANGER WKM GEN IV HANGER 3.500 64.7 64.7 0.15 XO Reducing CROSSOVER 3.5 x 2.875 2.875 I 1,813.9 1,790.9 26.11 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE. LOCKED OUT 2.312 6/13/2014 SAFETY VLV;1,873.9 Fel7,513.1 5,714.7 45.21 PBR CAMCO OEJ PBR 2.312 7,530.6 5,727.1 45.21 PACKER CAMCO HRP-1-SP PACKER 2.340 MI 7,601.6 5,777.1 45.19 NIPPLE CAMCO D NIPPLE NO GO 2.25 CA-2 PLUG,CATCHER 2.250 GAS LIFT;2,422.9 7,609.2 5,782.5 45.13 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots shot Den Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,688.0 7,704.0 5,838.4 5,849.8 C-4,A-2,3G- 8/28/1991 6.0 APERF 2 1/8"EnerJet;0 deg. 15 phasing;Oriented(+/-) SURFACE,35.0-3,474.5-t 45 deg.F/Lowside 7,704.0 7,736.0 5,849.8 5,872.7 A-2,3G-15 1/10/1991 4.0 IPERF 4 1/2"Expendable;180 deg.phasing Mandrel Inserts St GAS LIFT,4,397.7 A ati N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,422.9 2,295.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/14/1993 GAS LIFT.5,281sII 2 4,397.7 3,605.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 3 5,281.6 4,192.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 4 6,265.1 4,854.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/14/1993 111 5 6,900.8 5,285.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 GAS LIFT.0.205.1 6 7,470.8 5,685.0 MERLA TGPD 11/2 GAS LIFT DMY RK 0.000 0.0 10/1/2014 WI PKG 7 7,554.5 5,743.9 MERLA TGPD 11/2 INJ DMY RK 0.000 0.0 1/12/1991 GAS LIFT.5.900 aII Notes:General&Safety End Date Annotation 8/31/2010 NOTE:View Schematic w/Alaska Schematic9.0 1/20/2015 NOTE: T x IA COMMUNICATION WHILE ON GAS INJECTION GAS LIFT;7,470.8 PBR;7.513.1 II. PACKER;7,530.6 INJECTION;7.554.5 NIPPLE;7,601.6 SOS,7.6092 II APERF;7,688.0-7,704.0-r (PERF;7.704.0-7,736.0-. PRODUCTION,35 0-7,965.1 . • • 3G-15 DTTMSTART JOBTYP SUMMARYOPS 10/1/17 ACID RIH TO 7740' CTMD, INJECT 100 BBLS DAD ACID ACROSS PERFS FROM 7740'-7610', TURN OVER TO DSO, (JOB COMPLETE) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re � DATE: Thursday,August 10,2017 gg z, P.I.Supervisor `� 1f(2(�l 7 SUBJECT : Mechanical Integrity Tests ( CONOCOPHILLIPS ALASKA,INC. 3G-15 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-15 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry t1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-15API Well Number 50-103-20139-00-00 Inspector Name: Chuck Scheve Permit Number: 190-121-0 Inspection Date: 8/5/2017 — Insp Num: mitCS170806071329 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-15 - Type Inj W TVD 5728 Tubing 2704 2701 ' 2700 • 2675 - PTD 1901210 Type Test SPT Test psi 3000 - IA 950 3390 - 3330 3310 - BBL Pumped: 2.2 • BBL Returned: 2.3 OA 460 710 - 720 - 720 - Interval REQVAR P/F P Notes: Tested per A1O 2C.011 SCANtNED1_ , ;Y, Thursday,August 10,2017 Page 1 of 1 • • of yys THE STATE Alaska Oil and Gas o Conservation Commission fALAs A 333 West Seventh Avenue 1Sr#z Anchorage,OF Alaska 99501-3572 „P - GOVERNOR BILL WALKER Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer ConocoPhillips Alaska, Inc. SCANNED JUL. 0 7 '.01 P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 3G-15 Permit to Drill Number: 190-121 Sundry Number: 317-265 Dear Mr. Burke: 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, Daniel T. Seamount,Jr. Commissioner DATED this csur day of June, 2017. RBDMS JUN 2 7 2017 • RECEIVED STATE OF ALASKA JUN X 5 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate Er— Pull Tubing 0 Change Approved Pr99ram❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 0 Other: Acid Stimulate❑• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 190-121 • 3.Address: Stratigraphic ❑ Service 0 • 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20139-00-e-r) 7.If perforating: 8.Well Name and Number: y\ What Regulation or Conservation Order governs well spacing in this pool? N/A 'b 0 KRU 3G-15 Will planned perforations require a spacing exception? Yes 0 No U 9.Property Designation(Lease Number): , ,4) (firf7 10.Field/Pool(s): ADL 25547 ` 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): 7,991' ' 6,057' • 7876 5974 3502psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 79' 16" 115' 115' Surface 3,440' 12" 3,475' 3,001' Intermediate Production 7,930' 7" 7,965' 6,038' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7688-7704,7704-7736 5838-5850,5850-5873 2.875" L-80 7,610' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-CAMCO HRP-1-SP PACKER MD=7531 TVD=5727 SSSV:CAMCO TRDP-1A-SSA MD=1814 TVD=1791 12.Attachments: Proposal Summary 2 Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory 0 Stratigraphic 0 Development❑ Service 0 ' 14.Estimated Date for 7/1/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 ' GSTOR ❑ SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com .--- Contact Phone: (907)265-6097 Authorized Signat4cerDate: / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Nr, (c � (1.Z/_ 1 ' Other: � �O Post Initial Injection MIT Req'd? Yes 0 NoRBDMS 0— kips L 7 2017 Spacing Exception Required? Yes ❑ No Subsequent Form Required: APPROVED BY /Z6 117 Approved by:. j). COMMISSIONER THE COMMISSION Date: l V`7L ‘,/7a11�- O R 1 1 J'� Submit Form and Form 10-403 Revised 4/2017 i s valid for 12 months from the date of approval. p' Attachment in Duplicate �t11r 6- /1 / 7 • • • ConocoPhillips Alaska,Inc. ►-' Drilling&Wells ConocoPhillips Well Intervention Alaska 3G-15 Acid Treatment (TBD) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with • dispersing agent F 103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars,perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU 1.5" CT, MU 5 port wash nozzle BHA 2. Begin RIH down to 7740' MD. 3. When CT has reached depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH to 7610'. Continue injecting DAD into formation and it out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 4. After an additional 5 bbl of fluid has been injected behind the treatment POOH 5. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal June 7, 2017 3G-15 Well Work Procedure Page 1 of 1 ` KUP 3G-15 econocoPhilt ps `: Ing Well Attribu Max Angl D TD AlBS„kd' I6)0 " - Wel!bore APIJUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) CaacephilIips 501032013900 KUPARUK RIVER UNIT INJ 49.67 3,400.00 7,991.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-15,6/13/2017 3.38.42 PM SSSV:TRDP Last WO: 36.78 10/18/1990 - Verbal schematic(actual) Annotation Depth(ftKB) End Date Annotation last Mod By End Date Last Tag:SLM 7,679.0 6/14/2014 Rev Reason:ADD WAIVER NOTE hipshkf 1/20/2015 HANGER;31.4 I 'a 1 Casing Strings Casing Description OD(in) ID(in) Top' (ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED • Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade "Top Thread SURFACE 9518 8.921 35.0 3,474.5 3,001.0 36.00 J-55 BTC g OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(l...-Grade Top Thread ""`°""""°°°"�°'"`""`a"1` �" OO1'CasinPRODUCTIONDescription 7 6.276 35.0 7,965.1 6,038.5 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..,Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 2 7/8 2.441 31.3 7,609.9 5,783.0 6.50 L-80 EUE8rdABMOD 7 Completion Details --• Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;36.0-115.0 31.3 31.3 0.07 HANGER WKM GEN IV HANGER 3.500 64.7 64.7 0.15 XO Reducing 'CROSSOVER 3.5 x 2.875 2.875 I 1,813.9 1,790.9 26.11 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE. LOCKED OUT 2.312 6/13/2014 SAFETY VLV;1,813.9 rl, 7,513.1 5,714.7 45.21 PBR CAMCO OEJ PBR 2.312 al 7,530.6 5,727.1 45.21 PACKER CAMCO HRP-1-SP PACKER 2.340 7,601.6 5,777.1 45.19 NIPPLE CAMCO D NIPPLE NO GO 225 CA-2 PLUG,CATCHER 2.250 GAS LIFT,2,422.9 7,609.2. 5,782.5 45.13 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots) Top(065) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com - 7,688.0 7,704.0 5,838.4 5,849.8 C-4,A-2,3G- 8/28/1991 6.0 APERF 2 1/8"EnerJet;0 deg. 15 phasing;Oriented(+/-) SURFACE,3503474.5^- I 45 deg.F/Lowside 7,704.0 7,736.0 5,849.8 5,872.7 A-2,3G-15 1/10/1991 4.0 IPERF '4 1/2"Expendable;180 deg.phasing Mandrel Inserts at GAS LIFT;4,397.7 ti N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sera Type Type (in) (psi) Run Date Com 1 2,422.9 2,295.7 MERLA TMPD ' 1 GAS LIFT DMY BK 0.000' 0.0 5/14/1993 GAS LIFT;5,281.6 2 4,397.7 3,605.1 MERLA TMPD 1 GAS LIFT DMY BK - 0.000 0.0 1/12/1991 3 5,281.6 4,192.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 I4 6,265.1 4,854.5 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/14/1993 5 6,900.8 5,285.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1/12/1991 GAS LIFT;6,205.1al 6 7,470.8 5,685.0 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 10/1/2014 WI I PKG 7 7,554.5 5,743.9 MERLA TGPD 11/2 INJ DMY RK 0.000 0.0 1/12/1991 GAS LIFT;0,9008 ,Notes:General&Safety li End Date Annotation III 8/31/2010 NOTE:View Schematic w/Alaska Schematic9 0 1/20/2015 NOTE:T x IA COMMUNICATION WHILE ON GAS INJECTION GAS LIFT,7,470.8 FOR.7,513.1 .. PACKER;7,530.6 INJECTION;7,554.5 III NIPPLE;7,601.6 111 SOS,7,6092 li APERF;7,666.0-7,704.0-. IPERF;7,704.0-7,736.0----. PRODUCTION;35.0-7,965.1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,June 13,2016 Jim Regg 1 ce P.I.Supervisor (` 1�I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-15 FROM: Matt Herrera KUPARUK RIV UNIT 3G-I5 Petroleum Inspector Sre: Inspector Reviewed By:/� P.I.Supry r ige- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-15 API Well Number 50-103-20139-00-00 Inspector Name: Matt Herrera Permit Number: 190-121-0 Inspection Date: 6/1/2016 Insp Num: mitMFH160603145300 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-15 Type Inj W TVD 5728 Tubing 2608 . 2608' 2608 2608 , PTD 1901210 Type Test SPT Test psi 3000 IA 960 ' 3300 3250 3240 - Interval lREQvAR P/F P ✓ OA 415 660 660 - 660 Notes: AIO 2C.011 SCANNED DEC 2 92016 Monday,June 13,2016 Page 1 of 1 XHVZE Pages NOT Scanned in this Well History File 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. flo--[2l File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: Other- Pages: DIGITAL DATA Diskettes, No. Other, No/Type OVERSIZED .n' Logs 'of various .kinds . [] Other Scanned by: Dianna Vincent Nathan Lowell __ n TO RE-SCAN Notes:. Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Regg�, P.I. Supervisor t � ! I( SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -15 FROM: Jeff Jones KUPARUK RIV UNIT 3G -15 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry 0 NON Comm Well Name: KUPARUK RIV UNIT 3G - 15 API Well Number: 50 103 - 20139 - 00 - 00 Inspector Name: Jeff Jones Insp Num: mitJJ110906082813 Permit Number: 190 - 121 - Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well r 3G -15 Type Inj. G TVD r 5728 IA 1150 I 2160 "2110 2110 ' P.T.D 1901210 TypeTest SPT Test psi 1500 , 1 OA 240 300 300 300 Interval 4YRTST P/F P _ Tubing 3606 3629 3628 3649 Notes: 1 BBL diesel pumped. I well inspected; 6 exceptions noted: casing adapter L/D leaking, 5 bolts not properly engaged on well head. Mr. Mouser to initiate repair. r I; Wednesday, September 07, 2011 Page 1 of 1 ~ ~ COI'lOC ~ ~ ~ oPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder ~ ` ~ .~'t Aiaska Oil & Gas Commission ~~ r 333 West 7~' Avenue, Suite 100 ~~~ Anchorage,AK99501 s~~~34,~,,,~ _a . '.'~L~'= ~~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treahnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~`, 9~' and l Oth 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please ca11 Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, a~~~" ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 zr_ zu ~~ sr. ~n o~a ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ,..,~ Corrosion inhibitor . Corrosion inhibitor/ sealant date bbis al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n/a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'5" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50103200860000 1871120 17" n/a 17" n/a 5.52 8/8/2009 3H-106 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 8/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n/a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a Na 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8l2009 3Q-13 50029216640000 1861760 44'6" 5.OQ 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' S.25 30" 7/30l2009 8.5 8/8/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~S~;:~isor ~e11 ~1~¡D7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-15 KUPARUK RlV UNIT 3G-15 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv SSg. Comm NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 3G-15 API Well Number: 50-103-20139-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820171959 Permit Number: 190-121-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-15 Type Inj. G TVD 5727 .; IA 1350 2500 2490 2490 1".1. 'V'~" I ypu est ;)rl Test psi 1500 uA 440 520 520 520 Interval 4YRTST / P/F P / Tubing 3680 3680 3680 3680 Notes: Pretest pressures observed for 30+ minutes and found stable. ,/ SCANNED SEP 1 o 2007 . Wednesday, August 22, 2007 Page 1 of I 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: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk/KRU/3G DATE: 08/04/03 OPERATOR REP: Arend/Brake - APC AOGCC REP' Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. IType Inj T.V.D.15789I Tubing] 2000]2oooI 2oeoI 2oeoIInterval P.T.D. I1900840I Type Test Test psiI 1500 I Casing ] 13501 24601 24201 24201 P/F Notes: 2 Yr MIT required by internal Waiver Well 13G-12 P.T.D. 11900730 Notes: Type Test Test psil 1500 I Casing I 12501 23501 23001 22801 P/F Well J3G-13 P.T.D. J1901160 Notes: Type Test Test psiI 1500 I Casing I 11401 24001 23801 23801 P/F P.T.D.}1901210I IType TestP I Test psiI 1500 I Casing I 12401 24501 24251 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test Well13G-16 I Type Inj P.T.D. I1901040 Type Test Notes: T.V.D. 15764 I Tubingl 31001 31001 31001 310011nterva, Test psiI 1500 I CasingI 13001 24001 24001 24001 P/F Well 13G.24 P.T.D. I1901340 Notes: TypeTest Test psiI 1500 I Casing I 12001 21001 21001 21001 P/F 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 ~c/~t~,~E~ SEF .I. 5 2003 MIT KRU 3G 08-04-03.xls 8/5/2OO3 MEMORANDUM ,. State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Randy Ruedrich Commissioner Jim Regg /'~t~ P.I. Supervisor DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. We,,I 3~-~o IT~,~.,¢.I S I T.~.D. I~ I Tu~i,~l 2000 I=ooo i~ooo I~ooo I,,,~rv~,l ~ P.T.D.I 190-084 ITypetestl P ITestpsil 1447 I Casingl 1350I 2460I 2420I 2420I P/F I P Notes: w~.,I 3~-~ IT~,~,,i.I ~ I~'v'~' I ~ I Tubingl235012350 12350 1~3~0 I,,,~rv~,l ~ P.T.D.I 190-073 ITypetestl P ITestpsil 1422 ICasingI 1250I 2350I 2300I 2280I P/F I P Notes: P.T.D. Notes: P.,.D. Notes: VVe, P.*.D. Notes: P.T.D. Notes: 190-t16 ITypetestl P ITestpsil 1445 I Casingl 1140I 2400I 2380I 2380I P/F '1 P 190-121ITypetestl P ITestpsil 1432 I Casingl 1240I 2450I 2425I 2425 I P/F I --P 190-104ITypetestl P ITestpsil 1441 I Casingl 1300 I 2400 I 2400 I 2400I P/FI P 190-134ITypetestl P ITestpsil 1429 I CasingI 1200I 2100I 2100I 2100I P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S -- SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3G Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0804_M IT_KRU_3G-24_cs.xls 8/15/2003 (' STATE OF ALASKA (~' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Abandon ..... BI' 'suspend "Eli .... 0p~ati~n"shuidow~i E] perf~raie"'E] ......... Varia~ce'' r"'J AnnuiarDisp,'[--'~ · !~,;::! .Alter Casing .El RepairWell E~ Plug:Perf°rati°nS E] · stimulate E] · . ...Time'ExtenSion E] Other [~'~' i!;i!i . Change Approved Program . E~ Pull Tubing' r-'] · Perf0ra'{e New Pool E] ..Re-enter SusPended Well 2. Operator Name: ". zt. Current. Well statb~:" ·" · 5. Permit to Drill Number: , ConocoPhillips Alaska, Inc. . Dey.el0pment E] ExploratorY r-] · 190-121 / 3. Address: Stratig~aphic' O Service r~. · 6. APl Number: P. O. Box 100360 · 50-103-20139-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 90' 3G-15 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7991' feet true vertical 6057' feet Plugs (measured) Effective Depth measured 7876 feet Junk (measured) true vertical 5974 feet , . Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 115' 16" 115' 115' SUP. CASING 3384' 9-5/8" 3474' 3001' PROD. CASING 7875' 7" 7965' 6038' RECEIVED Perforation depth: Measured depth: 7688-7736 true vertical depth: 5838- 5873 J U N 2 ,~ 2 0 0 3 Alaska Oil & Gas Coils,, Commissie~ Tubing (size, grade, and measured depth) 2-7/8", L-80, 7610' MD. ADchoraoe Packers & SSSV (type & measured depth) pkr= CAMCO 'HRP-1-SP' pkr= 7531' SSSV= SSSV SSSV= 1814' · 12. Stimulation or cemeht squeeze summary: . .' · ... : Intervals treated (measured) ' .'N/A . .' ' . · · · · . · Treatment descriptions including V(~!u.mes used'and final pressure: '. · · . . . · 13.' · ." ... " .': . ," .'Representative'Da[ly Average Production or Injection D~ta · .. . , ............. · , · · ' " .' . ... Oil-Bbl. ,. .. Gas;Mcf ' · .... ' .Water~BIsI '. iCasin,q Pressure T0bin.q Pressure' .. Pdor towell·opera(ion .: · 69Y ' . 200, .' .. 2718..' · SubSequent'to operation .' .' 2374 ' · · 50 ' 345.8 .. · . :14..Attachmei-its .... ... ..... .15. Well·class after proposed work': . . . . .. .. · · . . . Copies of Logs an~l Surveys ~un -~- Exploratory 'D.. Oe~el;DPment' ['"]' · Se~vi~e [~ ..... . .Dai'ly Report of Well Operations "X 16.' Well'Statt~s 'after proposed .work: :.. · · .. Oilr-~ Gas[~ WAG. r'~ ' GINJF-~ WINJ ~ 'WDSPLF--~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.C. Exempt: I Contact Jeff Spencer @ 659-7226 Printed Name Robert D. Christens~n Title i:; !:!:.;!!~:!!;~i Production Engineering Technician Signature ~?~,~..,~ ~/~~~j Phone 659-7535 Date 6/19/03 Fo~~,2003 o'~ ~ ? ~ ORIGI ':JUL 0 9'Y IN DUPLICATE 3G-15 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 61161o31C~~:'WAG EOR' lnjecti°n' ' " ':1 I I I I ARCO Alaska, Inc. Post Office i-}ox July 7, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in duplicate are multiple Report of Sundry Well Operations (Form 10-404) notices in the Kuparuk field. The wells are listed below. WELL ACTION 3G-15 Conversion 3H-13 Stimulate 3K-16 Stimulate If you have any questions, please call me at 263-4241. Sincerely, P. S. White Sr. Engineer Kuparuk Petroleum Engineering RE(lEaVED J U L - .9 t99~ Alaska 0il & 6as Cons. 6omr~iss~O~ Anchorage A~CO Alaska, inc. is a Subsidiary of STATE OF ALASKA ALA:Sr,,A OIL AND GAS CONSERVATION COMMISS~'N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing ~ Re--'~air well Otherx, "~',/~ 2. Name of Operator 5. Type of Well: \....v 6. Datum elevation (DF c;r KB) //~-~ Development __~ ARCO Alaska. Inc. Exploratory RKB 90' feet 3. Address P. O. Box 100360, Anchorage, AK Stratigraphic 99510 Service Location of well at surface 2538' FNL, 45' FEL, Sec. 23, T12N, RSE, UM At top of productive interval 1405' FSL, 985' FWL, Sec. 23, T12N, RSE, UM At effective depth 1382' FNL, 859' FWL, Sec. 23, T12N, RSE, UM At total depth 1364' FSL, 781' FWL, Sec. 23, T12N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 7991 ' feet Plugs (measured) 6057' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number/approval number ~)0-121 / ~)3-113 10. APl number 50-1o3-2o13900 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7876' feet Junk (measured) 5974' feet 13. Casing Length Structural Conductor 78' Surface 3438' Intermediate Production 7928' Liner Perforation depth: measured 7688'-7704' true vertical 5838'-5850' Size Cemented 16" 211SxASI 9-5/8" 765SXAS III & 460 Sx Class G 7" 175 Sx Class G Tubing (size, grade, and measured depth) 2-7/8"6.5#, EUE, ABMOD, @7610' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA @1814', Packer: Camco HRP-1-SP @ 7531' Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL Intervals treated (measured) Treatment description including volumes used and final pressure Measured dep~ True vertical depth 115' 115' 3475' 3001' 7965' 6038 .alaska& t',-,,',,; ...... 'Anchorage 14. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure 38 105 1851 1204 Tubing Pressure 188 Subsec~uent to operation 0 0 0 25 59 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. Si~]ned , Title Petroleum Engineer Form 10-404 Rev 09/12/90 /" Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary. of Atlantic Richfield Company WELL DATE DAY / TIME KUPARUK RIVER UNIT WELL SERVICE REPORT DF..SCRIFI'ION OF WORK CONTRACTOR/~Y P~SON ] F~D COST ~T,. PBTD ~) ] LAST TAG (R~ATE SSSV TYPE / STATUS ! LOG ~Y AFC/CC# ACCUMULA'I]d} COST PAGE 1 OF KUPARUK PETROLEUM ENGINEERING i Gas Cons. ,,,- CHECK TI~_5 BLOCK IF SUMMARY coNTINUED ON BACK ] [-~COMPLETE ' ~'] INCO~ eather Report Il Temp. ~ Chill Factor j Visibility. [ Wind Vel. I Signed/~.~ ~. ARCO Alaska, Inc. Post Office B~,^ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 11, 1993 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approvals on the following Kuparuk well. Well Action 3G-15 Conv. to WI Anticipated Start Date May 1993 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering Attachments RE 'EIVEP Alaska 0il & Gas 0ohs. O0mmissior; ~.nch0rage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany A[~37,¥;00:~ C STATE OF ALASKA ALAbr,,A OIL AND GAS CONSERVATION COMMIS,~iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Alter casing __ Repair well Change approved program X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 45' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 1405' FSL, 985' FWL, Sec. 23, T12N, R8E, UM At effective depth 1382' FNL, 859' FWL, Sec. 23, T12N, R8E, UM At total depth 1364' FSL, 781' FWL, Sec. 23, T12N, R8E, UM Shutdown __ Re-enter suspended well __~,/,,,~/.. Operation _ Plugging __ Time extension _ Stimulate _ ' Pull tubing __ Variance _ Perforate __ Other 5. Type of Well' 6. Datum elevation (DF or KB) Development ~X Exploratory _ RKB ~)0' feet Stratigraphic _ 7. Unit or Property name Service __ Kuparuk River Unit 8. Well number 3G-15 9. Permit number 90-121 10. APl number s0-103-20139 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical 7991' 6057' 7876' 5974' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3475' 9 5/8" Intermediate Production 7 0 3 1 ' 7" Liner Perforation depth: measured 7688'-7704' true vertical 5838'-5850' Tubing (size, grade, and measured depth) 2-7/8"6.5#, EUE, ABMOD, @7610' Packers and SSSV (type and measured depth) feet Plugs (measured) feet None feet Junk (measured) feet None Cemented 211 Sx AS I 765 Sx AS III & 460 Sx Class G 175 Sx Class G Measured depth 115' 3475' 7965' True vertical depth 115' 3001 ' 6038' 4AY 1 1 199 Alaska Oil & Gas Cons. Coril~JssJof~ Anchorag~ SSSV: Camco TRDP-1A-SSA (1 814'), Packer: 13. Attachments Description summary of proposal ~X Convert well from oil producer to water injector. 14. Estimated date for commencing operation May. 1993 16. If proposal was verbally approved Name of approver Date approved Camco HRP-1-SP (7531') Detailed operation program BOP sketch -- 15. Status of well classification as: Oil Gas Suspended __ Service Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed C-~t). ~ Title Operations Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test _ Location clearance __ Mechanical Integrity Test ,z~ Subsequent form require 10- Approved by order of the Commission Original o,gnecl By David W. johnston IApproval N~. ,.; odg'J ,7 "'".' '-o .3'"-:"; ' '.; Commissioner Date Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE Attachment 1 Conversion to Water Injection Kuparuk Well 3G-15 ARCO Alaska requests approval to convert Well 3G-15 from an oil producer to a water injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 7688' and 7807'. This interval correlates with the strata found in ARCO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Aiaska 0[I & Gas :..,on,.,. L. Estrada/H. Scherffius Page 2 5/10/93 WATER INJECTION CONVERSION PROCEDURE WELLS 3G-13 May 10, 1993 AFC NUMBERS' Downhole Work - #K84386 Facilities Work- #K84394 CONVERSION PROCEDURE' 1. MIRU slick line unit. RIH and tag fill. 2. Replace GLV's with DV's. Freeze protect well as necessary w/diesel. . Conduct MIT. The state should be notified a few days prior to performing the MIT so they can witness the test. . SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2.0" meter runs, and calibrate instrumentation. , After well has been shut in for at least 72 hours, contact Onsite Petroleum Engineer (x7636) to record wellhead pressure and shoot tubing fluid level. This information will be used for waterflood surveillance. , Begin injection, eventually working up to a flow rate of approximately 4000 BWPD. API#: 50-103-20139 SPUD DATE' 10/12/90 KL,?ARUK WELL PRODUCTION WELL ADL LEASE: 25547 CC~PLETION DATE: 01/12/91 PERMIT#: 90-121 WORKOVER DATE' SURFACE LOCATION: 2538' FNL, 45' FEL, SEC 23, T12N, R8E, UM ORIGINAL RKB: 90 TOP OF KUPARUK: 1385' FNL, 1110' FWL, SEC 23, T12N, R8E, UM TUBING SPOOL: 31 TD LOCATION: 1324' FNL, 893' FWL, SEC 23, T12N, R8E, UM PAD ELEVATION: 53 All [Depths are MD-RKB to top of equipment unless otherwise noted 3-1/8" WKM GEN IV HGR CASING and TUBING DETAILS SIZE WEIGHT GRADE 16" 62.5 H-40 9. 625" 36.0 J-55 7" 26.0 J-55 3.5" 9.3 J-55 2.875" 6.5 L-80 DEPTH 115' 3475' 7964' 65' 7610' MISC. DATA DE SCRIP T ION KICK OFF POINT: MAX HOLE ANGLE: 50° ANGLE THRU KUP: 44° TVD TO UPPER PKR: TVD TO TOP C SD PERF TVD TO TOP A SD PERF VOLUME TO TT VOLUME TT TO TOP PERF VOLUME 7" ANNULUS 1100' 3400' 5727' N/A 5838' 44.0 BBLS 3.0 BBLS 227.0 BBLS PERFORATION DATA INTERVAL ZONE SPF PHASE COMME~S 7688-7704 A3 6 90° 2-1/8" GUNS 7704-7736 A2 4 180° 4-1/2" GUNS L 65': 3-1/2" X 2-7/8" X-OVER 1814': CAMCO TRDP-1A-SSA SSSV (2.312" I.D.) 2423': MERLA TMPD 1" GLM (3/16" GLV) 4398': MERLA TMPD 1" GLM (DV) 5282': MERLA TMPD 1" GLM (DV) 6265': MERLA TMPD 1" GLM (1/4" GLV) 6901': MERLA TMPD 1" GLM (DV) 7471': M~..RLA TGPD 1.5" GLM (3/8" GLV) 7513': CAMCO OEJ 7531': CAMCO HRP-1-SP PKR 7555' : MERLA TGPD 1.5" GLM (DV) 7602' : CAMCO D NIPPLE (2.25" I.D.) 7609': CAMCO PE-500 SHEAR OUT SUB 7802': LAST TAG (01/01/93) ~- 7876': PBTD (5974' SUB-SEA) Anchora~-~e REVISION DATE: 04/29/93 REASON: NEW SCHEMATIC BY: IGC 1, Operation Performed: STATE OF ALASKA 0 ~ ~ ~ ~.~ A ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well 2. Name of Operator AR(;;O Al{~ska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service Other 4. Location of well at surface 2538' FNL, 45' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 6. Datum elevation (DF or KB) ~)0' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-15 9. Permit number/approval number 1405' FSL, 985' FWL, Sec. 23, T12N, At effective depth 1405' FSL, 985' FWL, Sec. 23, T12N, At total depth 1364' FSL, 781' FWL, Sec. 23, T12N, 12. Present well condition summary Total Depth: measured 7 true vertical 6 R8E, UM R8E, UM R8E, UM 90-121 10. APl number 5o-103-20139 11. Field/Pool Kuparuk River Oil Pool 991 ' 057' feet Plugs (measured) feet None Effective depth: measured 7 6 8 8' true vertical 5 8 3 8' Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3 4 7 5' 9 - 5 / 8" Intermediate Production 703 1 ' 7" Liner Perforation depth: measured 7688'-7704' true vertical 5838'-5850' feet Junk (measured) feet None Cemented Measured depth True vertical depth 217 Sx AS I 1 1 5' 1 15' 765 Sx AS III & 3475' 3001' 460 Sx Class G 175 Sx Class G 7965' 6038' Tubing (size, grade, and measured depth) 2-7/8"6.5#, EUE, ABMOD, @7610' Packers and SSSV (type and measured depth) SSSV: Camco TRDP-1A-SSA (1814'), Packer: 13. Stimulation or cement squeeze summary Perforate 7688'-7704' Intervals treated (measured) RECEIVED JAN 2 8 t992 Alaska 0ii & Gas Cons. c0mmiss~0n Anchorage Camco HRP-1-SP (7531') Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure -558-/ -947- 0- 1300 -525-"" -861- O- 1120 Tubing Pressure 168 153 15. Attachments 16. Status of well classification as: Water Injector__ Copies of Logs and Surveys run __ Daily Report of Well Operations X Oil X Gas Suspended ;17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Si(;jned ~, [z). ~ Title Form 10-404 Rev 09/12/90 0 En ' Date / SUBMIT IN DUPLICATE ARCO Alaska, Inc. :~' Subsidiary of Atlantic Richfield Company WELL SERVICE REPORT ,ELL iPBDT _. ~'~ -/:' REMARKS ~ - ]1~0 / ~/o · ,',Jr 'a __ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather :Temp. !Chill Factor Report oF ' oF Visibility 'Wind Vel. l , , Signed miles: knots i DIST: ORIG - NSK KOE FILES DSENG KOE FILES DS FOREMAN NSK CENT FILES KUPARUK OPERATIONS ENGINEERING PERFORATION RECORD WEL~. NAME: ,~ G- I~'".,/~A~,l~ / ENG REP: TIED IN WI~: '~D~ DATED COMPLETION ~AILS: GUH INFO: ,SPF: SERV. 'CO' & t:NG: ~.~ uJ -~ ~E..£.~f,f-~ ~ PERF INTERVAL: SAND ,Cz/(.. INT "'7~g,~*"'*"/~O~ SAND INT SAND INT GUN PROPOSED PROPOSED GUN CCL CCL RUN PERFORATION8 PERFORATIONS LENGTH TO TOP SETTING NO. (md-OIL) (md-CET) ( ~1 ) SHOT DEPTH COMMENTS TIME GUN SHOT mmmmmm mmmmmmm~m . STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL [~] GAS r--] SUSPENDED F--'] ABANDONED [~ SERVICE ~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-121 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20139 ~: ' 9 Unit or Lease Name 4 Location of well at surface i ~J~ 2538' FNL, 45' FEL, SEC 23, T12N, RSE, UM !i'/~"/~..~j:' ~;~ " -'ii L...'2 ~ .............. "'/i:. ;.~; - ~ '~ r-'' -:'u-~-)"'-"h.S~ KUPARUK RIVER AtTop Producing Interval ~ ........... 10 Well Number ?:!; t -!;:!~ i;; f 3G-15 At Total Depth _ 11 Fieid and Pool 1364' FNL, 780' FWL, SEC 23, T12N, R8E, UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25547 ALK 2661 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 10/12/90. 10/16/90. 4/-H-/91. NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+rVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permafrost 7991' MD, 6057' TVD 7876' MD, 5974' TVD YES [~ NO [--]I 1814' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SE'I-rING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 217 SX AS I 9-5/8" 36# J-55 SURF 3475' 12-1/4" 765 SX AS III, 460 SX CLASS G 7" 26~ J-55 SURF 7965' 8-1/2" 175 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 7610' 7531' 7704'-7736' W/4-1/' CSG GUN @4SPF MD 5850'-5873 TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST iDate First Production JMethod of Operation (Flowing, gas lift, etc.) I DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD ~ FlowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ·. ~-- .. "w/Or~.r,.;~ ' .. .... Form 10-407 Submit ~n dO~ticate 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 VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7688' 58,.~' NA KUPARUK C Be'FI'OM 7695' 5843' KUPARUK A TOP 7695' 5843' KUPARUK A BOTrOM 7807' 5924' 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~'~----~"'~ ~ Title AREA DRILLING ENGINEER Date ~-'~/~--' ~./'/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repeal 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 ARCO Oil and Gas Company Well History - Initial Report - Daily Inslructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are stalled. Daily work prior to spudding should be summarized on the form Giving inclusive dates only. District ARCO ALASKA INC. Field KUPARUK RIVER UNIT lCounty, parish or borough NORTH SLOPE Lease or Unit Title ADL:25547 ALK: 2661 COMP LET I ON Slate AK Well no. 3G~15 Auth. or W.O. no. AK5261 Operator ARCO Spudded or W.O. begun SPUD J ARCO W, 55.252072 I°ate10/12/90 I"°ur 18:00 IPrierslat~s'faw'°' Date and depth as of 8:00 a.m. 01/11/91 ( 8) TD: 0 PB: 7876 SUPV:GB/SK Complete record for each day reposed NORDIC 1 RUNNING 2-7/8" COMP ASSY MW:10.7 NaC1/Br MOVE RIG F/3G-23 TO 3G-15, RIG ACCEPTED 1/10/91 @ 14:00, ND MASTER VALVE, NU BOPE, TEST, RU HLS & PERF IN TWO RUNS F/7704'-7736' W/4.5" CSG GUNS @ 4 SPF AND 180 DEG PHASE AND ALTERNATING BIG HOLE CHARGES, NU FLOW LINE, RU & RUN 2-7/8" COMP ASSY, 96 JTS IN @ 06:00 DAILY:S50,301 CUM:$971,148 ETD:S971,148 EFC:$1,230,000 The above is correct Signature ~ ~ . For form preparation and distribu/W~, see Procedures Manual, Section Drilling, Pages 86 and 87, Date I Title AR3B-459-1-D INumberall daity well history forms consecutively no. as they are prepared for each well. ~ ~Page ARCO Oi~ 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 indefini!e or appreciable length of lime. 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 ~f space is available. Accounting cost center code District ARCO ALASKA INC. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK5261 County or Parish NORTH SLOPE AK Lease or Unit JWelJ no. / ADL: 25547 ALK: 2661 3GF15 Title COMPLETION Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 01/12/91 ( TD: 0 PB: 7876 SUPV:GB/SK I A.R.Co. W.I. Date 10/12/90 Complete record for each day reported NORDIC I I otal number of wells (active or reactive) on this. pst center prior to plugging and bandonment of this well 5J~ .2:52072 our IPrior status if a W.O. I 18:00 RIG RELEASED MW:10.2 NaCl/Br FINISH RUNNING COMP.,DRAIN STACK, LAND TBG, RILDS, SET PACKER DISCOVERED LEAK AT SOS, BALL NOT SEATED/TRASH UNDER BALL, BOLDS, PU AND SHEAR OEJ, RELAND TBG, RILDS, TEST SSSV (OK), ND BOPE, NU TREE, TEST PACKOFF AND FLANGE, ACTUATOR VALVE NOT WORKING, STEAM HEAT ACTUATOR, OPEN VALVE, PULL BPV, SET TREE TP, TEST TREE AT 250/5000 PSI, PULL TREE TP, DISPLACE ANNULUS AND TBG W/ 450' DIESEL, RELEASE RIG DAILY:S137,359 CUM:$1,108,507 ETD:S1,108,507 EFC:$1,230,000 Old TD Released rig INew TD PB Depth Date I Kind o rig IType completion (single. dual. etc.) Official reservoir name(s) Classifications (oil, gas. etc.) Producing method PotenlJal test data Well no. Date Reser'zoir Producing Interval Oil or gasTest time Production Oil on test Gas oe, ':~, Pump size, SPM X length Choke size T,P. C.P. Water % GOR Grav,ty Allowable Ettec: .e ~*'-~ corrected The above is correct /-. . For form prep .... i .... d distri~%~lOn,¢ ~ ?./ ~.~llJ.~~l IIIII I~~=~r____~.. see Procedures Manual, Section, Drilling. Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as Ihey are prepared for each ,,veil. Division o! AHant,cRt¢ h,,-,dCompany /5 V/C/N/rY M~4P i.~ ~ Mt. L ,4 T. £0 /0 fiN. I../ FW.&. 08. PAD ~$38' ~$9' 48.9 ~$.~ I~0°00"t0.~$'' ~$$'~ ~4~' 48,? ~4.0 /~0~00'40.~0" ~$~'~' ~0~ 48.4 I~O~OO'41.?l~' ~8'~ 19~' 48.~ ~d.O /~O=O0'~ff'4~O" ~8'~ /70' 4?,8 1~0~0'~3.~1~" ~038'/ I~0' 48.~ ~.0 LO~, ~.L. F.E,L. 0.~. /~0~00'~8,0/ / " ~$8'~ ~0' 47.~ ~3./ /00°00'48.~$~~ ~$8'-- 40' 4~.1 1~0~'80,~04' ~38'-- ~8' 48.8 ~$.0 /~'~0,~$8~ ~05~'~ /~0' 4~,8 ~.~ 1~~'~1,8?/" P838'~ 14~' 48,8 ~3.0 1~~85.150~ ~$~' 19~' ~,3 Ir 8,900, 880.80 400, PO~. po pO°Pc' 4P, OeO~ I0 ~,980, 880. ~ 490:R$9.04 ?OoPi'Mp. pob'' I0 $,980) 8~0.84 400, R34.00 ?O°PP' 4p. ORIGINAL A GYRODATA DIRECTIONAL SURVEY FOR ARCO ALASKA INCORPORATED KUPARUK RIVER UNIT, WELL NUHBER 3G-15 NORTH SLOPE BOROUGH, ALASKA. DATE : 06 DECEMBER 1990 GREAT LAND DIRECTIONAL DRILLING, Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ....... · KRU 3G-15 Section at: N,74.38,W Surveyor..: ROB SHOUP INC. for Gyrodata Services, Inc. 01/16/91 Computation...: RADIUS OF CURVATURE Survey Date...: 11/14/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G252 API Number .... : 50-103-20139 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 100 0.23 7 200 0.09 7 300 0.16 7 400 0.27 7 500 0.15 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD 100.0 10.0 -0.0 N 60.67 E 0.2 N' 0.1 E 200.0 110.0 ~.-'~ -0.2 N 60.48 E 0.3 N 0.3 E 300.0 210.0 -0'.4 N 68.43 E 0.4 N 0.5 E 400.0 310.0 -0.7 N 49.64 E 0.6 N. 0~9 E 500.0 410.0 -0.9 N 54.29 E 0.8 N 1.1 E CLOSURE DL DISTNCE BEARING /100 0.2 N 30.33 E 0.23 0.5 N 48.34 E 0.14 0.7 N 53.54 E 0.07 1.0 N 55.51 E 0.11. 1.4 N 54.59 E 0.12 7 600 0.17 600.0 510.0 -1.1 N 66.08 E 1.0 N 1.4 E 1.7 N 55.51 E 0.02 7 700 0.50 700.0 610.0 -1.1 N 38.36 W 1.4 N 1.5 E 2.1 N 46.23 E 0.33 7 800 0.89 800.0 710.0 0.1 N 67.51 W 2.2 N 0.6 E 2.2 N 14.27 E 0.39 7 900 1.06 900.0 810.0 1.7 N 60.81 W 2.9 N 1.0 W 3.1 N 18.60 W 0.17 7 1000 1.39 1000.0 910.0 3.8 N 65.07 W 3.9 N 2.9 W 4.8 N 36.60 W 0.33 7 1100 5.34 1099.8 1009.8 9.6 N 64.21 W 6.4 N 8.2 W 10.4 N 52.00 W 3.95 7 1200 8.75 1199.0 1109.0 21.7 N 68.05 W 11.4 N 19.4 W 22.5 N 59.65 W 3.41 7 1300 9.25 1297.8 1207.8 37.3 N 68.90 W 17.1 N 33.9 W 38.0 N 63.27 W 0.50 7 1400 11.26 1396.2 1306.2 55.0 N 70.79 W 23.2 N 50.7 W 55.7 N 65.37 W 2.01 7 1500 12.90 1493.9 1403.9 75.9 N 71.67 W 30.0 N 70.5 W 76.6 N 66.97 W 1.64 7 1600 14.90 1591.0 '1501.0 99.9 N 69.70 W 37.9 N 93.1 W 100.6 N 67.85 W 2.00 7 1700 20.32 1686.3 1596.3 130.0 N 67.44 W 49.0 N 121.3 W 130.8 N 68.02 W 5.43 7 1800 25.27 1778.4 1688.4 168.4 N 65.78 W 64.3 N 156.8 W 169.5 N 67.70 W 4.96 7 1900 31.33 1866.4 1776.4 215.2 N 65.85 W 83.7 N 200.1 W 216.9 N 67.29 W 6.06 7 2000 31.79 1951.7 1861.7 266.9 N 64.6~ W 105.7 N 247.6 W 269.2 N 66.89 W 0.56 7 2100 34.35 2035.5 1945.5 320.9 N 67.08 W 127.9 N 297.4 W 323.8 N 66.72 W 2.67 ^Survey Codes: 7/GYRO (KRU3G15G) KRU 3G-15 Page 2 01/16/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 2200 35.09 7 2300 36.95 7 2400 38.15 7 2500 43.57 7 2600 45.46 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DiSTNCE BEARING /100 2117.6 2027.6 377.4 N 67.34 W 150.0 N 349.9 W 380.7 N 66.79 W 0.74 2198.5 2108.5 435.9 N 70.07 W 171.4 N 404.7 W 439.5 N 67.05 W 2.11 2277.8 2187.8 496.6 N 69.69 W 192.3 N 461.9 W 500.4 N 67.39 W 1.21 2353.4 2263.4 561.8 N 69.94 W 214.9 N 523.3 W 565.7 N 67.67 W 5.42 2424.7 2334.7 631.8 N 71.77 W 237.9 N 589.5 W 635.7 N 68.02 W 2.11 7 2700 46.48 2494.2 2404.2 703.6 N 73.05 W 259.6 N 658.1 W 707.4 N 68.47 W 1.22 7 2800 49.17 2561.3 . 2471.3 777.7 N 72.77 W 281.4 N 728.9 W 781.3 N 68.89 W 2.69 7 2900 49.57 2626.5 2536.5 853.6 N 72.72 W 303.9 N 801.4 W 857.1 N 69.23 W 0.40 7 3000 49.49 2691.4 2601.4 929.6 N 71.54 W 327.2 N ~873.8 W 933.0 N 69.47 W 0.69 7 3100 49.15 2756.6 2666.6 1005.3 N 71.61 W 351.2 N 945.7 W 1008.8 N 69.63 W 0.34 7 3200 49.05 2822.0 2732~0 1080.8 N 70.94 W 375.5 N 1017.3 W 1084.4 N 69.74 W 0.40 7 3300 49.16 2887.5 2797.5 1156.4 N 73.62 W 398.5 N 1089.3 W 1159.9 N 69.91 W 1.54 7 3400 49.67 2952.6 2862.6 1232.3 N 73.74 W. 419.8 N 1162.2 W 1235.7 N 70.14 W 0.51 7 3500 49.10 3017.6 2927~6 1308.2 N 73.35 W 441.3 N 1235.0 W 1311.5 N 70.34 W 0.61 ? 3600 49.31 3083.0 2993.0 1383.9 N 75.83 W 461.4 N 1308.0 W 1387.0 N 70.57 W 1.44 3700 49.11 3148.3 3058.3 1459.6 N 74.34 W 480.9 N 1381.1 W 1462.5 N 70.80 W 0.87 3800 48.85 3213.9 3123.9 1535.0 N 75.83 W 500.3 N 1454.0 W 1537.7 N 71.01 W 0.88 3900 48.95 3279.7 3189.7 1610.4 N 76.55 W 518.3 N 1527.2 W 1612.8 N 71.25 W 0.42 4000 49.20 3345.2 3255.2 1685.9 N 76.08 W 536.2 N 1600.6 W 1688.0 N 71.48 W 0.37 4100 49.14 3410.6 3320.6 1761.5 N 77.03 W 553.8 N 1674.2 W 1763.4 N 71.70 W 0.55 4200 49.22 3475.9 3385.9 1837.1 N 76.30 W 571.3 N 1747.8 W 1838.8 N 71.90 W 0.43 4300 49.27 3541.2 3451.2 1912.8 N 76.24 W 589.2 N 1821.4 W 1914.4 N 72.07 W 0.06 4400 49.10 3606.6 3516.6 1988.4 N 76.15 W 607.3 N 1894.9 W 1989.9 N 72.23 W 0.18 4500 48.97 3672.1 3582.1 2063.9 N 76.49 W 625.2 N 1968.3 W 2065.2 N 72.38 W 0.23 4600 48.81 3737.9 3647.9 2139.2 N 76.40 W 642.8 N 2041.5 W 2140.3 N 72.52 W 0.17 4700 48.49 3804.0 3714.0 2214.2 N 76.99 W 660.1 N 2114.6 W 2215.2 N 72.66 W 0.46 'Survey Codes: 7/GYRO KRU 3G-15 Page 3 01/16/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 4800 48.54 7 4900 48.28 7 5000 48.01 7 5100 47.95 7 5200 47.69 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 3870.2 3780.2 2289.1 N 76.72 W 677.1 N 2187.5 W 2289.9 N 72.80 W 0.16 3936.6 3846.6 2363.8 N 77.09 W 694.1 N 2260.4 W 2364.5 N 72.93 W 0.33 4003.3 3913.3 2438.2 N 76.79 W 710.9 N 2332.9 W 2438.8 N 73.05 W 0.32 4070.2 3980.2 2512.4 N 77.05 W 727.7 N 2405.3 W 2513.0 N 73.17 W O.16 4137.4 4047.4 2586.4 N 77.24 W 744.2 N 2477.5 W 2586.9 N 73.28 W 0.28 7 5300 47.75 4204.7 4114.7 2660.3 N 77.62 W 760.3 N 2549.8 W 2660.7 N 73.40 W 0.22 7 5400 47.90 4271.8 4181.8 2734.3 N 76.41 W 777.'0 N 2622.0 W 2734.7 N 73.49 W 0'.68 7 5500 47.70 4339.0 4249.0 2808.4 N 75.95 W 794.7 N 2693.9 W 2808.7 N 73.56 W 0.32 7 5600 46.98 4406.7 4316.7 2881.9 N 75.94 W 812.5 N 2765.2 W 2882.1 N 73.63 W 0.72 7 5700 46.84 4475.1 4385.1 2954.9 N 76.38 W 830.'0 N 2836.2 W 2955.1 N 73.69 W 0'.27 7 5800 46.81 4543.5 4453.5 3027.8 N 75.82 W 847.5 N 2906.9 W 3028.0 N 73.75 W 0.30 7 5900 47.25 4611.6 4521.6 3100.9 N 76.46 W 865.0 N 2978.0 W 3101.1 N 73.80 W 0.56 7 6000 48.11 4679.0 4589.0 3174.8 N 75.93 W 882.7 N 3049.8 W 3175.0 N 73.86 W 0.91 7 6100 48.39 4745.6 4655.6 3249.4 N 76.73 W 900.3 N 3122.3 W 32'49.5 N 73.92 W 0.53 7 6200 48.75 4811.7 4721.7 3324.3 N 77.35 W 917.1 N 3195.3 W 3324.4 N 73.99 W 0.50 7 6300 49.29 4877.3 4787.3 3399.7 N 77.62 W 933.5 N 3269.0 W 3399.7 N 74.06 W 0.56 7 6400 48.22 4943.2 4853.2 3474.7 N 78.07 W 949.3 N 3342.5 W 3474.7 N 74.15 W 1.10 7 6500 48.19 5009.9 4919.9 3549.1 N 78.63 W 964.4 N 3415.6 W 3549.1 N 74.23 W 0.31 7 6600 48.45 5076.4 4986.4 3623.5 N 79.25 W 978.7 N 3488.9 W 3623.5 N 74.33 W 0.43 7 6700 46.31 5144.1 5054.1 3696.9 N 79.19 W 992.5 N 3561.1 W 3696.9 N 74.43 W 2.14 7 6800 45.05 5214.0 5124.0 3768.2 N 78.18 W 1006.5 N 3631.3 W 3768.2 N 74.51 W 1.36 7 6900 45.39 5284.4 5194.4 3839.0 N 78.51 W 1020.8 N 3700.8 W 3839.0 N 74.58 W 0.38 7 7000 45.77 5354.4 5264.4 3910.2 N 78.61 W 1035.0 N 3770.8 W 3910.3 N 74.65 W 0.38 7 7100 45.25 5424.5 5334.5 3981.4 N 77.56 W 1049.7 N 3840.6 W 3981.5 N 74.71 W 0.74 7 7200 45.33 5494.8 5404.8 4052.4 N 77.99 W 1064.8 N 3910.1 W 4052.5 N 74.77 W 0.23 7 7300 45.64 5564.9 5474.9 4123.5 N 78.04 W 1079.6 N 3979.8 W 4123.7 N 74.82 W 0.31 ^Survey codes: 7/GYRO KRU 3G-15 Page 4 01/16/91 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 7400 45.26 7 7500 45.21 7 7600 45.20 7 7700 44.47 7 7800 43.86 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION DISTNCE BEARING 5635.1 5545.1 4194.6 N 78.69 W 5705.5 5615.5 4265.4 N 78.86 W 5776.0 5686.0 4336.2 N 78.79 W 5846.9 5756.9 4406.5 N 79.00 W 5918.6 5828.6 4475.9 N 78.95 W RELATIVE-COORDINATES FROM-WELL-HEAD 1093.9 N 1107.8 N 1121.5 N 1135.1 N 1148.4 N 4049.6 W 4119.3 W 4188.9 W 4258.1 W 4326.5 W CLOSURE DISTNCE BEARING 11oo 4194.8 N 74.88 W 0.50 4265.6 N 74.95 W 0.lC 4336.4 N 75.01 W 0.04 4406.8 N 75.07 W 0.74 4476.3 N 75.13 W 0.61 7 7853 43.38 5957.0 5867.0 X 7991 43.'38 6057.3 5967.3 4512.4 N 78.63 W 1155.5 N 4362.3 W 4606.9 N 78.63 W 1174.2 N 4455.3 W 4512.8 N 75.16 W 0.95 4607.4 N 75.23 W 0.00 ^Survey Codes: 7/GYRO X/EXTRAPOLATED KRU 3G-15 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/16/91 SUBSEA ~EAS INCLN DEPTH DEPTH ANGLE TVD BKB 0 90 0.21 90 100 190 0.10 190 200 290 0.15 290 300 390 0.26 390 400 490 0.16 490 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 N 60.67 E 0.13 N 0.08 E 0 0 N 60.50 E 0.29 N 0.33 E 0 0 N 67.64 E 0.39 N 0.51 E 0 0 N 51.52 E 0.56 N 0.82 E 0 0 N 53.83 E 0.80 N 1.12 E 500 590 0.17 590 600 690 0.47 690 700 790 0.85 790 800 890 1.04 890 900 990 1.36 990 0 0 N 64.90 E 0.94 N 1.36 E 0 0 N' 27.92 W 1.37 N 1.53 E 0 0 N 64.60 W 2.10 N 0.69 E 0 0 N 61.48 W 2.82 N 0.82 W 0 0 N' 64.65 W 3.78 N 2.67 W 1000 1090 4.95 1090 1100 1191 8.44 1190 1200 1292 9.21 1290 1300 1394 11.13 1390 1400 1496 12.83 1490 0 0 N 64.29 W 6.02 N 7.39 W 1 1 N 67.70 W 10.84 N 18.14 W 2 1 N 68.83 W 16.64 N 32.77 W 4 2 N 70.67 W 22.83 N 49.51 W 6 2 N 71.63 W 29.68 N 69.62 W 1500 1599 14.88 1590 1600 1704 20.52 1690 1700 1813 26.05 1790 1800 1928 31.46 1890 1900 2045 32.95 1990 9 3 N 69.72 W 37.82 N 92.89 W 14 5 N 67.37 W 49.49 N 122.57 W 23 9 N 65.79 W 66.61 N 161.90 W 38 15 N 65.52 W 89.66 N 213.16 W 55 18 N 65.76 W 115.84 N 269.67 W 2000 2166 34.84 2090 2100 2289 36.75 219'0 2200 2416 39.00 2290 2300 2551 44.53 2390 2400 2694 46.42 2490 76 21 N 67.25 W 142.55 N 332.07 W 99 23 N 69.78 W 169.17 N 398.69 W 126 26 N 69.73 W 195.70 N 471.04 W 161 35 N 70.87 W 226.77 N 556.64 W 204 43 N 72.97 W 258.32 N 653.82 W 2500 2844 49.35 2590 254 50 N 72.75 W 291.25 N 760.65 W KRU 3G-15 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 01/16/91 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 2600 2998 49.49 2700 3151 49.10 2800 3304 49.18 2900 3458 49.34 3000 3611 49.29 TVD BKB 2690 2790 2890 2990 3090 3100 3764 48.94 3190 3200 3916 48.99 3290 3300 4069 49.16 3390 3400 4222 49.23 3490 3500 4375 49.14 3590 3600 4527 48.93 3690 3700 4679 48.56 3790 3800 4830 48.46 3890 3900 4980 48.06 3990 4000 5129 47.87 4090 4100 5278 47.74 4190 4200 5427 47.85 4290 4300 5575 47.16 4390 4400 5722 46.83 4490 4500 5868 47.11 4590 4600 6017 48.16 4690 4700 6167 48.63 4790 4800 6319 49.08 4890 4900 6470 48.20 4990 5000 6620 48.01 5090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 308 54 N 71.56 W 326.74 N 872.24 W 361 53 N 71.27 W 363'.52 N 982.35 W 414 53 N 73.62 W 399.30 N 1092.08 W 468 54 N 73.52 W 432..19 N 1204.26 W 521 53 N 75.67 W 463.45 N 1315.86 W 574 53 N 75.29 W 493.50 N 1427.44 W 626 52 N 76.48 W 521'.10 N 1538.73 W 679 53 N 76.73 W 548.40 N 1651.03 W 732 53 N 76.29 W 575.12 N 1763.68 W 785 53 N 76.17 W 602..71 N 1876.31 W 837 53 N 76.47 W 629.95 N 1988.22 W 889 52 N 76.87 W 656.52 N 2099.20 W 940 51 N 76.83 W 682.25 N 2209.32 W 990 50 N 76.85 W 707.53 N 2318.53 W 1039 49 N 77.11 W 732.61 N 2426.62 W 1088 49 N 77.54 W 756.83 N 2534.00 W 1137 49 N 76.29 W 781.70 N 2641.52 W 1185 48 N 75.94 W 808.14 N 2747.79 W 1232 46 N 76.26 W 833.75 N 2851.64 W 1278 46 N 76.26 W 859.52 N 2955.29 W 1327 48 N 76.06 W 885.65 N 3061.73 W 1377 51 N 77.15 W 911.66 N 3171.23 W 1429 52 N 77.71 W 936.62 N 3283.41 W 1480 51 N 78.46 W 959.95 N 3393.78 W 1530 50 N 79.24 W 981.54 N 3503.85 W 5100 6766 45.48 5190 1576 46 N 78.52 W 1001.61 N 3607.63 W KRU 3G-15 Page DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 7 01/16/91 SUBSEA MEAS INCLN TVD MD-TVD DEPTH DEPTH ANGLE BKB DIFF 5200 6908 45.42 5290 1618 5300 7051 45.51 5390 1661 5400 7193 45.32 5490 1703 5500 7336 45.50 5590 1746 5600 7478 45.22 5690 1788 5700 7620 45.05 5790 1830 5800 7760 44.10 5890 '1870 5900 ~7898 43.38 5990 1908 VERT DIRECTION CRRT BEARING RELATIVE COORDINATES FROM WELL HEAD 42 N 78.52 W 1021.96,N 3706.40 W 43 N 78.08 W 1042.35 N 3806.49 W 42 N 77.96 W 1063.76 N 3905.32 W 43 N 78.27 W 1084.83 N 4004.87 W 42 N 78.82 W 1104.75 N 4103.96 W 42 N 78.83 W 40 N 78.97 W 38 N '78.63 W 1124.26 N 1143.14 N 1161.69 N 4202.73 W 4299.37 W 4392.93 W KRU 3G-15 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 01/16/91 MEAS I~CLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH AMGLE BKB SUB-S DIST BEARING CLOSURE FROM-WELLHEAD DIST BEARING 1000 1.39 1000 910 4 N 65.07 W 4 N 2000 31.79 1952 1862 267 N 64.67 W 106 N 3000 49.49 2691 2601 930 N 71.54 W 327 N 4000 49.20 3345 3255 1686 N 76.08 W 536 N 5000 48.01 4003 3913 2438 N 76.79 W 711 N DL/ 100 3 W 5 N 36.60 W 0.3 248 W 269 N 66.89 W 0.6 874 W 933 N 69.47 W 0.7 1601 W 1688 N 71.48 W 0.4 2333 W 2439 N 73.05 W 0.3 6000 48.11 4679 4589 3175 N 75.93 W 883 N 7000 45.77 5354 5264 3910 N 78.61 W 1035 N 3050 W 3175 N 73.86 W 0.9 3771 W 3910 N 74.65 W 0.4 01/16/91 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-15 Section at: N,74.38,W Surveyor..: ROB SHOUP Computation...: RADIUS OF CURVATURE Survey Date...: 11/14/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G252 API Number .... : 50-103-20139 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 45 WEL S23 T12N R8E. MARKER IDENTIFICATION KB RKB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C MEAS INCLN -VERT-DEPTHS SECT DEPTH ANGLE BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 0.00 0 -90 35 0.08 35 -55 3475 49.24 3001 2911 7688 44.56 5838 5748 7695 44.51 5843 5753 0 N 0.00 E ON 0 E -0 N 60.67 E 0 N 0 E 1289 N 73.45 W 436 N 1217 W 4398 N 78.97 W 1133 N 4250 W 4403 N 78.99 W 1134 N 4255 W TOP KUPARUK A BASE KUPARUK A 7~ CASING PROJECTED TD 7695 44.51 7807 43.80 7964 43.38 7991 43.38 5843 5753 4403 N 78.99 W 5924 5834 4481 N 78.91 W 6038 5948 4588 N 78.63 W 6057 5967 4607 N 78.63 W 1134 N 4255 W 1149 N 4331W 1171 N 4437 W 1174 N 4455 W Great Land Dlre£ tional Drilling. _THC. <KB>O VERTICAL SECTION VIEW 450 gOO t3§O INCLN 0.00 t800 43.38 ;~850 2700 3i50 3600 4050 4500 495O 5400 5850 63OO 6750 7200 7650 BiO0 45O ARCO ALASKA. [NC. KRU 36-!5 SecE[on at: N 74.38 ~ ..... TVD Sca]e.' ~ inch = gOO feet Dep Scale.' ! inch -- §00 feet _ Dpawn .... · 0t/~6/9! 14arker I~lentifica~ion MO ,~/O SECTN ~) KB 0 0 0 B} PROJECTED TD 799i 60§7 4607 ................. [ .... x~ .................. i ..... I ..... -- -'* I, 0 450 900 t350 1800 2250 2700 3t50 3600 4050 4500 Section Departure Sreat Land Directional Drilling. Znc. PLAN VIEW ARCO ALASKA. INC. KRU 3G-~5 CLOSURE ..... : 4607 ft N 75.23 DECLINATION.: 0.00 E SCALE ....... : ! inch = 900 feet DRAWN ....... : 0~/~6/9! 3t50 2700 2250 ~.SO0 1350 900 45O 45O 9OO ~350 2250 27OO 3t.50 4950 4500 4050 3600 3t50 2700 2250 t800 t350 900 450 0 450 <- NEST: EAST -> PEFiNiiT # ~ AUb~_~ L~_ULUbiCAL MATED. iALS iNVENTORY LiST - _../-~ / WELL NAME /~ ~ ~.~- -- / O" COMPLETION DATE CO, CONTACT j ~?~i.~k off or list dat.,a a,,s it is re. cei¥~d.'list received date for 407. if not re[juired list as NR , ,~,', ', .... .,,/.~/~,/1 u,...~,~ .~,o~-..;' ~.,,-."wJ ,7 J ~"~ "'~.~ dry ditch intervals core descriptio~ dio~ital data i' - , ¢~ 'rvn~' .... J RUN iII.Ik!TlCnt;A lc', ~,~Lo SCALE ...... NO. i (t~ the E , ] ARCO Alaska, Inc. Date: March 8, 1991 Transmittal #: 8030 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1 119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmiltal. 3G-24 1A-17 3G-23 3G-02 3G-15 Receipt Drilling Acoustic Cement Bond Log Acoustic Cement Bond Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log 1 1-14-90 6603-9725 12-31-90 5400-8438 1 1-15-90 4200-7282 1 1-12-90 4100-6545 Alaska Oil & Ga~." ' ~""t;°mm'ss'~" State of Alaska Ancb0[ag.~. ARCO Alaska, inc. Date: February 4, 1991 Transmittal #: 8000 RETURN TO: ARCO Alaska, inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. signed copy of this transmittal. 3G-o4x'. 3G-15~.~ 3 G- 22,:)(//',/ 3G-21/'~w~, 3G-04~;~, 3G-22¥,~ 1L-22"~ Receipt Drilling Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log Acoustic Cement Bond Log Squeeze Record Acknowledge: Please acknowledge receipt and return one 10-3-90 5229-9682 1 1-15-90 6698-9704 1 1-16-90 4900-7939 I 1-14-90 4500-7815 1 1-18-90 6600-9595 I 1-23-90 8466-11;513 1 1-1 6-90 4892-7962 I 1-1 8-90 6600-9616 1 -20-91 9200-9800 ~~~ ...... Date' State of Alaska CEIV'ED FE~ 5 1991 A/aska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALA,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 _.X_ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing_ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, In¢. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 45 FEL,SEC 23,T12N,R8E, UM At top of productive interval 1385' Fnl, 1110' FWL, Sec. 23, T12N, RSE, UM At effective depth NA At total depth 1324"FNL, 893' FWL, Sec. 23, T12, R8E, UM (approx! (approx) 12. Present well condition summary Total Depth: measured 7990' feet (approx) true vertical 6084' feet Effective depth: measured NA feet (approx) true vertical NA feet Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) RKB 90' 7, Unit or Property name Kuparuk River Unit feet 8. Well Number 3G-15 9. Permit number 90-1~1 10. APl number 50-103-20139 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Casing Length Size Structural Conductor 8 0' 1 6" Surface 3440' 9 5/8" Intermediate Production 7929' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 217 SX AS I 765 Sx AS III & 460Sx Class G 175Sx class G Measured depth True vertical depth 1 1 5' 115'approx. 3475' 3002'(approx) 7964' 6044' (approx) REEEIVED DEC - 4 Alaska 0il & Gas Cons. C0rnm[$~'t0t~ Anchorage 13. Attachments Description summary of proposal Detailed operation program ..X___ BOP sketch 14. Estimated date for commencing operation January, 1991 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:I Oil ~( Gas _ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed //~,~, ~,/"/~ Title Area Drilling Engineer - / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require IApproval No. Approved by the order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 Approvea Copy R~tur~ed SUBMIT IN TRIPLICATE ORIGINAL SIGNED BY LONNIE C. SMITH ARC._ Jil ,--..,, Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "Initial Reperf' on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to slDudd_~rtg should be summarized on the form giving inclusive dates only. District ICounty. parish or borough IState ARCO ALASKA INC. I NORTH sLoPE , AK ]we, no. Field ILease or Unit KUPARUK RIVER UNIT I ADL 25547 ALK 2661 13G-15 Auth. or W.O. no. ITM AK5261 I DRILLING Operator IARCO W.I. ARCO I 55.2521 SpuddedsPuDOr W.O. begun IDate 10/12/90 ]Hour 18:00 IPrior status if a W.O. Date and depth as of 8:00 a.m. 10/13/90 (1) TD: 1609'(1609) SUPV:PW 10/14/90 (2) TD: 3500'(1891) SUPV:PW 10/15/90 (3) TD: 4270'( 770) SUPV:PW 10/16/90 (4) TD: 7157'(2887) SUPV:PW 10/17/90 (5) TD: 7990'( 833) SUPV:PW 6) Complete record for each day reported DOYON 14 DRLG MW: 9.0 VIS: 70 MOVE RIG FROM 3G-24 TO 3G-15. ACCEPT RIG @ 1500 HR 12-OCT-90. INSTALL 20" DIVERTER STACK, RISER AND FLOWLINE. PU BHA AND ORIENT MWD. OPERATE AND TEST DIVERTER SYSTEM. DRILL TO PRESENT DEPTH. DAILY:S65,947 CUM:$65,947 ETD:S65,947 EFC:$1,230,000 POH FOR CSG MW: 9.6 VIS: 56 DRILLING 1609 TO 3500. CBU. TOH. TIH. HOLE TIGHT 1600 TO 1800. CBU POH FOR 9-5/8 CSG. DAILY:S54,195 CUM:$120,142 ETD:S120,142 EFC:$1,230,000 DRLG MW: 9.5 VIS: 38 LD 12-1/4" BHA. RAN 80 JTS 9-5/8" 36 PPF J-55 BTC CSG. LAND WITH SHOE @ 3474 COLLAR @ 3395'. CIRC ONE CSG VOL. MIX AND PUMP 80 BBL PREFLUSH, 264 BBL LEAD (12.2 PPG) AND 98 BBL TAIL (15.8 PPG). GOOD CIRC THROUGHOUT JOB. 110 BBL CMT TO SURF. RD DOWELL AND FLUSH DIVERTER. ND DIVERTER. INSTALL CSG HEAD FLANGE. NU BOPE. TEST CHOKE MANIFOLD, BOP AND SURF EQ TO 3000 PSI. INSTALL WEAR RING. MU BHA AND ORIENT MWD. LOAD AND CALIBRATE RLL TOOL. RIH. DRILL FC AND CMT TO 20' ABOVE SHOE. TEST CSG TO 2000 PSI. CHANGE OVER .M~D.~i~SYSTEM. DRILL 10' OF NEW FORMATION. RAN EMW TEST @ :>:~7~.~i~!'I'VD TO 12.3 PPG TEST OK. DRILL TO PD. "!~!~:$62,218~-- CUM:$182,360 ETD:S182,360 EFC:$1,230,000 ~?~i~-~~-".-. ~:i ~: 9.6 vis: 37 DRAG Y/4270'-7157', 14.5 ADT, 1.1 AST DAILY:S57,631 CUM:$239,991 ETD:S239,991 EFC:$1,230,000 TIH MW:10.2 VIS: 40 DRLD F/7157-7435'. PERFORM FORMATION INTEGRITY TEST TO 11.1 PPG - NO LEAKOFF. DRLD TO 7990' TD. CBU. POH, REMOVE SOURCES AND DOWNLOAD RLL LOGGING TOOL. LD TURBINE. MU BHA FOR CLEAN OUT RUN. LOG QUALITY IS SATISFACTORY. RIH TO CLEAN OUT FOR 7" CSG. DAILY:S66,698 CUM:$306,689 ETD:S306,689 EFC:$1,230,000 The above is corre(;t Signature TEST PACKOFF MW:10.6 NaCl CONT RIH, SLIP & CUT DRILL LINE, CONT RIH, CIRC HOLE CLEAN, DROP SS SURVEY, POOH LAYING DOWN 5" DP, PULL WEAR BUSHING, RU & RUN 185 + i MRKR JT OF 7" 26#, J-55 BTC & AB MOD TO 7965', RU DOWELL CMT HD & CIRC @ 600 PSI & 6 BPM, PUMP 175 SX OF CLASS G, DISPLACED W/ 303 BBL OF BRINE, BUMP PLUB W/3000 PSI, CHECK FLOAT EQUIP, CIP @ 02:30 HRS, RD CMT HD, RAISE BOP, SET 7" SLIPS W/ 175K SOW BLOW BRINE OUT OF ANN, BUT & LD 7" STUB, INSTALL TORQUE PACKOFF, MU & TEST TBG HEAD TO 3000 PSI. DAILY:S307,079 For form preparation and distribution, /'~ see Procedures Manual, Section 10. / Drilling, Pages SS and 87./~~ IDate [ Title CUM: $613,768 ETD: $613,768 EFC: $1,230,000 INumber all dally well history forms consecullvely as they are prepared for each well. iPage no. AR3B-459-1-D AR~. (. and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Filial i:le~ort" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be subrllitted al~ ~'her~Operatlons are suspended for an indefinile or appreciable length of time. On workovers when an official test is not required upon completion, report coml~_.~a~ld 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 I Slate ARCO ALASKA INC. I AK County or Parish NORTH SLOPE Field Itease or Unit Well no. KUPARUK RIVER UNIT JTitle ADL 25547 ALK 2661 3G-15 I DRILLING Auth. or W.O. no. AK5261 Operator A.R.Co. W.I. ARCO Date 55. 2521 Spudded or W.O. begun S?UD 10/12/90 Complete record for each day reported Date and depth as of 8:00 a.m. 10/19/90 ( TD: 7990 PB: 0 SUPV:JMM Old TD Released rig 7) Classifications (oil, gas, etc.) DOYON 14 RELEASE RIG I otal number of wells (active or inactive) on this est center prior to plugging and bandonment of this well our I Prior status if a W.O. 18:00 DAILY:SO MW:10.6 NaC1 CUM:$613,768 ETD:$613,768 EFC:$1,230,000 RECEI¥ D Alas/(a Oil & Gas Cor~s. Commission Anchorage JNew TO ] PO Depth Date Kind of rig Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data lWell no. Date Reservoir Producing Interval Oil or gasTesl 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 Si gnat ur e~...~=~ ~ I Dat/;/~__/~ I T~ ~"~ ~ ~,. . _ For form preparation a~lJistribution, ~ / / ~ see Procedures Manual,',~ection 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively Page as they are prepared for each well. I ~ no. I Dl¥1~on of AllanllcRIchfleldCompany ARCO Alaska, Inc. Date: October 26, 1990 Transmittal #: 7933 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. one signed copy of this transmittal. 3G-15 3G-24 LIS Tape and Listing LIS Tape and Listing Please acknowledge receipt and return ~o-~-~o ~oo-~ ~o-~-~o ~oo-~o ~ Receipt Acknowledged: Date: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: October 26, 1990 Transmittal #: 7932 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 Open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-15 3G-24 3 G - 15 Dual Gamma Ray Compensated 1 0 - 1 6 - 9 0 3 5 0 0 - 7 9 91 Neutron Porosity Simultaneous Formation Density Dual Gamma Ray Electrmagnetic 1 0- 1 6- 9 0 Wave Resistivity Formation Exposure Time Dual Gamma Ray Compensated 1 0 - 1 1 - 9 0 Neutron Porosity Simultaneous Formation Density 3G-24 Dual Gamma Ray Electrmagnetic 1 0-1 1 -90 4600-9940 Wave Resistivity Formation Exposure Time Receipt Acknowledged' ~-- Date' 3500-7991 4600-9940 DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) RECEIVED OCT 1 1990 Alas'~a Oil & Gas Cons. Commission Anchorage October 10, 1990 Telecopy: (907)276-7542 A. Wa>~e ~.-~cB~ Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-15 Revisad ARCO Alaska, Inc. Permit No. 90-137 Sur. Loc 2538'F~, 45'~EL Sec 23 T12N RSE ~ Btmhole Loc. 1324'FN7~, 893'~, Sec. 23, T!2N, RSE, UM. Dear Mr. McBride: Enclosed is the approved revised application for permit to drill the above referenced well. ~,"fhe provisions of the cover letter, dated August 24, ]990, accompanying the original approved permit are in effect for this revision. Sincerely, ,/ ...... ?', -/~,c , _ / :. .- . ,/ :~ -- , Commissioner Alaska Oil and Gas Conservation Commission BY OPDER OF THE COI*~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 8, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99510-3192 Attn: Mr. Lonnie C. Smith Re: Kuparuk River Unit Well 3G-15 ARCO Alaska, Inc. Revised Permit to Drill Dear Mr. Smith: ARCO Alaska, Inc requests to revise the BHL for Kuparuk River Unit Well 3G- 15. Enclosed is a revised Permit to Drill Form 10-401. Original 3G-15 Permit //90-121 Appr Date 8/24/90 BHL: 1561' FNL, 1617' FEL, Sec. 23, T12N, R8E, UM Revised 3G-15 BHL: 1324' FNL, 893' FWL, Sec. 23, T12N, R8E, UM Drilling to date on 3G pad has been successful and more wells are expected to be drilled on the western edge of the field than previously anticipated. This has caused the need to revise the BHL for the previously submitted permit to drill Well 3G-15. A BHL to the west is proposed to be drilled from the conductor for Well 3G-15. The previously submitted BHL for 3G-15 will be drilled from a different conductor, 3G-2, on the eastern side of the pad. The permit for 3G-2 has previously been submitted to you. Thank you for your consideration in this matter. If you have any questions, please call me at 265-6575. Sincerely, Sr. Drilling Engineer cc: A.W. McBride gECEIVED STATE OF ALASKA ALAS~ OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.O05 ! la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratory~ Slratigraphic Tesl _ 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, Inc. RKB 90', Pa, d 5,3' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 45' FEL, Sec. 23, T12N, R8E, UM Kuoaruk River Vrli! At top of productive interval (TARGET) 8. Well number Number 1385' FNL, 1110' FWL, Sec. 23, T12N, R8E, UM 3G-15 Revised #U630610 At total depth 9. Approximate spud date Amounl 1324' FNL, 893' FWL, Sec 23, T12N, R8E, UM 29-OCT-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 3G-16 7948' MD 893'@ TD feet 24' at 420 feet 2560 66056 TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 11 00' feet Maximum hole angle 48° Maximum surface 1860psig At total depth (TVD) 6056 @ 3370 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stage dataI '24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' :f_200 Cu. Ft. 12.25 9.625" 36.0# J-55 BTC 3586 35' 35' ~8'6.~F¥_3140' 1480 Cu. Ft. AS III & HF-ERW---- -- ,L:~~-, 590 Cu. Ft. Class G 8.5 7" 26.0#1J-55 AB-MO[ 3786' 35' 35' 3821' 3275' 180Cu. Ft. ClassG 8.5 7" 26.0#1J-55 BTC 41 27' 3821' 3275 7948' 6056' Top 500' above Kuparuk 19. To be completed for Reddll, 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 deplh Structural Conductor Cu. Ft. Surface Ca. Ft. Intermediate Production Liner ' ':~i~i'~ ~-~ ¢:) Perforation depth: measured true vertical ~'7,;~/Oil.& Gas C0 s. Com .issi!.' 20. Attachments Filing fee ~ Property plat __ BOP Sketch X Diverfer Sketch ~ Drilling program ~ 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 Signed ~-'~./~~ Title Area Dr illin, En~ineer Date Commission Use Onl~' Permit Number I APl number I Approvab~a~2~/C~0 J See cover letter for Co ..~d"~ '-/,~_,,/ I 50- ~/~::~,~-.- ~..~/~ '~ other recluirements nditions of approval Samples required __Y e s ~'N o Mud log required __ Ye s N o Hydrogen sulfide measures Yes ,~ N o Directional survey required]_ ~l~' .~_~.~j ~_ N o Required working pressure for BOPE~ __ 2M; ..~ 3 M; __ 5 M' __ 1 0 M' __ 1 5 M _. ;" ,-~.' by order of /d- /'~),- Approved b~/ (, Commissioner the commission Date Form 10-401 Rev. 7-2;~F'89 Submit in triplicate HORIZONTAL PROJECTION SCALE 1 !N. = 1000 FEET TD LOCATION, 1324' FNL. 893' FYL SEC. 23. T I2N. R8E Z TARGET LOCATION, 1385' FNL. 1110' FYL SEC. 23. TI2N. RSE 3000 20OO 1000 1000 ARCO ALASKA. lnG. Pad 50. Nell No, 15 Revlsod Propossl Kuperuk Field. North SI ope. AIssJ~s I/EST-EAST 5000 4000 5000 2000 I I TARGET TVD-5850 THD-?642 DEP-4283 NORTH 1153 YEST 4125 1000 I 1000 I ~CE SURFACE LOCATION, 2538' FNL. 45' FEL SEC. 23. TI2N. R8E N 74 DEG 23 MIN W 4283' (TO TARGET) 200 150 100 50 _ 0 5O 100 300 250 200 150 I I I I lO0 100 50 0 50 100 I I I ~ I,, 1 700 900 ',,7oo 1500 1300 ;300 250 200 150 100 50 0 50 100 200 _ 150 _ lO0 _ 5O _0 _ 5O _ 100 ARCO ALASKA, 1. no, Pad 3G, Well No: lb Revisecl Kuparuk Field, North Slops, Proposal Alaska 0 . RKB ELEYATION, 90' 1 000 _ 2000. 3000 _ 4000 5000 6000 _ 7000 KOP TVD=1100 TMD=IlO0 DEP=O 3 BUILD 3 DEG g PER 100 FT 15 B/ PERMAFROST 21 T/ UG~NU SNDS TVD=1605 TMD=1611 DEP=68 TVD--177'0 TMD=1785 DEP-121 T/ W SAK SNDS TVD=2455 TMD=2606 DEP=564 EOC TVD=2511 TMD=2688 DEP=623 B/ AVERAGE ANGLE 47 DEG 38 MI N W SAK SNDS TVD=2940 TMD=3324 DEP=lO93 9 5/8' CSG PT TVD=3140 TMD=3621 DEP=1312 K-lO TVD=3320 TMD=3888 DEP=1510 K-5 TVD=4690 TMD=5921 DEP=3011 TAROET - T/ ZONES C - A TVD=5850 TMD=7642 DEP=4283 B/ KUP SNDS TVD=5921 TMD=7748 DEP=4361 TD / LOG PT TVD=6056 TMD=7948 DEP=4509 I I ! 0 1000 2000 3000 VERTICAL SECTION I 4000 I 5OOO Si 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3G PAD Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs. Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. Reperforate and add additional perfs. DRILLING FLUID PROGRAM (3G-lS) Spud to 9-5/8" Drill out to surface casino weioht UD _ -- Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 1 5-4 0 4 - 8 APl Filtrate 1 0-1 2 8-1 0 pH 9-10 8.5-9 % Solids 10 +/- 4- 7 Weight up 10.7 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 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 N0te~;: - 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/ff. This shows that formation breakdown would occur before a surface pressure of 1830 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-15 will be 3G-16. As designed, the minimum distance between the two wells would be 24' at 420' (MD). 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. . .JPARUK RIVER UN,. 20" DIVERTER SCHEMATIC 5 I 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6, 2.0' - ZOO0 PSI ANNULAR PREVENTER SRE 2/6/ I I ,13 5/8" 5000 tBOP STACK 7 ACCUMULATOR CAPACITy TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 30(X) PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEl_ 2. CHECK THATALL HOLD-DOWN SCREWSARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD, 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3(X)0 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3(XX) PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3(X)0 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI, 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INRDRMAT1ON ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILUNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2(XX) PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5~8' - 5(X)O PSI SPACER SPOOL 4. 13-5/8" o 5(X)O PSI PIPE RAMS 5. 13-5/8' - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES 6. 13-5/8' -5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 August 24, 1990 Telecopy: (907)276-7542 A. Wayne. McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-15 ARCO Alaska, Inc. Permit No. 90-121 Sur. Loc~ 2538'F~, 45'FEL, Sec. 23, T12N, R8E, IR~4.. Btmhole Loc. 1561'FNL, !617'FEL, Sec. 23, T12N, RSE, UM. Dear Mr. McBride 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 authoriz~ conducting drilling operations until all other required p~rmitting determinations are made. Tha Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, ~ ._~ Co~issioner Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COI~4~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMIVIISSION PERMIT TO DRILL 2O AAC 25.OO5 I la. Type of Work Drill X Redrill -- I lb. Type of Well Exploratorym Stratigraphic Test _ Development Oil .~X 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, Inc. RKB 90', Pad 53' GL feet Kuparuk River Field 3. Address 6. Properly Designation Kuparuk River Oil Pool P. O. Box 100360, Anchoracge, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or properly Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 45' FEL, Sec. 23, T12N, R8E, UM Kuparuk River Unit At top of productive interval (TARGET) 8. Well number Number 1640' FNL, 1490' FEL, Sec. 23, T12N, RSE, UM 3G-15 #U630610 At total depth 9. Approximate spud date Amounl 1561' FNL, 1617' FEL, Sec 23, T12N, RSE, UM 27-AUG-90 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) properly line 3G-16 6532' MD 3663'@ TD feet 23' at 240' feet 2560 6083' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 21 81 ' feet Maximum hole angle 28° Maximum surface 1830 psig At total depth (TVD) 3250 psig 18. Casing program Setting Depth size Specification Top Botlom Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD IVD TVD (include stac~e data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3094' 35' 35' 3129 3090' 1350 Cu. Ft. AS III & HF-ERW 475 Cu. Ft. Class G 8.5 7" 26.0# J-55 AB-MOF 3305' 35' 35' 3340' 3275' 185Cu. Ft. ClassG 8.5 7" 26.0# J-55 BTC 3192' 3340' 3275' 6532' 6083' 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 verticaltrue vertical feet Casing Length Size Cemented Measured dc4~th~ ~ l., i %Tr~l,..V~ioal depth StructuralKb L ~[~ ~ V ~m m,~ conductor cu. Ft. Sudace Cu. Ft. Intermediate io. AUG 2 1990 Liner ~. asJ~a Oil & Gas Cons. Perforation depth: measured true vertical '~'~.i,~ ch0ra 20. Attachments Filing fee ~ Property plat __ BOP Sketch X Diverter Sketch X Drilling program ~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed repod _20 AAC 25.050 requirements X~ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed //~/[/~ ~'~ Title Area Drillin, Engineer Date - ' / Commission Use Only Approval date ee cover letter for Permit Number I APl number I o8 / 24/19c . - ] I 50- ,/,~__~..~- ~.o//3. ~' , . ~ other rec~uiremems ConUitions of approval Samples required __Y e s .~.N o Mud Icg required __ Y e s~. N o Hydrogen sulfide measures Yes ~ N o Directional survey required ,,~'~Yes N o Required working pressure for BOPE 2M; ¢"",~' 3 M; 5 M · 1 0 M · 1 5 M Other: '~ C,/' by order of ~ -~. Approved by . Commissioner the commission Date Form 10-401 Rev. Submit in triplicate DRILLING FLUID PROGRAM (3G-15) Spud to 9-5/8" Drill out to Weight up surface casing weight up to TD Density 8.6-10.0 8.6-9.3 11.0 PV 1 5-35 5- 1 5 1 0-1 8 YP 15-35 5-8 8-12 Viscosity 50-100' 30-40 35-50 Initial Gel 5-15 2-4 2-4 10 Minute Gel 15-40 4-8 4-8 APl Filtrate 1 0-12 8-1 0 4-5 pH 9-1 0 8.5-9 9.0-9.5 % Solids 10 +/- 4-7 10-12 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 Notes: RECEIVED AUG 2 ) 1990 _/gas~ Oil & Gas Cons. - 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 1830 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 3G-15 will be 3G-16. As designed, the minimum distance between the two wells would be 23' at a depth of 240'. 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. ARCO ALASKA, Inc. Pad 30, Wel I No~ 15 Propoeed Kuperuk Field, North Slope, Alaeka 0 _ RKB ELEYATION~ 90' 1000_ 2000 _ 3000_ 4000_ 5000 _ 6000_ 7000 B/ PERMAFROST TVD'=160.5 T/ UONU SNDS TVD=1780 KOP TVD=2181 TMD=2181 DEP=O 3 T/ W SAK SNDS TVD=2420 TMD=2421 DEP=15 9 BUILD 3 DEO PER lO0 Fl' I$ B/ W SAK SNDS TVD=2890 TMD=2907 DEP=136 27 EOC / 9 5/8" CSO PT TVD=3090 THD-3129 DEP=2;30 K-lO TVD=~)320 TMD-3390 DEP=355 AVERAGE ANGLE 28 DE[; 26 MI N K-5 TVD,,4720 TMD---4982 DEP=ll13 TAROET / TOP ZONE C-A TVD"5807 TMD=6218 DEP-1701 B/ KUP SNDS TVD-'Sg07 TMD'"6332 DEP=1755 TD / LOG PT TVD=6083 TMD=6532 DEP=1851 I I 1 000 2000 VERTICAL SECTION 150 100 5O 5O 100 150 200 150 100 50 I ....... I ........ ! ..... "-g.~O0 SO0 ?00 900 1100 / / / / / 3900 0 50 ""~!::~' 500/* 500 '1,500 500 /'" 3500 ~ 700 / ! / / 3700 700 900- '" 100 150 .! ...... ! ~'00 lO0 ;00 200 I I I _ 150 ' 100 _ SO 0 5O lO0 150 200 1 50 1 O0 50 0 50 1 O0 1 50 200 HOF~ ZONTAL SCALE 1 IN. PROJECTION = 1000 FEET ARCO ALASKA, I ne. Pmd 3g, Well No8 15 Kupeeuk Field, North Propoeed Slope, Alaekm :~000 20O0 1000 1000 3000 2000 I WEST-EAST 1000 I TARGET TVDm$80T THD=6218 DEP-I?OI NORTH 898 VEST 1445 SURFACE 1000 I TARGET LOCATION, 1540' FNL, 1490' FEL SEC. 23. TI2N. RGE SURFACE LOCATION, 2538' FNL. 45' FEL SEC. 23, TI2N. RGE TD LOCATIONt 1,561' FNL, 1617' FEL SEC. 23. TI2N. RSE RECEIVED AUG ~ ~ 1BBO Riaska Oil .& Gas .......... N 58 DE(; 8 MI N W 1701' (TO TARGET) GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD 10 11 12 13 14 15 16 17 18 19. 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. 13 5/8" 5000 !- _,1 BOP STACK 7 , 6 5 4 ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACKAND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEATAND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3.CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TESTANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO~FOM PIPE RAMS. TEST BOTFOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKSAND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE DOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" o 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 t. UPARUK RIVER UNI, 20" DIVERTER SCHEMATIC I I HCR 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENANCE & OPERATION . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16" CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6~J0 CEE~ LIST FOR NEW ~ PERM~T$ ITLM_ APPROVE DATE · ¢9 :hr= ' 10. /~,~I. ~. 1~.t~-~,, 1!. (~o md i3), 12., i3. (14 thru 22) (5) soP~ (22 thru 28) (29 t~' 3i)'- Geolo ~y: Enzineer!u~: rev: 01/30/89 6.0IL · 14. 15. Company Is the permi: fee at=ache~ .,. .......................................... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper disuance from property line .................. 4. Is well lo=aced proper disuance from other wells ........ ~ ........... 5. Is sufficient undedicaued acreage available in this pool ............ 6. Is well ~o be cleric=ed and is we!!bore plat included ................ 7. Is operator the only affected parry. ................................. 8. Cam permi= be approved before fifteen-day wait ...................... 16. 17. 18. 19. 20. al. 22. 23. 24. 25. 26. 27. 28. 30. 31. 3Z. Does operator have a bond in force .................................. Im a conservation order needed ...................................... Is administrative approval needed ................................... is :he lease number appropriate ..................................... Does =he well have a unique mama end number ......................... IS c6nductor string provided ........................................ Will surface casing prouect al! zones reasonably ~xpected 1:o serve as am underground source of drinking wa=ar ..................... '~, is enough cement used ~o circulate on conductor and surface ......... W~i~! cement tie iA surface and intermediate or production strings ...' Will cement cover ~ kmc~a productive horizons ..................... Will al! casing give adequate safety in collapse, tension amd burs:.. Is this =ell to be kicked off from an e--~Lsting wei!bore ............. ,.. Is old we!!bore abandomment procedure included on 10-403 ............ Is adequate weilbore separation proposed ..................... ' ...... Is a diver:er system required ....................................... /~-< · Is ~he drilling fluid program schematic and list of equipment adequaue ~e necess~ ~agr~ Does BOPS ~ve s~fici~: pres~re rau~g - Tes: Does ~e ~oka ~oi~ a~17 w/~Z ~-53 (~y 84) ............... ~... ~ ~e pr~ca of ~2S gas probable ............................. ~... e~ploratory a~d S=ratigraphic wellsr Are data presented on pouential overpressure zones? ................. Are seismic ena!ysis data presented on shallo~ gas zones ............. Lf am offshore loc.. are survey resul:s of seabed conditions preset:ad Addinional requiremenrm ............................................. '{ 'INITIAL ! GEO. ! ~IT i 0N/0FF POOL,, C~'_~S Z'~TUS, AREA NO~ ... Sl~OEZ CHECK LIST FOR NEW WELL PER,fITS (1) lee (2) Lo c APPROVE DATE 8) (9 :hr= (10 and 13) (14 mhz: Z2) . 3. 4. $. 6. 7. 8. Company ./~-___~ . 10. 1!. 12.' 13. 14. 15. ,~/, ~ £. (23 :hr= 28) 16. 17. 18. 20. 21. 22. 23. 24. 25. 26. 27. 28. !s the permit fee atmached .......................................... Is well to' be located in a defined pool ............................. Is well located proper dis:anco from property line .................. Is well located proper distance ~rom other wells ........ ; ........... Is sufficient undedicated acreage available in this pool ............. !s we!! =o be deviated and is we!!bore pla= included ................ Is operator the only affected party ................................. Can permit be approved before fifteen-day wait ...................... Does opera=or have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... is the lease number appropriate ..................................... Does =he well have a unique name and number ......................... Lease & YES _ IS adnductor s=ring provided ........................................ WiLl surface casing pro=act all zones reasonabiy exoected to serve as an underground source of drinking wa=er ..................... NO Is enough cement used 1:o circulate on conductor and surface ......... Will emmet= tie in surface and intermediate or production strings . ..' Will cement cover ~ known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burs=.. Is :his well :o be kicked off from an e.~-~suing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diveruer system required ....................................... is the drilling fluid program schematic and list of equipment adequate Are necessary diagr~ and descriptions of diverter and BOPE a~:ached. Does BOPE have sufficie~ pressure ra~ing - Test to .~OO.~p psig .. Does :he choke ~ifold comply w/AP1 RP-53 (~ay 84) .................. Is :he presence of H2S gas probable ............................. ~... Geoiogy;.,.- Engine er!ng: rev: 01/30/89 6.011. · For 29. 30. 31. 32. exploratory and Srrauigraphic wellsr Are data presented on pouenuia! overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed condluions presented ! , Additional requirements .............................. Additional X~mJrks: "" P,OOL CLASS STATUS AREA NO. , SMOKE , Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIXi .. No special 'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: 3G15 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G15.MWD SERVICE NAME: SSDS VERSION #: V2.40 DATE: 10/10/19 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD NPSC MWD RHOB MWD ROP MWD CAL MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD FXE MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT EWR MWD NPSC MWD RHOB MWD ROP MWD CAL MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD FXE MWD ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 1 4 0 1 68 OHMM 0 0 0 0 1 4 0 1 68 P.U. 0 0 0 0 1 4 0 1 68 G/C3 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 INCH 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 CTS 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 HOUR 0 0 0 0 1 4 0 1 68 ** DATA VERIFICATION DEPT NFl 3250.000 -999.250 3300.000 -999.250 3400.000 429.000 3500.000 545.667 3600.000 553.000 3700.000 564.333 3800.000 540.333 3900.000 511.000 4000.000 511.000 4100.000 519.000 4200.000 521.667 4300.000 512.600 4400.000 561.667 4500.000 559.000 4600.000 609.667 4700.000 564.333 4800.000 575.000 4900.000 522.555 5000.000 599.000 5100.000 567.000 (every 100 FT) ** EWR NN0 NPSC NN1 RHOB GRC -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9.198 2280.000 52.759 2312.000 2.582 47.264 6.121 2546.667 42.865 2482.667 2.287 99.413 5.096 2560.000 37.342 2664.000 2.268 93.699 5.411 2621.333 37.737 2605.333 2.294 88.025 5.387 2637.333 38.489 2450.667 2.295 81.649 4.253 2600.000 40.967 2520.000 2.275 87.208 4.218 2509.333 40.348 2504.000 2.302 96.178 4.392 2520.000 39.532 2488.000 2.459 89.621 3.824 2536.000 40.918 2440.000 2.247 95.346 3.769 2552.000 39.690 2625.600 2.297 74.137 3.099 2642.667 37.782 2584.000 2.309 87.193 3.537 2760.000 34.437 2664.000 2.297 100.240 4.430 2946.667 27.109 2930.667 2.378 69.513 3.431 2722.667 34.495 2680.000 2.285 87.009 2.799 2664.000 35.557 2712.000 2.293 83.939 2.370 2578.666 37.766 2664.000 2.284 99.403 3.260 2600.000 35.294 2672.000 2.380 105.119 3. 019 2674.667 34.422 2738.667 2.407 79.055 ROP FXE -999.250 -999.250 -999.250 -999.250 356.938 .751 283.136 .989 280.664 .825 420.605 .552 195.348 .832 331.108 .506 290.986 .535 280.120 .567 247.500 .715 206.055 .521 385.137 .588 275.474 .856 79.492 .789 74.438 .707 201.963 .679 278.951 .653 300.586 .467 235.437 .637 CAL -999.250 -999.250 8.745 9.358 8.738 8.735 8.916 8.809 8.756 8.992 8.754 8.853 8.672 8.703 8.648 8.724 8.724 8.744 8.889 8.930 NFO -999.250 -999.250 418.615 577.667 581.000 585.667 599.000 535.000 553.667 615.000 559.000 560.600 561.667 639.000 681.667 599.000 551.000 587.445 621.000 612.333 5200.000 588.333 5300.000 551.000 5400.000 568.600 5500.000 855.000 5600.000 607.000 5700.000 553.667 5800.000 583.000 5900.000 535.000 6000.000 628.333 6100.000 543.000 6200.000 603.000 6300.000 615.000 6400.000 599.000 6500.000 617.667 6600.000 623.000 6700.000 601.667 6800.000 567.000 6900.000 579.000 7000.000 667.000 7100.000 599.000 7200.000 581.400 7300.000 703.000 7400.000 711.000 2.748 2621.333 2.243 2584.000 2.091 2526.400 5.267 2840.000 3.709 2472.000 4.304 2589.333 3.609 2652.000 1.882 2584.000 3.922 2797.333 3.448 2712.000 3.996 2792.000 4.214 2812.000 4.064 2749.333 4.495 2909.333 4.358 2760.000 4.251 2840.000 3.945 2632.000 3.660 2712.000 8.311 3072.000 4.523 2776.000 4.016 2667.200 4. 133 2520. 000 3.863 2648.000 37.466 2589.333 38.369 2504.000 39.547 2494.400 25.647 2840.000 38.492 2376.000 37.884 2573.333 37.046 2608.000 36.851 2600.000 30.322 2850.667 33.034 2765.333 35.032 2776.000 32.779 2704.000 34.657 2738.667 30.867 2797.333 33.397 2872.000 31.436 2834.667 36.961 2600.000 34.325 2720.000 27.665 3112.000 33.981 2744.000 36.089 2644.800 35.1,47 2600.000 32.330 2648.000 2.474 86.371 2.336 98.591 2.304 103.475 2.492 195.229 2.385 164.592 2.528 140.981 2.261 114.085 2.416 138.503 2.410 96.952 2.384 77.420 2.449 91.265 2.870 82.319 2. 512 90.310 2.396 92.087 2.764 96.986 2.429 86.390 2.484 96.135 2.498 87.109 2.605 76.987 2.485 84.737 2.440 105.893 2.483 171.041 2.462 168.695 279 290 164 148 168 240 303 165 186 198 256 248 215 203 201 1 187 222 130 56 1 78 145 1 75 2 63 1 .627 .666 .385 .754 .394 .683 .641 .663 .327 .636 .271 .687 .809 .678 .428 .603 .768 .565 .047 .512 .138 .731 .438 .932 .487 .876 .906 ·685 .412 .027 .376 .841 .932 .754 .078 .900 .034 .325 .472 .945 · 617 .276 .732 .245 .466 .995 9.085 8.679 8.645 8.796 8.874 8.642 8.756 8.859 8.855 8.770 8.843 8.974 8.977 8.798 9.359 8.729 8.903 9.064 8.931 8.874 8.997 8.953 8.965 569.667 599.000 559.000 815.000 671.000 593.667 587.000 543.000 620.333 644.333 595.000 613.000 628.333 615.000 639.000 612.333 583.000 611.000 651.000 623.000 583.000 679.000 719.000 7500.000 519.000 2.626 43.352 2440.000 2440.000 2.342 113.915 7600.000 607.000' 4.151 37.690 2408.000 2424.000 2.308 188.719 7700.000 647.000 24.088 22.430 3240.000 3192.000 2.407 53.437 7800.000 559.000 5.594 38.780 2616.000 2808.000 2.323 88.828 7900.000 559.000 2.608 39.745 2392.000 2568.000 2.427 92.915 8000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 8100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 462 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 3G15.MWD SERVICE NAME: SSDS VERSION #: V2.40 DATE: 10/10/19 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE N~E: 1024 88.491 1.374 42.269 1.754 26.597 1.629 61.787 1.813 52.582 1.957 -999.250 -999.250 -999.250 -999.250 3250.00 TO 8.751 8.924 8.878 8.991 8.999 -999.250 -999.250 8100.00 FT 559.000 607.000 687.000 535.000 599.000 -999.250 -999.250 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: 3G15 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/10/19 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********