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Home My WebLink About190-132CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supv To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:NSK Wells Integrity Eng CPF1 & CPF3; NSK Wells Integrity Eng CPF2 Subject:10-426 forms for 2Z-pad & 3G-pad Witnessed MIT-IA"s & 3G-23 non-witnessed MIT"s 8/6/25 Date:Thursday, August 7, 2025 8:23:16 AM Attachments:image001.png MIT KRU 3G-12 and 15 08-06-25.xlsx MIT KRU 3G-23 SI TESTS 08-06-25.xlsx MIT KRU 2Z-2,3 and 14 08-06-25.xlsx Morning, Please see the attached 10-426 form from the AOGCC witnessed MIT-IA’s on 2Z-pad and 3G- pad as well as the non-witnessed MIT’s on 3G-23 that were performed on 8-6-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .58* 37' OPERATOR:FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1901320 Type Inj N Tubing 1771 1774 1774 1774 Type T 5745 BBL Pump 3.6 IA 310 3300 3130 3100 Interv 3000 BBL Return 3.2 OA 350 710 735 750 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1901320 Type Inj N Tubing 1771 1771 1771 1771 Type T 5745 BBL Pump 1.1 IA 290 360 370 370 Interv 1800 BBL Return 1.1 OA 290 2000 1900 1875 Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type Inj Tubing Type T BBL Pump IA Interv BBL Return OA Resu TYPE TEST Codes INTERVAL Codes Result Codes p, Kuparuk / KRU / 3G Pad Cook/Sheets 08/06/25 TIA to maximum anticipated injection pressure per AIO 2C.004 3G-23 3G-23 TOA to 1800 psi per AIO 2C.004 9 9 9 9 999 9 9 9 9 9 9 9 99À 99 9 9 -5HJJ TIA TOA AIO 2C.004 AIO 2C.004 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 3G-23 50-103-20144-00-00 190-132-0 W SPT 5744 1901320 1800 2698 2696 2697 2696 375 2010 1850 1820 REQVAR P Kam StJohn 10/8/2023 MIT/OA to 1800 psi per AIO 2C.004 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-23 Inspection Date: Tubing OA Packer Depth 90 150 150 150IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS231008124548 BBL Pumped:0.7 BBL Returned:0.7 Tuesday, December 5, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9MIT/OA AIO 2C.004 James B. Regg Digitally signed by James B. Regg Date: 2023.12.05 13:51:38 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, December 5, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/05/2023 3G-23 50-103-20144-00-00 190-132-0 W SPT 5744 1901320 3000 2697 2699 2696 2698 470 900 900 890 REQVAR P Kam StJohn 10/8/2023 MIT/IA to maximum anticipated injection pressure per AIO 2C.004 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-23 Inspection Date: Tubing OA Packer Depth 100 3410 3285 3200IA 2699 880 45 Min 3180 60 Min Rel Insp Num: Insp Num:mitKPS231008124248 BBL Pumped:4.5 BBL Returned:3.6 Tuesday, December 5, 2023 Page 1 of 1 9 9 9 9 9 9 9 9 999 9 9 9 9 MIT/IA t AIO 2C.004 James B. Regg Digitally signed by James B. Regg Date: 2023.12.05 13:49:45 -09'00' 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Wednesday, August 2, 2023 9:43 AM To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:3G PAD 10-426 forms from 8-1-23 Attachments:MIT KRU 3G Pad page 1 08-01-23.xlsx; MIT KRU 3G Pad page 2 08-01-23.xlsx; MIT KRU 3G-23 SI TESTS 08-01-23.xlsx Good AŌernoon, Please see the aƩached 10‐426 forms for the AOGCC witnessed tests that were conducted on 3G PAD on 8‐1‐23. Please let me know if you have any quesƟons or concerns. Thanks, Bruce Richwine/Shelby Sumrall DHD Field Supervisor KOC F‐wing 2‐14 (907) 659‐7022 Office (907) 943‐0167 Cell N2238@COP.com CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3G-23PTD 1901320 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1901320 Type Inj N Tubing 2100 2100 2100 2100 Type Test P Packer TVD 5745 BBL Pump 3.6 IA 200 3300 3120 3090 Interval V Test psi 3000 BBL Return 3.6 OA 120 520 520 520 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1901320 Type Inj N Tubing 2100 2100 2100 2100 Type Test P Packer TVD 5745 BBL Pump 1.1 IA 180 250 250 250 Interval V Test psi 1800 BBL Return 1.0 OA 50 2010 1980 1970 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 2C.004 Adam Earl declined to witness Notes: 3G-23 3G-23 Notes:MITOA to 1800 psi per AIO 2C.004 Adam Earl declined to witness Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3G Pad Caudle / Arend 08/01/23 Form 10-426 (Revised 01/2017)2023-0801_MIT_KRU_3G-23_2tests          J. Regg; 10/12/2023 MEMORANDUM TO: Jim Regg een P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3G-23 Insp Num• mitBDB210825102642 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, September 3, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhitlips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Sre: Inspector Reviewed By- P.I. Supry Comm API Well Number 50-103-20144-00-00 Inspector Name: Brian Bixby Permit Number: 190-132-0 Inspection Date: 8/24/2021 -- Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5744 Tubing 2750 2750 2750 2750 1800 IA 150 200 - 190 190 I OA 410 2000 1840 - 1805 P Friday, September 3, 2021 Page 1 of I Packer Well 3G-23 Type Inj w TVD PTD 1901320 Type Test SPT Test psi BBL Pumped: I BBL Returned: Interval REQVAR P/F Notes: MITOA as per AIO 20004 Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min 5744 Tubing 2750 2750 2750 2750 1800 IA 150 200 - 190 190 I OA 410 2000 1840 - 1805 P Friday, September 3, 2021 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor Teq FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Src: Inspector Reviewed By: P.I. Suprv� Comm Well Name KUPARUK RIV UNIT 3G-23 API Well Number 50-103-20144-00-00 Inspector Name: Brian Bixby Permit Number: 190-132-0 Inspection Date: 8/24/2021 v Insp Num: mitBDB210825102402 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G -z3 ,' TYPe Inj `h' TVD 5744 Tubing' 2750 2750 z�so 2zso _— PTD 1901320 'Type Test SPT Test pSl 3000 IA 150 3300 3150 3100 " BBL Pumped: i 4.2 - BBL Returned:, 4.1 OA 520 850 - 850 " 850 Interval REQVAR P/F P Notes: MITIA as per AIO 2C.004 v/ Thursday, August 26, 2021 Page 1 of 1 My I DIM1193F.101 at" TO: Jim Regg P.I. Supervisor �l l I 0(16I I I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 9, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Ste: Inspector Reviewed By: P.I. Sup" NON -CONFIDENTIAL Comm Well Name KUPARUK AIV UNIT 3G-23 API Well Number 50-103-20144-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ191009080359 Permit Number: 190-132-0 Inspection Date: 9/16/2019 ✓ Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G -z3 Type Inj w TVD naa 3000 Tubing IA zoos 430 zolo 3290 - zon 3150 zolz " 3120 - PTD 1901320 Type Test SPT Test psi BBL Pumped: 3.9 BBL Returned; 3. + 3.7 OA seo 870 880 880 ' REQVAR Intervalli Notes: IA x OA communication; 2 yr MIT -IA to MAIP AIO 2C.004. 1 well inspected, no exceptions noted. Wednesday, October 9, 2019 Page 1 of I MEMORANDUM TO: Jim Regg P.I. Supervisor Q� i l `,i< t / FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October 9, 2019 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-23 KUPARUK RIV UNIT 3G-23 Ste: Inspector Reviewed By: P.I. SuprxI p - NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-23 API Well Number 50-103-20144-00-00 Inspector Name: Jeff Jones Permit Number: 190-132-0 Inspection Date: 9/16/2019 Insp Num: mitJJ191009081101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-23 Type Inj w TVD 5744 - Tubing 2008 200 - 2009 2009 PTD 1901320 "I'ypQ Test SPT Test psi 1800 IA 430 - 480 - 490' - 490 1810 BBL Pumped: 0.9 ' BBL Returned: 0.8 OA Oso 1980 - 1850' Interval REQVAR P/F P Notes: IA x OA communication; 2 yr MIT -OA to 1800 psi; AIO 2C.011. 1 well inspected, no exceptions noted. Wednesday, October 9, 2019 Page I of I M -?el-Z-3 Regg, James B (CED) /DM tgO132-0 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 ��// Cc: NSK DHD Field Supervisor �l N04rl Subject: KRU 3G Pad SI MIT's Attachments: MIT KRU 3G PAD SI TESTS 08-15-19.xlsx 0 Please see the attached MIT test forms for shut in wells 3G-15, 3G-20, & 3G-23 in Kuparuk on 3G pad. Sincerely, Sa-WCarlt A& (}f "") / 2aCJ e Ka,4tk 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.carlisle@cop.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: Ilm eag4tal8sk8aoy, AOGCC.Insoectorsldalaska.00v: phoebe. brooksOalaska.aov OPERATOR: FIELD / UNIT / PAD: DATE: - OPERATOR REP: AOGCC REP: ConowPhillips Alaska Inc Kuparuk / KRU / 3G Pad 08/15/19 Duffy / Caudle Chris wlallacce4alaska.aov Well 3G-18 INTERVAL Codes Pressures: Well 3G-18 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min, 45 Min. 60 Min. 1=Initial Test P=Pass PTD 1901210 Type Inj N Tubing 1560 1560 1560 1560 O = Other (describe in notes) Type Test P Packer TVD 5727 1 BBL Pump 1 2.8 IA 200 3300 3260 3250 Interval V Test psi 3000 BBL Return 1 2.7 OA 20 20 20 20 Result P Notes: MITIA to maximum anticipated injection pressure per A102C.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-21 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320. Type InjN Tubing 1810 - 1810 1810 • 1810 - Type Test P Packer TVD 5745 BBL Pump 1 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 213,004 Well 3G-23 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1901320• Type Inj N Tubing 1 1810 - 1810 1810 - 1810 • Type Test P Packer TVD 5745 BBL Pump 1.0 IA 260 260 260 - 260- Interval V Test psi 1800 1381- Return 1.0 - OA 150 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 BBL Return OA Result Notes: INTERVAL Codes Result Cades TYPE INJ Codes TYPE TEST Codes W=Wetsr P=Pressure Test 1=Initial Test P=Pass G = Gas 0 = Other (describe in Notes) 4 = Four veer Cyde F = Fall S = Slurry V = Required by Vananm 1= Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting Form 10426 (Revised 01/2017) 2019-0a15_MIT _ KRU_ 3G -pad Swells STATE OF �OMMIALA OIL AND GAS CONSERVATION CO N RECEIVED REPORT OF SUNDRY WELL OPERATIONS NOV 0 6 2011 1.Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ O tutdown ❑ Performed: Suspend ID Perforate ❑ Other Stimulate Q Alter Casing❑ al(p�le�DD ogram ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD ACID Stimulate CI 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory ❑ 190-132 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service 0 6.API Number: 99510 50-103-20144-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 3G-23 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 7,420 feet Plugs measured None feet true vertical 6,133 feet Junk measured None feet Effective Depth measured 7,345 feet Packer measured 6,930 feet true vertical 6,073 feet true vertical 5,745 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 115' MD 115 TVD SURFACE 3,649 feet 9 5/8" 3,684' MD 3164 TVD PRODUCTION 7,357 feet 7 " 7,392' MD 6110 TVD SCANNED (� Perforation depth Measured depth 7040-7054,7070-7110 feet DEL 2 2 21)17 True Vertical depth 5831-5842,5854-86 feet Tubing(size,grade,measured and true vertical depth) 3 1/2 x 2 7/8 L-80 6,960' MD 5,768'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-HRP-1-SP RETRIEVABLE PACKER 6,930'MD 5,745'TVD SAFETY VLV-CAMCO TRDP-IA-SSA SAFETY' 1,812'MD 1,728 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1236 750 2675 Subsequent to operation: 0 0 1968 1400 2740 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ 0 WAG ❑ 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: 317-266 4` Authorized Name: Jason Burke q ItOvui,L..„ Contact Name: Jason Burke Contact Email: Jason.Burke@cop.com Authorized Title: Staff Wells Engineer y rf///Authorized Signature: C `-'v tr t� Date: 1t/( /Z0/ Contact Phone: (907)265-6097 1- viz- 117- ./7-- Form 1 /� l Form 10-404 Revised 4/2017 �J, ( -77�, RBDMS t/ NOV - 7 2017 Submit Original Only • • 3G-23 DAD ACID STIMULATE DTTMST.JOBTYP SUMMARYOPS 10/2/17 ACID RIH TO 7120' START PUMPING ACID, START LAYING IN ACID AND COULD NOT PICK UP, TEMPORARILY UNABLE TO MOVE PIPE, JOB IN PROGRESS 10/3/17 ACID PUMP N2 TO DISPLACE CT, UNABLE TO POOH; SPOT MINERAL OIL DOWN BACKSIDE OF CT, UNABLE TO POOH; CIRCULATE 5 BBL SWEEP MINERAL OIL AROUND SPOTTING SWEEP ON BACKSIDE FROM 1000'TO SURFACE, UNABLE TO MOVE CT. SECURE WELL AND SITE, RELIEF CREW DRY WATCHING CTU OVER NIGHT. 10/4/17 ACID CIRCULATE WELL WITH HEATED SLICK DIESEL WHILE ATTEMPTING TO MOVE CT, STILL DETAINED. PUMP 60 BBL SLICK SEAWATER TO CT WITH CHOKE CLOSE MANIPULATING CT, STILL DETAINED. BUILD CONTAINMENT, SET AND LOAD TANKS WITH SEAWATER, CT IN TENSION AT PUW=21K PUMPING SEAWATER DOWN TUBING AT 2.60 BPM. 10/5/17 ACID PUMP 63 DEG. SEAWATER DOWN PROD. TUBING AT 1.50 -2.0 BPM. MANIPULATE CT INTERMITTENTLY, PUW= 23 -25K, WHILE PUMPING SEAWATER, NO CHANGE, STILL DETAINED. DEPTH = 7141'. 10/6/17 ACID PUMP 63 DEG SEAWATER DOWN CT BACKSIDE WORKING PIPE, STILL DETEINED PUMP 30 BBL LVT MIN. OIL, WORK PIPE TO 7129'. PUMP SAFE LUBE EP TO CT BACKSIDE, WORK PIPE FREE, POOH AT 26K-28K. 10/7/17 ACID POOH WITH CT. FREEZE PROTECT WELL AND CT. RDMO CTU r KUP I 3G-23 ConocoPhillips - Well Attribunr Max Angle 4 D TD +ti,I,,ltik<,v....; ,;.,5 Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) tarrocoPh81,,,' 501032014400 KUPARUK RIVER UNIT INJ 40.88 2,600.00 7,420.0 n,... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3G-23,1113)20172-.16-.11 PM SSSV:TRDP Last WO: 37.21 10/5/1990 VerScalsohernabc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,187.0 1/1/2012 Rev Reason:WAIVERED WELL NOTE lehallf 11/9/2014 HANGER,313 _ Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED _ l' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 34.9 3,683.6 3,164.4 36.00 J-55 BTC Casing Description 'OD(in) 'ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 35.0 7,391.8 6,110.5 26.00 J-55 BTCAB- MOD .),,,,,,u.ot.a,,.,,�a.a..r,r,,,r.„,''"'"' .t, , -Tubing Strings Tubing Description String Ma... ID(in) Top(ftKB) Set Depth(ft..)Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection r'1 ) TUBING 2 7/8 2.441 31.3 6,960.6 5,768.4 6.50 L-80 AB MOD-EUE 3.5x2.875 @65' Mn , ,.,�Completion Details CONDUCTOR;38.0-115.0 -4 ' Nominal ID Top(ftKB) Top(TAD)(ftKB) Top Incl C) Item Des Com (in) 31.3 31.3 0.07 HANGER WKM GEN IV TUBING HANGER 3.500 1,812.1 1,727.8 3722 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 6,912.9 5,730.7 37.90 PBR 'CAMCO OEJ PBR 2.313 SAFETY VLV,1,812.1 h '% 6,930.4 5,744.6 37.88 PACKER CAMCP HRP-1-SP RETRIEVABLE PACKER 2.347 "I € 6,948.3 5,758.6 37.86 NIPPLE CAMCO D NIPPLE NO GO 2.250 ..` 6,960.0 5,767.9 37.85 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots GAS LIFT;2,5564 Shot Den Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,040.0 7,054.0 5,831.1 5,842.2 6/28/1996 4.0 APERF '1 11/16"EJ,0 deg. phasing 7,070.0 7,110.0 5,854.8 5,886.5 1/9/1991 4.0 (PERF 4.5"Expendable;180 deg.phasing Mandrel Inserts SURFACE;34.93,683.6 St ati on Top(TVD) Valve Latch Port Size TRO Run 1 N Top(ftKB) (COB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com GAS LIFT;4,234.6 1 2,556.4 2,297.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/12/1992 2 4,234.6 3,592.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 1028/1991 3 5,250.9 4,407.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1991 GAS LIFT;5,250.9 4 5,858.2 4,899.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/12/1992 5 6,371.8 5,304.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1991 GAS LIFT;5,858.2 6 6,859.1 5,688.3 MERLA TGPD 1 1/2 GAS LIFT DMY TG 0.000 0.0 2/12/1992 Notes:General&Safety End Date Annotation GAS LIFT;6,371.8 5/25/1996 NOTE:''BUCKLED TUBING ABOVE PBR @ 6913'**CAN'T PASS LONGER THAN 3'x2 1/8" 11/12/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/26/2014 NOTE:Waivered Well IA X OA Communication > GAS LIFT,6,859.1 PBR',6912.9 --_-_-- riliff PACKER.6,930.4 l®f't NIPPLE-,6,948.3 SOS;6,960.0 + APERF;7,040.0-7,054.0 (PERF;7,070.0-7,1t0.0-. PRODUCTION;35.0.7,391.8 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,August 10,2017 P.I.Supervisor `l7� 612(1( 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3G-23 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-23 Petroleum Inspector Src: Inspector Reviewed By,: P.I.Supry J NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-23 API Well Number 50-103-20144-00-00 Inspector Name: Chuck Scheve Permit Number: 190-132-0 Inspection Date: 8/5/2017 - Insp Num: mitCS170806072156 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-23 ' Type Inj W 'TVD 5744 - Tubing 2700 2700 - 2680 2670 PTD 1901320 ' Type Test SPT Test psi 1800 IA 690 870 - 910 910 • BBL Pumped: 0.8 BBL Returned: 0.8 OA 640 1985 1865 - 1840 - Interval REQVAR P/F P Notes: MITOA Per AIO 2C.004 Thursday,August 10,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim ReDATE: Thursday,August 10,2017 gg P.I.Supervisor � ( Z C' 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 3G-23 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-23API Well Number 50-103-20144-00-00 Inspector Name: Chuck Scheve Permit Number: 190-132-0 Inspection Date: 8/5/2017 Insp Num: mitCS170806071841 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-23 ' Type Inj W TVD 5744 Tubing 2650 2655 ' 2640 2690 PTD 1901320 -Type Test SPT Test psi 3000 - IA 690 3380 3230 3210 BBL Pumped: 3.7 • BBL Returned: 3.5- OA 640 910 910 - 910 Interval REQVAR P/F P Notes: Tested Per AIO 2C.004 SCANNED EL 2 o ,) Thursday,August 10,2017 Page 1 of 1 • • of T� ,w��\�yy, s� THE STATE Alaska Oil and Gas ti - „,‘ o ® T e c 1A Conservation Commission 333 West Seventh Avenue Anchorage,GOVERNOR BILL WALKER Alaska 99501-3572 Main: 907.279.1433 ALAS* Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke woe ,; ° ,r� 17 Staff Wells Engineer I�.�-:. � ��'� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 3G-23 Permit to Drill Number: 190-132 Sundry Number: 317-266 • 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 3C day of June,2017. RBDMS L 7 2017 • RECEIVED STATE OF ALASKA JUN 15 2011 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGICC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate IEr Pull Tubing ❑ Change Approved gram❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Acid Stimulate 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 190-132 ' 3.Address: Stratigraphic ❑ Service 0 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-103-20144-00 `C 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A `6'6°77 KRU 3G-23 • Will planned perforations require a spacing exception? Yes ❑ No LI 9.Property Designation(Lease Number): 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): 7,420' • 6,133' • 7345 6073 4125psi NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3,649' 12" 3,684' 3,164' Production 7,357' 7" 7,392' 6,110' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7040-7054,7070-7110 5831-5842,5854-5886 3 1/2 x 2 7/8 L-80 6,961' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-CAMCP HRP-1-SP RETRIEVABLE PACKER MD=6930 TVD=5745 SAFETY VLV-CAMCO TRDP-1A-SSA SAFETY VALVE MD=1812 TVD=1728 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ 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 ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com ii-- Contact Phone: (907)265-6097 Authorized Signature: Date:COSSION US ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317-2C4C., Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ c- (o tib 1 k4 Other: Post Initial Injection MIT Req'd? Yes ❑ No ra"--. Spacing Exception Required? Yes ❑ No V Subsequent Form Required: `e) —4-0 zf— RBDMS LV JUrd t 7 2017 APPROVED BY Approved by:if,),------. ...7 COMMISSIONER THE COMMISSION Date: ‘ /Z0( i 7 OjAQe \JPAti ,.is Form 10-403 Revised 4/2017 valid for 12 months from the date of approval. ' Attachments in Duplicate 07 . 4..- — 4,- ( ,l7 • • ConocoPhillips Alaska,Inc. ' Drilling&Wells Conoco fillips Well Intervention Alaska 3G-23 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 7120' 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 6960'. 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 HCI 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-23 Well Work Procedure Page 1 of 1 s^ KUP 3G-23 ConocoPhiHi s 8 Well Attribu Max Angillt D TD Alaska Int, Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) Carocatillips I 501032014400 KUPARUK RIVER UNIT INJ 40.88 2,600.00 7,420.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3G-23,6/14/2017 10.0622 AM SSSV:TRDP Last WO: 37.21 10/5/1990 - Vertical schematic(actual) _ Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,187.0 1/1/2012 Rev Reason:WAIVERED WELL NOTE lehallf 11/9/2014 HANGER;31.3 EMI j1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...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(WD)...WtlLen(I...Grade Top Thread SURFACE 95/8 8.921 34.9 3,683.6 3,164.4 36.00 J-55 BTC Ii. Cas ng Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(WD)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,391.8 6,110.5 26.00 J-55 BTC AB- MOD I �' t..-Tubing Strings I Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(WD)(...Wt(Ib/ft) Grade Top Connection �� TUBING 2 7)8 2.441 31.3 6,960.6 5,768.4 6.50 L-80 AB MOD-EUE 3 5x2 875 @65' Completion Details CONDUCTOR;38.0-115.0 Nominal ID Top(ftKB) Top(TVD)(ftKB) Top 1nc1 CI Item Des Corn (in) 31.3 31.3 0.07 HANGER WKM GEN IV TUBING HANGER 3.500 1,812.1 1,727.8 37.22 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE 2.312 6,912.9 5,730.7 37.90 PBR CAMCO OEJ PBR 2.313 SAFETY VLV,1,812.1 r';j 6,930.4 5,744.6 37.8C PACKER CAMCP HRP-1-SP RETRIEVABLE PACKER 2.347 I6,948.3 5,758.6 37.86 NIPPLE CAMCO D NIPPLE NO GO 2.250 6,960.0 5,767.9 37.85 SOS CAMCO SHEAR OUT SUB 2.441 Perforations&Slots GAS LIFT,2,556.4 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,040.0 7,054.0 5,831.1 5,842.2 6/28/1996 4.0 APERF 1 11/16"EJ,0 deg. phasing 7,070.0 7,110.0 5,854.8 5,886.5 1/9/1991 4.0 (PERF 4.5"Expendable;180 deg.phasing Mandrel Inserts SURFACE,34.9-3,683.6 St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn GAS LIFT,4,2346 1 2,556.4 2,297.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/12/1992 2 4,234.6 3,592.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1991 3 5,250.9 4,407.6 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1991 GAS LIFT,5.250.9 4 5,858.2 4,899.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/12/1992 I 5 6,371.8 5,304.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/28/1991 GAS LIFT,5,858.2 6 6,859.1 5,688.3 MERLA TGPD 1 1/2 IGAS LIFT DMY TG 0.000 0.0 2/12/1992 Notes:General&Safety End Date Annotation GAS LIFT;8,371.8 5/25/1996 NOTE:**BUCKLED TUBING ABOVE PBR @ 6913'"'CAN'T PASS LONGER THAN 3'x2 1/8" 11/12/2010 NOTE:View Schematic w/Alaska Schematic9.0 10/26/2014 NOTE:Waivered Well IA X OA Communication GAS LIFT;6,859.1 I PBR,6,9129 lb 1 PACKER;8,930.4 NIPPLE;8,948.3 1r I SOS,6,960.0 iii APERF;7,040.0-7,054.0 IPERF;7,070.0-7,110.0 PRODUCTION;35.0-7,391.8 6 0 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 28,2016 TO: Jim Regg P.I.Supervisor II l 145(/o SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-23 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv�' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-23API Well Number 50-103-20144-00-00 Inspector Name: Chuck Scheve Permit Number: 190-132-0 Inspection Date: 9/26/2016 Insp Num: mitCS160927154741 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-23 Type Inj 1 W TVD 5744 " Tubing 2706 ,, 2706 2706 - 2706 - PTD 1901320 . Type Test!SPT Test psi 1800 ., IA 1000 - 1050 -( 1050 - 1050 � — — Interval REQVAR P/F r P v OA 1550 2000 -1 1880 1850 Notes: MITOA Per AIO 2C.004 SCANNED JUN 0 7201% Wednesday,September 28,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,September 28,2016 TO: p 2 I to13 1 P.I.Supervisor SUBJECT: Mechanical Integrity Tests P.I. CONOCOPHILLIPS ALASKA INC 3G-23 FROM: Chuck Scheve KUPARUK RIV UNIT 3G-23 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv.� NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-23 API Well Number 50-103-20144-00-00 Inspector Name: Chuck Scheve Permit Number: 190-132-0 Inspection Date: 9/26/2016 Insp Num: mitCS160927154007 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min {1__ _� --- --- -- T 2706 2706 Well 36-23 Type Inj w 'TVD 5744 Tubing 2706 2706 PTD 1901320 '1Type Test SPT Test psi 3000 - IA 1060 3400 • 3280 - 3260 - Interval REQVAR P/F P / OA 590 810 'i 810 810 Notes: MITIA Per AIO 2C.004 SCANNED JUN 0 72017 Wednesday,September 28,2016 Page 1 of 1 • . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Regg P.I. Supervisor (II SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -23 FROM: Jeff Jones KUPARUK RIV UNIT 3G -23 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J� NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G -23 API Well Number: 50- 103 - 20144 -00 -00 Inspector Name: JeffJones Insp Num: mitJJ110906084404 Permit Number: 190 -132 -0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 3 G -23 ' 1 / 574 ' I 960 3050 2990 - 2940 ' 2920 - Well (Type Inj. N TVD P.T.D 1901320 1TypeTest I sPT Test psi ism - OA 240 510 510 510 500 Interval 4YRTST P/F P Tubing 2500 2475 2475 2475 2475 Notes: 3 BBLS diesel pumped. 1 well inspected; no exceptions noted. "i v Wednesday, September 07, 2011 Page 1 of 1 ~ Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ` `"`"~ ~ ~ "~''~~ ` ~- ~ ' ~ t1; Dear Mr. Maunder: ~ b~43d`~- ~~ ~~~~ Enclosed please find a spreadsheet with a Iist of wells from the Kupaiuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~', 9~' and 10~' 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, ~~G~ 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 DetB 08/11/09 ~i± au ov o on o..a Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitorJ sealant date bbls 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-10B 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 nla 17" Na 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 n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8l2009 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 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/S/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg ~.~ Có/l~¡ P.I. Supervisor 1"f1( '-ïò 7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOpmLLIPS ALASKA INC 3G-23 KUPARUK RIV UNIT 3G-23 FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .Jßf?- Comm NON-CONFIDENTIAL Well Name: KUPARUK RN UNIT 3G-23 API Well Number: 50-103-20144-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820 173421 Permit Number: 190-132-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-23 Type Inj. N TVD 5744 J vIA 700 2420 2350 2340 P.T. 1901320 TypeTest SPT Test psi 1500 -./ OA 20 40 40 40 Interval 4YRTST /P/F P ,// Tubing 2450 2450 2450 2450 Notes: Pretest pressures observed for 30+ minutes and found stable. ./' SCA.NNED SEP 1 0 2007 Wednesday, August 22, 2007 Page 1 of 1 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE OCTOBER 27, 2000 P M C:LO~M. DOC E E 1~ E W A T E R IA L U N D ER TH IS M ARK ER STATE OF ALASKA AI_A,SKA OIL AND GAS CONSERVATION COMMISL~uN REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing ~ Alter casing Stimulate Plugging Repair well 2. Name of Operator 15. Type of Well: Development ARCO Alaska. Inc. Exploratory 3. Address Stratigraphic P. O. Box 100360, Anchorage, AK 99510 Service 4. Location of well at surface 2528' FNL, 245' FEL, SEC.23, T12N, R8E, UM At top of productive interval 2177' FSL, 1418' FWL, SEC.23, T12N, R8E, UM At effective depth 2157' FSL, 1233' FWL, SEC.23, T12N, R8E, UM At total depth 2151' FSL, 1188' FWL, SEC.23, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7420' feet Plugs (measured) 6133' feet Perforate Other X 6. Datum elevation (DF or KB) RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-23 feet 9. Permit number/approval number 90-13;~ / 92-011 10. APl number ,50-103-2014400 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical 7345' feet Junk (measured) 6073' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 80' 3649' Size 16" 9-5/8" 7357' 7" measured 7070'-71 1 0' true vertical 5855'-5887' Cemented Measured depth True vertical depth 180 SX AS 1 115' 115' 835 SX AS III & 3684' 31 65' 460 SX CLASS G 200 SX CLASS G 7 3 9 2' 6 0 7 3' Tubing (size, grade, and measured depth) 2-7/8" L-80, 6.5#, IPC, EUE ABMOD, @ 6971' Packers and SSSV (type and measured depth) CAMCO HRP-SP PKR @ 6941', CAMCO TRDPolA-SSA SSSV @ 1796' 13. Stimulation or cement squeeze summary CONVERTED FROM PRODUCING WELL TO WATER INJECTION WELL Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1048 1587 0 1179 0 0 3625 Tubing Pressure 176 1616 16. Status of well classification as: Water Injector _X_=_ Oil m Gas ~ Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Petroleum Engineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE MORNINg WELL INPUT DATE 02/17/93 PAGE REPORT FOR pRODUCTION _ >~**.~****~-****~.~** INdEcTIoN WELL sTATus *~***~~**~ ~ S/I? ~ S T ; A Z ] T 0 _ U N . S E '0 SWI B '2 SWI B ~6 SWI B lO _SW I B I AI C C IV IV ANP CNP D C S AP AP MR NO NOM LdR TdR TE HB EISR ISR'ED dLB dLM LEEP UEEP Eg OE VNIE TNIE TI EU~ EUS OCSS ACSS M KA ECNS ECNS EN CML CMC WTSI LTSI PF EN NHgS NHgS Rg TES TEF 2750 2578 58 176 0 30 2750 2612 40 176 300 0 2750 2607 58 176 800 ~20 2750 2588 58 176 600 340 0 9500 0.000 0 6394 0.000 0 6828 0.000 0 5988 0.000 2750 2559 57 176 720 80 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O. 0 0 0 0 0 0 0 0 0 0 0 0 o 472 o. ooo 0 0 0.000 O 0 0.000 0 0 0.000 0 0.. 0.000 0 0 0.000 T C I 0 M D E E FOTALS' (SWI' 33437 + PWI' O) = 33437 0.0000 e**~******~*~ HEADERS **~****~*~**** * DRAIN )ROD H20 INO GAs INd GAS LIFT 1-8 9-16 ) P D P D P D p_ p p ] S E S E S E S S S ~F t ~F t GF I GF I I I t60 155 60 ~650 0 0 176 1430 220 260 ** METHANOL TANK LEVEL TEMP F PU D F I CL E T N TL gF 24 2. O0 52 0 ]OMMENTS: 3g-lO T/M BAD WOW :UNCTION KEYS HELP PRINT }ISPLAY FWD/BACK' PA~E ! PAGE FWD/BACK' OTHER INJECTION WELLS (IF ANY) SHIFTS' i) RETOTAL 2) UPDATE 3) PRINT D/S 4) REDO S/I,. ETC. 5) NEW DS (DS~ TOP) 3) PRINT S/S 7) S/S MULTIPRINT (CPF~: TOP) 8) D/S MULTiPRINT 9)' WAG I. OR II GAS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate _ Plugging __ Perforate _ Pull tubing X Alter casing __ Repair well X Other Repair 7" csg 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2528' FNL 245' FEL, SEC 23, T12N, R8E, UM At top of productive interval 2177', FSL, 1418' FWL, SEC 23, T12N, R8E, UM At effective depth 2156' FSL, 1233' FW;. SEC 23. T12N. R8E. UM At total depth 2151' FSL, 1188' FWL, SEC 23, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7420' 6133' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 90', 53' PAD 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3G-23 9. Permit number/approval number 90-132 /Conserv Order ~261 10. APl number 50-103-20144 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 7345' true vertical 6073' feet feet Junk (measured) Casing L e n g t h Structural Conductor 80' Surface 3 6 4 9' Intermediate P reduction 7 3 5 7' Liner Perforation depth: measured 7070' - 7110' MD' true vertical Size 16' 9-5/8" 7" Cemented 180 SX AS I 835 SX AS III & 460 SX Class G 200 SX Class G 5855' - 5887' TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# J-55 X/0 @ 65', 2-7/8" 6.5# L-80 @ 6961' Packers and SSSV (type and measured depth) CAMCO HRP-1-SP RETR @ 6930', CAMCO TRDP-1A-SSA SSSV @ 1812' Measured depth 115' md 3684' md 7392' md True vertical depth 115' tvd 3165' tvd 6111' tvd RECEIVED 13. Stimulation or cement squeeze summary See Attached Addendum Intervals treated (measured) Treatment description including volumes used and final pressure d U L - ? Alaska Oil & Gas Cons, ComrMSS'~Or~ 'Anchorage 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsecluent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector __ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Area Drillin~l Engineer Form 10-404 Rev 05/17/89 Date SUBMIT IN DUPLICATE ARC~O ALASKA INC. DAILY OPERATION, PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: 3G-23 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-103-20144 q o-~ ACCEPT: 11/16/91 07:11 SPUD: RELEASE: 11/29/91 12:11 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 11/16/91 (1) TD: 0 PB: 7345 MOVING RIG TO 3G PAD MOVING RIG. MW: 6.8 Diesel 11/17/91 ( 2) TD: 0 PB: 7345 11/18/91 (3) TD: 0 PB: 7345 11/19/91 (4) TD: 0 PB: 7345 11/20/91 ( 5) TD: 0 PB: 7345 WAIT ON WL UNIT _ ACCEPT RIG @ 0700 HRS 11-16-91. SITP=465MW:10'3' NaC1/Br PSI, SI 7" =750 PSI, SI 9-5/8" =725 PSI. RU AND PUMP SW TO PERFORATIONS. ESTIMATE KW TO BE 9.7 PPG EMW. PUMP 10.3 PPG BRINE DOWN TBG AND 7" CASING. COULD NOT INJECT DOWN 9-5/8" CSG. CIRCULATE BRINE DOWN TBG AND OUT 7' CSG VALVE. HOLE BETWEEN 300 AND 500'. COULD NOT PUMP DOWN 7" CSG AND UP TBG. TBGF AND CSG DEAD. SET BPV AND ND TREE. NU BOP STACK AND TEST SAME. BOLDS AND ATT TO PULL TBG. PU 1/2" CANNOT GO UP OR DOWN. CALL OUT E-LINE TO CUT TBG. MILLING OVER 2-7/8" TBG MW:10.1 NaC1/Br WO ATLAS WL. RU AND CUT TBG @ 265' WLM W/ JET CUTTER. POH AND LD TBG. GIH W/ 7" STORM VALVE AND SET @ 1' BELOW TBG SPOOL. ND 7-1/16" BOP STACK AND TBG SPOOL. NU 13-5/8" STACK. (TACK WELD 7" SLIPS TO CSG.) TEST BOPE. PULL STORM VALVE AND PU WASHOVER BHA. GIH OVERTBG STUB AND TAG UP @ 277' NORDIC RKB. MILL 4'. LOST 58 BBLS FLUID WHILE MILLING. DISPLACE W/ VISC BRINE MW:10.1 NaC1/Br GIH W/ WP TO 269' REV CIRC ARCTIC PACK OUT OF 9-5/8" X 7" ANNULUS. WASHOVER STUMP TO 285'. POH. LD WP AND PU O/S. TAG TOF @ 269' (MOVED DOWN 5'.) POH. NO RECOVERY. GIH W/ O/S. TAG TOF @ 273'. WORK DOWN TO 277'. POH. NO RECOVERY. REMOVE EXTENSION AND GIH. WORK TO 277' POH. RECOVERED 18' OF 2-7/8" TBG. ATT TO PULL 7" CSG. NO GO. CUT 7" CSG @ 277'. RECOVER 5 JTS AND 2 CUT JTS MU MILLING BHA. DISPLACE WELL WITH VISCOSIFIED BRINE @ 277' MILLING ON 7" AND 2-7/8" ~ MW:10.1 NaC1/Br FINISH DISPLACING WELL. MILL ON 7' AND 2-7/8" F/ 277'-288'. POH. HOLE TIGHT WITH METAL SHAVINGS. WORK OUT OF HOLE. GIH W/ SHOE AND 4-1/2" WP. ATT TO GET OVER TBG W/O SUCCESS. POH AND LD WP. MADE TWO LIMPRESSION BLOCK RUNS AND COULD NOT GET AN IMPRESSION. GIH W/ FLAT BOTTOM MM MILL AND MILL F/ 288'- 298' RECEIVED Alaska Oil & Gas Con,,. Commission Anchorage WELL : 3G-23 OPERATION: RIG : NORDIC 1 PAGE: 2 11/21/91 ( 6) TD: 0 PB: 7345 11/22/91 ( 7) TD: 0 PB: 7345 11/23/91 ( 8) TD: 0 PB: 7345 11/24/91 ( 9) TD: 0 PB: 7345 11/25/91 (10) TD: 0 PB: 7345 POH W/ 2-7/8" TUBING . MW:10.1 NaCl/Br MILLED ON 7' AND 2-7/8" TO 308'. TRIP FOR 1 JT 4-1/2" WP. GOT OVER TBG STUB AND WASHED TO 316'. TRIP FOR O/S AND GRAPPLE. WORKED OVER TOF FOR 2-1/2'. COULD NOT LATCH FISH. TRIP FOR WP AND 4-7/8" SHOE. WASH OVER TBG STUB TO 315'. TRIP FOR O/S AND GRAPPLE FOR TBG COLLAR. LATCH FISH AND PU OEJ OFF OF PKR. REVERSE CIRC TO BALANCE FLUIDS. POH. LD BHA AND TBG. HOLE WAS TIGHT WHEN SSSV CAME THROUGH TOP OF 7" STUB. POH W/ CSG CUTTER MW:10.1 NaCl/Br POH TO SSSV. CIRC VISCOSIFIED BRINE OUT OF WELL. CONTINUE TO POH AND LD COMPLETION STRING. PU 5-7/8" SWAGE. GIH AND SWAGE F/ TOP OF STUB @ 308'-310' TRIP FOR 6-1/8" SWAGE AND SWAGE 308'-310'. TRIP FOR CSG CUTTER. COULD NOT GET INTO STUB. TRIP AND INSTALL 5-7/8" SWAGE ON BOTTOM OF CUTTER. GIH AND CUT 7" CSG @ 386'. TRIP FOR SPEAR. CASING WOULD NOT PULL. RELEASE SPEAR AND TRIP FOR CSG CUTTER. CUT CSG @ 386'. POH W/ CUTTER. RU TO LD 7" CSG ' MW:10.1 NaC1/Br LD CSG CSG CUTTER. GIH W/ SPEAR AND LETCH 7" CSG. POH AND LD 77' CSG. MADE BIT RUN TO 4000'. CIRC HOLE CLEAN. POH. RU SWS. LOGGED W/ CBL F/3940' TO 200' TOC @ 2315'. RD SWS. PU 5-7/8" SWAGE AND CSG CUTTER. ~IH AND CUT CSG @ 1728'. POH AND LD TOOLS. GIH W/ SPEAR AND LATCH 7' CSG @ 386'. PU AND CIRC OUT ARCTIC PACK. POH AND LD TOOLS AND 7" CSG. POH AND LD 7" CSG MW:10.1 NaC1/Br POH AND LD 7" CSG. MU 8-1/2" BIT AND GIH TO TOP OF 7" STUB. CIRC ARCTIC PACK OUT OF HOLE. POH. GIH W/ RBP. COULD NOT GET IN 7" STUB. POH AND WAIT ON NEW RBP. GIH W/ NW BP. SET RBP @ 2202' TEST 9-5/8" CSG TO 1550 PSI FOR 1/2 HR. OK. TRIP FOR TRISTATE BACKOFF TOOL. BACK OUT CUT JOINT @ 1746'. POH. CUTTING 7" CSG MW:10.1 NaC1/Br FPOH AND LD TRISTATE BACKOFF TOOL. GIH W/ SPEAR AND LATCH 7" STUB. POH AND LD CUT JOINT. RU AND RUN NEW 7" CSG. DISPLACE ANNULUS W/ ARCTIC PACK PRIOR TO SCREWING IN. TEST CSG TO 2500 PSI. OK. ND BOP STACK AND INSTALL CSG SLIPS. PREP TO CUT OFF 7" CSG. ,jU k -'~ Alaska. Oil & Gas Cons. Commission Anchoraga WELL : 3G-23 OPERATION: RIG : NORDIC 1 PAGE: 3 11/26/91 (11) TD: 0 PB: 7345 11/27/91 (12) TD: 0 PB: 7345 11/28/91 (13) TD: 0 PB: 7345 DISPLACING VISCOUS BRINE MW:10.1 NaC1/Br FIN 7" CUT. ND BOP STACK. INSTALL TUBING SPOOL. NU 7-1/16" BOP STACK. TEST PLUG WAS SET ABOVE LOCK DOWN SCREWS AND WAS DAMAGED WHEN PRESSURE WAS APPLIED. ND STACK AND INSPECT WELLHEAD AFTER PULLING TEST PLUG. NU BOP STACK AND INSTALL BORE PROTECTOR. GIH TO 1800' AND DISPLACE DIESEL OUT OF WELL. FGIH AND LATCH RBP. RELEASE SAME. CBU AND POH. PU CAMCO 'OEJ' AND GIH TO TEST PKR AND CSG. LD FISHING TOOLS MW:10.1 NaC1/Br FGIH W/ 'OEJ'. COULD NOT GET OVER SLICK SLICK. POH. JUNK MARKS ON OD OF 'OEJ.' PU WASH-OVER SHOE ABD O/S. GIH AND WASH OVER STICK. LATCH STICK. PKR RELEASED. POH. REC'D 'OEJ', PKR AND TAIL PIPE. LD FISH AND FISHING TOOLS. ALSO RECOVERED SLIVER OF 7" CASING. PREPARE TO RUN TBG MW:10.1 NaC1/Br MADE BIT AND SCRAPER RUN. PUSH JUNK TO 7224'. CLEAN OUT SAND TO 7232'. POH AND PREPARE TO RUN TUBING 11/29/91 (14) TD: 0 PB: 7345 RR @ 0000 HRS 11-29-91 MW: 6.8 Diesel FIN RU AND RUN 3-1/2" X 2-7/8" COMPLETION ASS'Y. DROPPED SETTING BALL. PRESSURE TBG TO 2500 PSI AND SET PACKER. SHEARED 'OEJ.' TESTED SSSV. OK. SHEAR OUT BALL WITH 3200 PSI. CLOSE SSSV AND INSTALL BPV. ND BOP STACK AND NU TREE. TEST PACKOFF AND TREE TO 250/5000 PSI. PULL TEST PLUG, OPEN SSSV, AND DISPLACE WELL TO DIESEL. SITP = 800 PSI. SICP = 800 PSI. 9-5/8" X 7" ANNULUS PRESSURE = 700 PSI. SECURE WELL. RD AND MO RIG. RR @ 0000 HRS 11-29-91. RECEIVED 4lastra Oil & G~.s Cons. Anchorage (,'omrnission APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program ..~ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension_ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2528' FNL, 245' FEL, Sec. 23, T12N, R8E, UM At top of productive interval 2177' FSL, 1418' FWL, Sec. 23, T12N, R8E, UM At effective depth 2157' FSL, 1233' FWL, Sec. 23, T12N, R8E, UM At total depth 2151' FSLr 1188' FWL, Sec. 23~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 7420' feet true vertical 61 3 3' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 90 7. Unit or Property name Kuparuk River Unit Effective depth: measured true vertical 7345' feet Junk (measured) 6073' :feet None Casing Length Structural Conductor 8 0' Surface 3 6 4 9' Intermediate Production 7 3 5 7' Liner Perforation depth: measured 7070'-71 10' true vertical 5855'-5887' Size Cemented 1 6" 180 Sx AS I 9 5/8" 835 Sx AS III & 460 Sx Class G 7" 200 Sx Class G feet 8. Well number 3G-23 9. Permit number 10. APl number 5o-103-;~0144 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 11'5' 115' 3684' 3165' 7392' 6073' Tubing (size, grade, and measured depth) 2-7/8" L-80 , 6.5#,1PC, EUE ABMOD, W/Tail @ 6971' Packers and SSSV (type and measured depth) Camco HRP-1-SP Pkr. ~ 6941'~ Camco TRDP-1A-SSA SSSV ~ 1796' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch Convert well from oil producer to water injector. 14. Estimated date for commencing operation ~15. Status of well classification as: MARCH 1992 I Oil _ Gas _ Suspended 16. If proposal was verball/y approvalS, Name of approver / ' (~' '"~'"'";'~-~ /-- "' Date approved t Service Water In!action 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sic]ned C, ~L)-~ Title Operations Engineer Aiaska Oil & Gas Cons. FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BO? Test_ Location clearance__ Mechanical Integrity Test ..~ Subsequent form require ORIGINAL SIGNED B'~ Approved blt order of the Commission Form 10-403 Rev 09/12/90 IApproval No. 7 10. ,~"~'~-- : ' /-30- ?~ Commissioner Date /- ,~ H- c~ ~ SUBMIT IN TRIPLICATE Well 3G-23 Conversion to Water Injection ARCO Alaska requests approval to convert Well 3G-23 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 7040' and 7170'. 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. ARCO Alaska, Inc. Date: December 6, 1991 Transmittal #: 8300 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 Cased Hole items. return one signed copy of this transmittal. Receipt Cement Bond Log Cement Bond Log Ultrasonic Imager Drilling Please acknowledge receipt and 1 1-22-91 1 1-28-91 11-28-91 Ultrasonic Imager 1 1 - 2 8 - 91 Cement Bond Log 1 1 - 2 8 - 91 Acknowledge' ~~e' V Stale of Al~.~(~+sepia) 200-3940 6140-8988 6146-8994 5770-10478 6000-10485 NSK RECEIVED DEC 0 9 1991 AJaska 0il & Gas Cons. CornmissJon Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM,,,,SSION WELl_ COMPLi=TION OR RI=COMPLI=TION REPORT AND LOG 1 Status of Well ClassificaUon of Service Well OIL ~'l GAS [~] SUSPENDED [~] ABANDONED E~] SERVICE E~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-132 3 Address 8 APl Number P.O. BOX 100360, Anchorage, AK 99510-0360 -[-~~ 50-103-20-144 4 Location ofwell atsurface ~ ;-~i~,~ ~ ~:' ,"~? ~ ;9 Unitor Lease Name .......... i l, VEf.~IFFf-D 5hq ~ ~ ~,~:'.'~_ i KUPARUK RIVER At Top Producing nterva i ! i 10 We, Number 2177'FSL, 1418'FWL, SEC23, T12N, RSE, UM i ,'~--~-~- i ' 11 Fie~d and Pool At Total Depth 2151' FSL, 1188' 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., Sus, p. or Abend. I 15 Water Depth, if offshore 16 No. of Completions 9~28/90. 10103/90. 11; 01~3. //'//./?/I NA feet MSL 1 7420' MD, 6133' TVD 7345' MD, 6073' TVD YES ~ NO [~ 1796' feet MD 1600' APPROX 22 Type Electric or Other Logs Run EWR, CN, SFD, DGR, CET, CBL, GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 180 SX AS I 9-5/8" 36~ J-55 SURF 3684' 12-1/4" 835 SX AS III, 460 SX CLASS G 7" 26~ J-55 SURF 7392 8-1/2" 200 SX CLASS G 24 Perforations open to Production (MD+'I'VD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 6.5# L-80 6971' 6941' 7070'-7110' W/4-1/2" CSG GUN @ 4SPF MD 5855'-5887' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL iGAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ,,~ FIowTubing 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. ,, _ ~.~ £.. , V~.~ ~!..z'/! ~.: ..~,._ "~':/"h"¥ ~? El) ?0(-;1 ' ~:4~?/;~? ,'7" ' ~'~" "-,.'-.W.& ~as Cons Form 10-407 Submit in duplicate Rev. 7-1-80 ~INUED ON REVERSE SIDE i GEOLOGIC MARKERS FORMATION TESTS NA,'VE Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7040' 5831' NA KUPARUK C BO'FrOM 7040' 5831' KUPARUK A TOP 7040' 5831' KUPARUK A BO'FrOM 7170' 5934' I I i 1 3~. LIST OF ^'I'-I'^~I-tMEhlTS GYRO, 32. I hereby certify ~hat tho forogoino is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repod 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 pedinent 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 OiI and Gas Company Well History - Initial Report- Daily Inst,uctions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. ICounty. parish or borough NORTH SLOPE Lease or Unit ADL:25547 ALK: 2661 Title COMP LET I ON JState AK Well no. 3G~23 KUPARUK Auth. or W.O. no. AK5181 Operator ARCO Spudded or W.O. begun IDate IHour SPUD 09/28/90 13:00 Date and depth as of 8:00 a.m. 01/10/91 ( TD: 0 PB: 7345 SUPV:GB/SK 8) ARCO Wi 55. 252072 Pnor status ;f a wo Complete record for each day reported -NORDIC 1 RIH W/COMP ASSY 7"@ 7392' MW:10.6 NaCl/Br MOVE RIG F/3G-24 TO 3G-23, RIG ACCEPTED ON 1/10/91 @ 12:30, ND MASTER VALVE, NU BOPE, CHANGE PIPE RAMS TO 2-7/8", TEST BOPE, RU HLS & PERF IN TWO RUNS F/7070'-7110' W/4.5" CSG GUNS @ 4 SPF 180 DEG PHASE AND ALTERNATING BIG HOLE CHARGES, RD HLS, NU FLOWLINE, RU & RUN 2-7/8" COMP ASSY, DAILY:S33,480 CUM:$733,192 ETD:S733,192 EFC:$1,310,200 The above is correct Signature For form preparation and distributj,~, see Procedures Manual, Section Drilling, Pages 86 and 87. AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after alrowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon comple!ion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting cost center code District State ARCO ALASKA INC. AK ICounty or Parish NORTH SLOPE Lease or Unit ADL: 25547 ALK:2661 Title COMPLETION I Well no. 3~-23 KUPARUK Auth, or W.O. no. AK5181 Operator ARCO Spudded or W.O. begun SPUD A.R.Co. W.I. Date Iotal number of wells (active or inactive) on this ost center prior to plugging and 55. 252 bandonment of this well 0'72 our13:00 Prior status if a W.O. 09/28/90 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 01/11/91 ( TD: 0 PB: 7345 SUPV:GB/SK 9) RIG RELEASED 7"@ 7392' MW:10.6 NaC1/Br MU TBG HANGER IN COMP STRING, TEST HANGER & CL TO 5000 PSI F/15 MIN, LAND TBG , RILDS, SET PKR, BOLDS, PU & SHEAR, OEJ, RELAND TBG, RILDS, TEST SSSV F/15MIN W/500 PSI DIFF, BLEED TBG & ANN PRESS, CLOSE SSSV, LD LANDING JT, SET BPV, ND BOP STACK, NU TREE, PULL BPV, SET TP, TEST TREE TO 250/5000 PSI, TEST PO TO 5000 PSI, PULL TP, OPEN SSSV, TEST ANN TO 2500 PSI, F/15 MIN, PRES TBG & SHEAR OUT BALL, DISPLACE ANN W/12 BBL DIESEL & BULLHEAD 4 BBL DIESEL DOWN 2-7/8" TBG SECURE WELL, SITP=250 PSI, SICP=0 PSI, RELEASE RIG 1/10/91 @ 13:30 DAILY:S138,099 CUM:$871,291 ETD:S871,291 EFC:$1,310,200 Old TD 'I New TD PB Depth Released rig I Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off cial reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effechve !,v,: corrected __ The above is correct Signature /~.~ ~ IDate~/ ~/¢/ Title For form preparati ....d distribu ~~ / / Drilling Supt. seep .... d .... M a ~nJ,% ed ~I ~ nb u~Y0...~' Drilling, Pages 86 and 87. AR3B-459-3-C rNumber all daily well history forms consecutively : as they are prepared for each well. Division of Atlant~cRIchh-,dCor'npany ORIGINAL A GYRODATA DIRECTIONAL SURVEy FOR ARCO ALASHA INCORPORATED KUPARUH RIVER UNIT, WELL NUMBER NORTH SLOPE BOROUGH, ALASKA. DATE : 06 DECEMBER 1990 ]REAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 11/26/90 ~lient .... : ARCO ALASKA, INC. ~ield ..... : KUPARUK RIVER UNIT ~ell ...... : KRU 3G-23 ~ection at: S,80.85,W ~urveyor..: ROB SHOUP Computation...: Survey Date...: RKB Elevation.: Job Number .... : API Numbeer...: RADIUS OF CURVATURE 11/16/90 90.00 ft AKl190G254 50-103-20144 MEAS DEPTH 100 200 300 400 500 INCLN VERTICAL-DEPTHS ANGLE BKB SUB- SEA RECORD OF SURVEY SECTION DIRECTION DISTNCE BEARING 0.22 100.0 10.0 0.2 N 85.47 W 0.20 200.0 110.0 0.5 N 70.26 W 0.26 300.0 210.0 0.9 N 85.44 W 0.57 400.0 310.0 1.6 S 87.29 W 3.85 499.9 409.9 5.4 N 84.15 W RELATIVE-COORDINATES FROM-WELL-HEAD CLOSURE DISTNCE BEARING /lOO 0.0 N 0.2 W 0.2 N 85.47 W 0.22 0.1 N 0.5 W 0.6 N 80.48 W 0.02 0.2 N 0.9 W 1.0 N 79.38 W 0.06 0.2 N 1.7 W 1.7 N 83.56 W 0.31 0.3 N 5.5 W 5.5 N 86.95 W 3.28 600 6.83 599.5 509.5 14.4 N 85.70 W 700 9.28 698.5 608.5 28.2 N 89.83 W 800 10.17 797.0 707.0 44.8 S 89.78 W 900 12.82 895.0 805.0 64.6 S 85.40 W 1000 17.23 991.6 901.6 90.5 S 79.76 W 1.1 N 14.8 W 14.8 N 85.68 W 2.98 1.7 N 28.8 W 28.8 N 86.69 W 2.45 1.7 N 45.7 W 45.7 N 87.92 W 0.89 0.8 N 65.6 W 65.6 N 89.29 W 2.66 2.5 S 91.3 W 91.3 S 88.41 W 4.44 1100 22.07 1085.7 995.7 124.1 S 78.55 W 1200 22.43 1178.3 1088.3 162.0 S 83.42 W 1300 22.93 1270.5 1180.5 200.5 S 83.29 W 1400 23.02 1362.6 1272.6 239.5 S 84.14 W 1500 23.21 1454.6 1364.6 278.6 S 85.07 W 8.9 S 124.3 W 124.6 S 85.93 W 4.84 14.8 S 161.7 W 162.3 S 84.77 W 0.80 19.2 S 200.0 W 200.9 S 84.50 W 0.50 23.5 S 238.8 W 239.9 S 84.37 W 0.16 27.2 S 277.8 W 279.2 S 84.41 W 0.24 1600 25.25 1545.8 1455.8 319.6 S 82.89 W 1700 29.66 1634.5 1544.5 365.7 S 82.30 W 1800 36.79 1718.1 1628.1 420.4 S 80.01 W 1900 40.36 1796.2 1706.2 482.8 S 80.08 W 2000 39.90 1872.7 1782.7 547.2 S 80.66 W 31.5 S 318.7 W 320.2 S 84.35 W 2.08 37.5 S 364.4 W 366.3 S 84.13 W 4.41 45.9 S 418.5 W 421.0 S 83.74 W 7.18 56.7 S 479.9 W 483.2 S 83.27 W 3.57 67.4 $ 543.4 W 547.6 S 82.93 W 0.52 ? 2100 40.31 1949.2 1859.2 611.6 S 81.25 W 77.6 S 607.0 W 612.0 S 82.72 W 0.48 'Survey Codes: 7/GYRO [KRU3G23G Bl.17) KRU 3G-23 Page 2 11/26/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE 7 2200 40.42 7 2300 40.06 7 2400 40.35 7 2500 40.55 7 2600 40.88 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 2025.4 1935.4 676.4 S 81.35 W 87.4 S 671.1 W 676.7 S 82.58 W 0.12 2101.7 2011.7 741.0 S 82.49 W 96.4 S 735.0 W 741.3 S 82.53 W 0.59 2178.1 2088.1 805.5 S 82.63 W 104.8 S 799.0 W 805.9 S 82.53 W 0.30 2254.2 2164.2 870.4 S 83.16 W 112.8 S 863.4 W 870.7 S 82.56 W 0.30 2330.0 2240.0 935.5 S 82.53 W 120.9 S 928.1 W 936.0 S 82.58 W 0.43 7 2700 39.91 2406.1 2316.1 1000.3 S 77.37 W 132.2 S 991.9 W 1000.7 S 82.41 W 2.34 7 2800 39.51 2483.1 2393.1 1064.1 S 77.23 W 146.3 S 1054.2 W 1064.3 S 82.10 W 0.40 7 2900 39.36 2560.3' 2470.3 1127.5 S 77.11 W 160.4 S 1116.2 W 1127.6 S 81.82 W 0.16 7 3000 39.56 2637.5 2547.5 1190.9 S 77.36 W 174.4 S 1178.2 W 1191.0 S 81.58 W 0.22 7 3100 39.89 2714.4 2624.4 1254.7 S 77.50 W 188.4 S 1240.5 W 1254.8 S 81.37 W 0.33 7 3200 39.54 2791.4 2701.4 1318.5 S 77.17 W 202.4 S 1302.9 W 1318.5 S 81.17 W 0.37 7 3300 39.52 2868.5 2778.5 1382.0 S 77.31 W 216.4 S 1365.0 W 1382.0 S 80.99 W 0.06 7 3400 39.62 2945.6 2855.6 1445.6 S 78.06 W 230.0 S 1427.2 W 1445.6 S 80.84 W 0.32 7 3500 39.53 3022.6 2932.6 1509.2 S 77.85 W 243.3 S 1489.5 W 1509.2 S 80.72 W 0.12 7 3600 39.49 3099.8 3009.8 1572.8 S 78.32 W 256.4 S 1551.7 W 1572.8 S 80.62 W 0.19 7 3700 39.33 3177.1 3087.1 1636.2 S 78.15 W 269.4 S 1613.9 W 1636.2 S 80.52 W 0.17 7 3800 39.21 3254.5 3164.5 1699.4 S 77.78 W 282.6 S 1675.8 W 1699.5 S 80.43 W 0.19 7 3900 39.19 3332.0 3242.0 1762.5 S 77.88 W 295.9 S 1737.6 W 1762.6 S 80.34 W 0.04 7 4000 39.19 3409.5 3319.5 1825.6 S 77.97 W 309.1 S 1799.4 W 1825.7 S 80.25 W 0.04 7 4100 39.16 3487.0 3397.0 1888.7 S 77.97 W 322.3 S 1861.2 W 1888.9 S 80.18 W 0.03 7 4200 37.78 3565.3 3475.3 1950.9 8 79.21W 334.6 S 1922.1 W 1951.0 S 80.13 W 1.46 7 4300 37.37 3644.5 3554.5 2011.9 S 80.03 W 345.6 S 1982.1 W 2012.0 S 80.11 W 0.51 7 4400 37.16 3724.1 3634.1 2072.4 S 79.53 W 356.3 S 2041.7 W 2072.6 S 80.10 W 0.28 7 4500 36.93 3803.9 3713.9 2132.6 S 79.43 W 367.3 S 2100.9 W 2132.8 S 80.08 W 0.23 7 4600 36.79 3884.0 3794.0 2192.6 S 79.32 W 378.4 S 2159.9 W 2192.8 S 80.06 W 0.15 7 4700 36.32 3964.3 3874.3 2252.1 S 79.39 W 389.4 S 2218.4 W 2252.3 S 80.04 W 0.47 ^Survey Codes: 7/GYRO KRU 3G-23 Page 3 11/26/90 RECORD OF SURVEY MEAS INCLN DEPTH ANGLE 4800 36.22 4900 36.51 5000 36.23 5100 36.63 5200 36.61 VERTICAL-DEPTHS BKB SUB-SEA SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 4044.9 3954.9 2311.3 S 78.87 W 400.5 S 2276.5 W 2311.5 S 80.02 W 0.21 4125.4 4035.4 2370.5 S 80.94 W 410.9 S 2334.9 W 2370.8 S 80.02 W 0.79 4206.0 4116.0 2429.8 S 80.76 W 420.4 S 2393.4 W 2430.1 S 80.04 W 0.29 4286.4 4196.4 2489.2 S 81.92 W 429.3 S 2452.2 W 2489.4 S 80.07 W 0.57 4366.7~ 4276.7 2548.9 S 81.65 W 437.8 S 2511.2 W 2549.1 S 80.11 W 0.10 7 5300 36.52 4447.0 4357.0 2608.4 S 81.99 W 446.3 S 2570.2 W 2608.6 S 80.15 W 0.15 7 5400 35.78 4527.7 4437.7 2667.4 S 84.07 W 453.5 S 2628.7 W 2667.5 S 80.21 W 1.03 7 5500 35.50 4609.0 4519.0 2725.5 S 85.07 W 459.0 S 2686.7 W 2725.6 S 80.31 W 0.44 7 5600 35.52 4690.4 4600.4 2783.4 S 85.32 W 463.8 S 2744.6 W 2783.5 S 80.41 W 0.09 7 5700 35.63 4771.7 4681.7 2841.5 S 84.55 W 469.0 S 2802.5 W 2841.5 S 80.50 W 0.28 7 5800 36.82 4852.4 4762.4 2900.4 S 84.56 W 474.6 S 2861.4 W 2900.5 S 80.58 W 1.19 7 5900 37.60 4932.1 4842.1 2960.8 S 83.84 W 480.7 S 2921.5 W 2960.8 S 80.66 W 0.82 7 6000 37.79 5011.2 4921.2 3021.9 S 83.55 W 487.4 S 2982.3 W 3021.9 S 80.72 W 0.22 7 6100 37.99 5090.1 5000.1 3083.2 S 83.40 W 494.4 S 3043.3 W 3083.2 S 80.77 W 0.21 7 6200 38.04 5168.9 5078.9 3144.7 S 83.46 W 501.4 S 3104.5 W 3144.7 S 80.82 W 0.05 7 6300 38.01 5247.7 5157.7 3206.3 S 83.59 W 508.4 S 3165.7 W 3206.3 S 80.88 W 0.06 7 6400 37.98 5326.5 5236.5 3267.8 S 83.03 W 515.6 S 3226.9 W 3267.8 S 80.92 W 0.21 7 6500 38.04 5405.3 5315.3 3329.3 S 82.64 W 523.2 S 3288.0 W 3329.3 S 80.96 W 0.16 7 6600 38.13 5484.0 5394.0 3391.0 S 82.99 W 531.0 S 3349.2 W 3391.0 S 80.99 W 0.16 7 6700 38.23 556Z.6 5472.6 3452.8 S 82.35 W 538.8 S 3410.5 W 3452.8 S 81.02 W 0.26 7 6800 37.65 5641.4 5551.4 3514.2 S 82.27 W 547.1 S 3471.4 W 3514.2 S 81.04 W 0.58 7 6900 37.92 5720.5 5630.5 3575.5 S 82.87 W 555.0 S 3532.2 W 3575.5 .S 81.07 W 0.35 7 7000 37.80 5799.4 5709.4 3636.8 S 83.12 W 562.5 S 3593.1 W 3636.8 S 81.10 W 0.15 7 7100 37.66 5878.5 5788.5 3697.9 S 83.33 W 569.7 S 365'3.8 W 3698.0 S 81.14 W 0.16 7 7200 37.30 5957.9 5867.9 3758.7 S 83.61 W 576.6 S 3714.3 W 3758.8 S 81.18 W 0.37 7 7300 37.35 6037.4 5947.4 3819.3 S 83.87 W 583.2 S 3774.6 W 3819.4 S 81.22 W 0.11 ^Survey Codes: 7/GYRO KRU 3G-23 Page 4 11/26/90 RECORD OF SURVEY S MEAS INCLN C DEPTH ANGLE X 7420 37.35 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 6132.8 6042.8 3892.0 DIRECTION BEARING S 83.87 W RELATIVE-COORDINATES FROM-WELL-HEAD 591.0 S 3846.9 W CLOSURE DISTNCE BEARING /lOO 3892.1 S 81.27 W 0.00 ^Survey Codes: X/EXTRAPOLATED KRU 3G-23 DATA INTERPOLATED FOR 100 Page FT SUBSEA INTERVAL 5 11/26/90 SUBSEA DEPTH 0 100 2OO 300 40O 5OO 600 7OO 8OO 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2O00 2100 2200 2300 2400 MEAS DEPTH 90 190 290 390 490 590 691 793 895 998 1105 1213 1321 1430 1539 1649 1765 1892 2023 2154 2285 2416 2547 2679 2809 INCLN TVD MD-TVD VERT ANGLE BKB DIFF CRRT 0.20 90 0 0.20 190 0 0.25 290 0 0.54 390 0 3.52 490 0 6.55 590 0 9.07 690 1 10.11 7'90 3 12.68 890 5 17.16 990 8 22.09 1090 15 22.49 1190 23 22.95 1290 31 23.08 1390 40 24.00 1490 49 27.43 1590 59 34.33 1690 75 40.07 1790 102 39.99 1890 133 40.37 1990 164 40.12 2090 195 40.38 2190 226 40.71 2290 257 40.11 2390 289 39.50 2490 319 DIRECTION BEARING 0 N 85.47 W 0 N 71.78 W 0 N 83.92 W 0 S 88.02 W 0 N 85.00 W 0 N 85.55 W 1 N 89.48 W 1 S 89.81 W 2 S 85.63 W 3 S 79.85 W 6 S 78.77 W 8 S 83.40 W 8 S 83.47 W 9 S 84.42 W 9 S 84.23 W 11 S 82.60 W 16 S 80.80 W 26 S 80.07 W 31 S 80.79 W 31 S 81.30 W 31 S 82.32 W 31 S 82.71 W 32 S 82.86 W 32 S 78.46 W 30 S 77.22 W RELATIVE COORDINATES FROM WELL HEAD 0.01 N 0.16 W 0.08 N 0.52 W 0.17 N 0.90 W 0.19 N 1.57 W 0.25 N 4.88 W 1.03 N 13.68 W 1.65 N 27.41 W 1.66 N 44.42 W 0.90 N 64.44 W 2.44 S 90.79 W 9.19 S 125.98 W 15.34 S 166.48 W 20.20 S 208.15 W 24.68 S 250.36 W 28.65 S 293.26 W 34.28 S 340.38 W 42.55 S 398.67 W 55.74 S 474.67 W 69.77 S 557.71 W 82.82 S 641.29 W 95.13 S 725.24 W 106.09 S 809.06 W 116.56 S 893.90 W 129.41 S 978.66 W 147.56 S 1059.81 W 2500 2938 39.44 2590 348 29 S 77.21 W 165.82 S 1139.95 W KRU 3G-23 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 11/26/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 2600 3068 39.79 2690 2700 3198 39.55 2790 2800 3328 39.55 2890 2900 3458 39.57 2990 3000 3587 39.50 3090 3100 3717 39.31 3190 3200 3846 39.20 3290 3300 3975 39.19 3390 3400 4104 39.11 3490 3500 4231 37.65 3590 3600 4357 37.25 3690 3700 4483 36.97 3790 3800 4608 36.75 3890 3900 4732 36.29 3990 4000 4856 36.38 4090 4100 4980 36.29 4190 4200 5104 36.63 4290 4300 5229 36.58 4390 4400 5353 36.12 4490 4500 5477 35.57 4590 4600 5599 35.52 4690 4700 5722 35.90 4790 4800 5847 37.19 4890 4900 5973 37.74 4990 5000 6100 37.99 5090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 378 30 S 77°46 W 183.93 S 1220.64 W 408 30 S 77.18 W 202.11 S 1301.79 W 438 30 S 77.52 W 220.29 S 1382.29 W 468 30 S 77.94 W 237.65 S 1463.14 W 497 30 S 78.26 W 254.80 S 1543.84 W 527 29 S 78.09 W 271.56 S 1624.27 W 556 29 S 77.83 W 288.70 S 1704.13 W 585 29 S 77.95 W 305.81 S 1783.85 W 614 29 S 78.02 W 322.80 S 1863.55 W 641 27 S 79.47 W 338.13 S 1940.92 W 667 26 S 79.74 W 351.66 S 2016.22 W 693 25 S 79.45 W 365.40 S 2090.63 W 718 25 S 79.33 W 379.22 S 2164.34 W 742 24 S 79.22 W 392.89 S 2237.00 W 766 24 S 80.03 W 406.61 S 2309.10 W 790 24 S 80.80 W 418.49 S 2381.90 W 814 24 S 81.91 W 429.68 S 2454.79 W 839 25 S 81.75 W 440.33 S 2528.33 W 863 24 S 83.10 W 450.41 S 2601.51 W 887 23 S 84.84 W 457.78 S 2673.20 W 909 23 S 85.32 W 463.82 S 2744.31 W 932 23 S 84.55 W 470.23 S 2815.64 W 957 25 S 84.22 W 477.35 S 2889.57 W 983 26 S 83.63 W 485.58 S 2966.01 W 1010 27 S 83.40 W 494.38 S 3043.25 W 5100 6227 38.03 5190 1037 27 S 83.49 W 503.31 S 3120.92 W ~RU 3G-23 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 11/26/90 ~UBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 6354 37.99 5290 5300 6481 38.03 5390 5400 6608 38.14 5490 5500 6735 38.03 5590 5600 6861 37.82 5690 5700 6988 37.81 5790 5800 7115 37.61 5890 5900 7240 37.32 5990 6000 7366 37.35 6090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1064 27 S 83.29 W 512.16 S 3198.58 W 1091 27 S 82.72 W 521.72 S 3276.12 W 1118 27 S 82.94 W 531.53 S 3353.86 W 1145 27 S 82.32 W 541.71 S 3431.80 W 1171 27 S 82.64 W 552.00 S 3508.65 W 1198 27 S 83.09 W 561.60 S 3585.81 W 1225 26 S 83.37 W 570.72 S 3662.63 W 1250 26 S 83.72 W 579.31 S 3738.62 W 1276 26 S 83.87 W 587.51 S 3814.48 W KRU 3G-23 Page 8 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL 11/26/90 MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES DEPTH ANGLE BKB SUB-S DIST BEARING 1000 17.23 992 902 91 S 79.76 W 2000 39.90 1873 1783 547 S 80.66 W 3000 39.56 2638 2548 1191 S 77.36 W 4000 39.19 3409 3319 1826 S 77.97 W 5000 36.23 4206 4116 2430 S 80.76 W CLOSURE DL/ FROM-WELLHEAD DIST BEARING 100 3 S 67 S 174 S 309 S 420 S 91 W 91 S 88.41 W 4.4 543 W 548 S 82.93 W 0.5 1178 W 1191 S 81.58 W 0.2 1799 W 1826 S 80.25 W 0.0 2393 W 2430 S 80.04 W 0.3 6000 37.79 5011 4921 3022 S 83.55 W 7000 37.80 5799 5709 3637 S 83.12 W 487 S 562 S 2982 W 3022 S 80.72 W 0.2 3593 W 3637 S 81.10 W 0.2 11/26/90 by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER UNIT Well ...... : KRU 3G-23 Section at: S,80.85,W Surveyor..: ROB SHOUP Computation...: RADIUS OF CURVATURE Survey Date...: 11/16/90 RKB Elevation.: 90.00 ft Job Number .... : AKl190G254 AP1 Number .... : 50-103-20144 INTERPOLATED MARKERS REPORT Surface Location' 2538 SNL 245 WEL S23 T12N R9E MARKER IDENTIFICATION KB RKB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" CASING PROJECTED TD MEAS INCLN DEPTH ANGLE VERT-DEPTHS SECT BKB SUB-S DIST 0 0.00 0 -90 35 0.08 35 -55 3684 39.36 3165 3075 7040 37.74 5831 5741 7040 37.74 5831 5741 7040 37.74 5831 5741 7170 37.41 5934 5844 7392 37.35 6111 6021 7420 37.35 6133 6043 DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 N 0.OOE ON 0E 0 N 85.47 W 0 N 0 W 1626 S 78.18 W 267 S 1604 W 3661 S 83.20 W 565 S 3617 W 3661 S 83.20 W 565 S 3617 W 3661 S 83.20 W 3741 S 83.53 W 3875 S 83.87 W 3892 S 83.87 W 565 S 3617 W 575 S 3696 W 589 S 3830 W 591 S 3847 W £pemt L,n6 Oire£tionel Drilling. Inc. <KB>O 400 [ ..... 8OO i200 1600 VERTICAL SECTION VIEW ARCO ALASKA, INC. KRU 36-23 Section at: S 80.85 W TVD Scale.' ! inch = 800 feet Bep Scale.' ! inch = 800 feet Drawn · !1/26/90 Harker Identification ~D TVD SECTN INCLN A) KB 0 0 0 0.00 B) PROJECTED TD 7420 6i33 3892 37.35 2000 2400 3200 3800 4000 4400 4800 5200 5600 I'--' .......... r .................. 6000 6400 680O 7200 400 0 400 800 i2oo t8oo 2000 2400 2800 3~oo 3600 4000 Section Departure 8naat Len~ Olns£tional Orilling. £n£. Harker Identification HO N/S KB 0 0 N 0 E PROJECTED TD 7420 5§! S 3847 H PLAN VIEW ARCO ALASKA, INC. KRU 3G-23 CLOSURE ..... : 3892 ft S 8~.27 DECLINATION.: 0.00 E SCALE ....... : t inch = 700 feet DRAWN ....... : 1~/26/90 350 " 0 ~v 350 700 ~050 i400 ~750 2i00 2450 3i50 3500 3850 4200 4550 3850 3500 3t50 2800 2450 2t00 t750 t400 t050 700 350 0 350 <- WEST ' EAST -> · ct~ecl~'~ff or li~ data' as it is 'received.*list received date for 407. if not uired'list as NR Cored intervals core anal,vsis ~/~ dry ditch intervals digital data - ' ' ' ,,.,-,-=,-,,,,~'i,-. SCALE " LOG T,~,nc-, ,r'L. " RUN NO. [to thc nearest foot] . [inchtl§0'] __u ~ 1, i ,,, i i, ARCO Alaska, Inc. Date: March 22, 1991 Transmittal #: 8040 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATe-1119 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 transmittal. ~1A-20 £xlA 20 '~I"A-1 7 ~3G-21 ~1L-21 ~L-21 Receipt Drilling 'Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Pulse Echo Cement Evaluation Log Acoustic Cement Bond Log Pulse Echo Cement Evaluation Log Cement Bond Log 1 -2-91 I -2-91 12-31-90 11-23-90 I 1 -1 5-90 3-13-91 Cement Evaluation Log ..d ~ ×/3 - 1 3 - 91 State of Alaska . 6421 -8926 5894-8927 5400-8435 8464-11508 4170-7268 9500-12269 9500-12269 RECEIVED 91 NSK Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date: March 8, 1991 RETURN TO: ARCO Alaska, Inc. ATTN: Maria Trevithick Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 8030 Transmitted here with are the following Items, Please acknowledge receipt and return one signed copy of this transmittal. 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 11-14-90 6603-9725 12-31-90 5400-8438 1 1-15-90 4200-7282 1 1-12-90 4100-6545 State of Alaska Alaska 0il & Gasl'~l~. C0mmissl.lin .... ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS,51~ 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, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 245' FEL, SEC 23,T12N,RgE,UM At top of productive interval 2150' Fnl, 1360' FWL, Sec. 23, T12N, R8E, UM At effective depth NA At total depth 2120"FNL, 1173' FWL, Sec. 23, T12, R8E, UM 5. Type of Well: Development Exploratory Stratigraphic Service (approx) (approx) 12. Present well condition summary Total Depth: measured 7420' feet (approx) true vertical 6137' feet Effective depth: measured NA feet (approx) true vertical NA feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3649' 9 5/8" Intermediate Production 7357' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None 6. Datum elevation (DF or KB) RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3(3-23 9. Permit number 90-132 10. APl number 50-1 03-20144 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) Junk (measured) Cemented 180 SX AS I 835 Sx AS III & 460Sx Class G 200Sx class G Measured depth True vertical depth 1 1 5' 115'approx. 3684' 3164'(approx) 7392' 6115' (approx) RECEIVED DEc - 4 1990 Alaska 0il & {las Cons. C0m~ts$[o[~ Anchorage 13. Attachments Description summary of proposal _ Detailed operation program X BOP sketch 14. Estimated date for commencing operation January, 1~)~)1 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil ;~ Gas m Service Suspended 17. I hereby certSfy that the foregoing is true and correct to the best of my knowledge. Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity m BOP Test~ Location clearance__ Mechanical Integrity Test m Subsequent form require IApprova_l No. ,.., . / Approved by the order of the Commission Commissioner Form 10-403 Rev 06/15/88 SUBMIT IN T~PLICATE Approvea Copy Re~urne~ ORIGINAL SIGNED BY LONNIE C. SMITH ~CO A~S~ ': J I NORTH S~PE ~ Field IL ..... Unit JW'li no. ~~ ~ ~L 25547 A~ 2661 3~-23 Auth. or W.O. ~o. ~?itle ~5181 ~ DRILLING Operator IARCO W.I- ARCO I 55.2521 Spudded orW.O, begUnsPT,TD ]Date 09/28/90 ;" ]Hour 13:00 [Prior status if a W.O. Date and depth aa of 8:00 a.m. 09/29/90 (1) TD= 1738'(1738) SUPV:JMM 09/30/90 (2) TD: 3705'(1967) SUPV:JMM 10/01/90 (3) TD: 3715'( 10) SUPV:JMM 10/02/90 TD: 5403'( SUPV:JMM/PDW 10/03/90 (5) TD: 7220'(1817) SUPV:JMM/PDW 10/04/90 (6) TD: 7420'{ 200) SUPV:JI,g~/PDW Complete record ~r each day DOYEN 14 NAVIDRLG 12.25 HOLE MW: 9.3 VIS: 61 MOVE RIG FROM 3G-18 TO 3G-23. CNTLV DRL OVER HOLE, N/U DIV LINES, FLOWLINE, S SUR STACK, RISER. P/U M/U BHA & ORIENT. TEST HYDRIL & DIV VALVES, CHECK FOR LEAKS. SPUD IN 3G-23 @ 115' NAVIDRIL 12.25 HOLE 115' TO 1517'. NAVIDRILL LOSING POWER; POOH TO CHANGE SAME. M/U NEW NAVIDRILL; ORIENT & RIH. NAVIDRLG 12.25 HOLE 1517' TO 1738'. DAILY:S70,332 CUM:$70,332 ETD:S70,332 EFC:$1,310,200 WASH & REAM TIGHT HOLE MW: 9.7 VIS: 49 NAVIDRLG 12.25 HOLE, 1738' TO 3705'. CIRC N COND HOLE. DROP SS SURVEY. PMP SLUG & POOH TIGHT @ 2000' TO 1600'. L/D TURBINE, P/U & M/U B/N HOLE OPENER. RIH TO 1637', TIGHT. WASH N REAM 1637' TO 1835'. DAILY:S54,810 CUM:$125,142 ETD:S125,142 EFC:$1,310,200 CMT TOP JOB ON 9.625" MW: 9.9 VIS: 45 UNABLE TO REAM @ 1835' INCREASE VIS N BUILD HI VIS PILL TO SWEEP HOLE. CIRC W/ INCREASED VIS MUD N PMP HI VIS SWEEP. UNABLE TO REAM PAST 1835' POOH. P/U NAVIDRILL NEW BIT, M/U BHA N ORIENT. RIH W/ NAVILDRILL . WASH & REAM WORK HOLE 1819 TO-~Q~2, RIH TO 2356'. WASH&REAM N WORK HOLE 2356' TO ~_~ii ~:~ BX @ 3705 NAVILDRILL 10' O~ NEW HOLE TO ~~::!:com~. POOH. L/O J~l~~cK ~T EOm'. L/D, N/D SURF. R/U TOP ~OB ~:~ COM=$272,020 ETD=S272,020 EFC=$1,310,200 ~~. ': MW: 9.5 VIS: 42 ~~;i'IiIP BOP STACK. R/U & TEST BOP & SURF EQUIP. SET WEAR RING.i CHANGE BHA, BRING BACK TURBINE. CALBR. ELL TOOL. RIH. SLIP & CUT DRLG LINE. TAG FL COLLAR ~ 3603', DRILL SHOE + 10' RUN FORMATION COMPETENCY TEST TO EM~ 12.2PPG CONT. DRGL. DAILY:S142,267 CUM:$414,287 ETD:S414,287 EFC:$1,310,200 DRILLING MW=10.6 VIS: 38 DRILLING 5403' TO 6731'.. PERFORM FORMATION COMPETENCY TEST TO 11.1 PPG EMW. DRILLING 6731' TO 7220'. DAILY:S65,237 CUM:$479,524 ETD:S479,524 EFC:$1,310,200 LAY DOWN DRILL PIPE 7"~ 7392' MW:10.8 VIS: 40 DRLG 7220' TO 7363'. WASHOUT IN DRILl,PIPE. POH 10 STDS LOCATE WASHOUT. RIH DRLG 7365' TO 7420'. CIRC~ DROP SURVEY, POH. STAND BACK BHA, DOWNLOAD ELL, BRK DOWN TURBINE. RIH. CIRC & COND FOR 7" CSG, SPOT 29 BBL DIESEL. POH, LAY DOWN D/P. DAILY:S58,247 CUM:$537,771 ETD:S537,771 EFC:$1,310,200 The above la ~ct /) {'ax AR3B-459-1-D DEC - 4 1990 JNumber all daily well history forms consecutively 0ii a Gas Cons. C0mmi$slo~' they ~re ,repl,d for each well. Anchorage jPage no. ComPany Dally Well History-Final Report Instructions: Prepare a~ ~.Wadnesdey after allowable has been assigned or well ia Plugged, Abandoned, or Sold. "Flnll RI~' ehould~~~~~nded for an indefinite or appreciable length of time. On workovere when In official test Is not required upon completl~ I~..~$t data in blocks provided. The"Finll l=l~ol't" form maybiuled for reporting the entire operation if space is aVal[l~lJtlll~IL~jJi~ ,..'~- · ~%'!: J'.~ccounting cost center code I ~(~f:!: '!:~ :~ JCounty or Psnsh is,at, District .j ~.~.. ':~*i' ~' I NORTH SLOPE Field ILease or Unit IWell no. KUPARUK I ADL 25547 A:M< 2661 3~;-23 Auth. or W.O. no. ITitle - AK5181 I DRILLTNG Operator I A.R.Co. W.I. ARCO JDate55.2521 Spudded or W.O. begun SPUD J 09/28/90 Date and depth as of 8:00 a.m. 10/05/90 (7) TD: 0'( SUPV:JMM/PDW o) Complete record for each day reported DOYON 14 Iotal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our IPrl°r status if a W.O. 13:00 RIG RELEASED @ 19:30 HRS 7"6 7392' MW: 0.0 VIS: 0 RUN 7" CASING, LAND W/ SHOE @ 7391' COLLAR @ 7345'. CIRC. TEST LINES AT 2500 MIX AND PUMP 10 BBLS PREFLUSH FOLLOWED BY 35 BBLS ARCO SPACER & 200 SX "G" CMT BUMP PLUG W/ 2500 PSI FLOATS HELD . CIP @ 1545. ND BOP SET SLIP ON 7",INSTL PACK OFF & TUBG SPOOL TEST TO 3000 PSI. DAILY:S161,941 CUM:$699,712 ETD:S699,712 EFC:$1,310,200 Alaska Oii& ( as Cons. Commission Anchorage Old TD JNewTO J PB Depth I I Classifications (oit, gas, otc.) I Type completion (single, dual, etc,) I Producing method JOfflclal reservoir name(s) I Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production ~11 on test Gas per day I~ump size, SPM X length Choke elze !T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above Is correct Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively aa they are prepared for each well. jPage no. Dlvllton of AtlantlcRIchfleldCm~y ARCO Alaska, Inc. Date: October 12, 1990 Transmittal #: 7920 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-23 LIS Tape and Listing Please acknowledge receipt and return 10-8-90 3687-7420 :~ z~---~ Receipt Acknowledged: Date: DISTRIBUTION: Lynn Goettinger State of Alaska RECEIVED OCT 1 5 1990 ARCO Alaska, Inc. Date: October 12, 1990 Transmittal #: 7918 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. 3 G - 23 Dual Gamma Ray Compensated 1 0 - 3 - 9 0 3 6 8 3 - 7 4 2 0 Neutron Porosity Simultaneous Formation Density 3G-23 Dual Gamma Ray Electrmagnetic 1 0-3-90 3683-7420 Wave Resistivity Formation Exposure Time Acknowledged' ~'~--~ Receipt Date' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) EC£1vED OCT ? 5 1990 llaska 011 & Gas Cons. Commission Anchorage TO: THRU: MEMORANL UM Sta e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION Lonnie C. Smi~ Commissioner DATE: FILE NO: October 3, 1990 JT.HH.103.1 TELEPHONE NO: SUBJECT: RIG/BOPE Inspection AAI KRU Well DS 3G-23 Kuparuk Rv Field FROM: Harold Hawkins Petroleum inspector Saturday sept. 29, 1990: I went to the Kuparuk Rv Field AAI KRU DS ~G223' t'5~d6 a 'RiG/BOPE Inspection on Doyon Rig 14. I inspected the rig throughout and found no infractions of the AOGCC regulations. The last BOP test was performed 9/24/90. The AAI co man was Jerry McCauley. The toolpusher was Jim Spaulding. In summary: The RIG/BOPE Inspection was satisfactorily performed. 02-00lA (Rev. 6/89) 20/ll/MEMO1.PM3 September 26, !990 Teleeopy: (q07)276-7542 A. Wayne McBride Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3G-23 ARCO Alaska, Inc. Permit No. 90-132 Sur. Loc. 2538'FNL, 245'FEL, Sec. 23, T12N, R9E, UM. Btmhole Loc. 2120'FSL, l173'FWL, Sec. 23, T12N, RSE, 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 authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, ".-Lonnie C. ~i S~i th Commissioner Alaska Oil and Gas Conservation Commission BY ORDER OF nE COMMiSSiON dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AI.A~, ,A OIL AND GAS CONSERVATION COMMIS,~JON PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill X Redrill _ ~ lb. Type of Well Exploratory~ 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. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface ~-~ ~-07 ~ ~'J~ 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 245' FEL, Sec. 23, T12N, ~..gE,)UM KuDaruk River Unit At top of productive interval (TARGET)~ 8. Well number Number 2150' FSL, 1360' FWL, Sec. 23, T12N, R8E, UM 3G-23 #U630610 At total depth 9. Approximate spud date Amount 2120' FSL, 1173' FWL, Sec 23, T12N, R8E, UM 01-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-20 7420' MD 1173' ~ TD feet 64' at 560 feet 2560 6137' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400' feet Maximum hole an~le 37° Maximum surface 1870 psig At totaldepth (TVD) 3415 psi~ @ 6137' 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casin~ Weight Grade Coupling! Length lVD TVD IVD TVD linclude sta~e dataI 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' +200 Cu. Ft. 12.25 9.625" 36.0# J-55 BTC 3630' 35' 35' 3665 3160' 1620 Cu. Ft. AS III & HF-ERW 530 Cu. Ft. Class G 8.5 7" 26.0#1J-55 AB-MCI 3775' 35' 35' 3810' 3275' 180Cu. Ft. ClassG 8.5 7" 26.0#IJ'55 BTC 3610' 3810' 3275 7420' 6137' 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 depth True Vertical depth Structural Conductor Surface cu.CU'Ft'Ft. REEEIVED Intermediate Production Liner S E P 2 0 1990 Perforation depth: measured Alaska. Oil & Gas Cons. C0m~[ss',tO~tl. . . true vertical 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ Diverter Sketch .~_ Drilling program ~ Drilling fluid program ~ Time vs depth pict ~ Refraction analysis _ Seabed report _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 Drilling Engineer Date l Commission Use Only ' ' ' Perm~N~mbe~ I APl number I Approval date 0C~/2~)/C~0 J See cover letter for ,~,~ 50-/~O ,~' "' 2..4:~ ~ ~ other requirements Conditions of approval Samples required __Y e s .~ N o Mud Icg required__ Ye s ,.~ N o Hydrogen sulfide measures__ Yes z~. N o Directional survey required ~'Yes __ N o Required working pressure for BOPE ~/~_2M; ~ 3 ;. __ 5M' __ 10M' __ I 5 M · by order of ?prov~e~, ~b~ ...... ~/~ Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate ARGO ALASKA, ]ne. Pad 3G. Wall No, 23 Propoeed Kuparuk Field. North Slope. Alaeke 0 .., RKB ELEYATION, go' t000_ 2000. 3000. 4000_ 5000_ 6000_ 7000., 0 KOP TVD=400 TMD=400 DEP=O 9 BUILD 3 DEC ! $ PER 100 FT 21 27' ;3 EOC TVD-1564 THD-1652 DEP-396 B/ PERHAFROST TVD-1605 Tt'ID=1703 DEP-427 T/ UGNU SNDS TVD-1760 Tt'ID=1899 DEP-546 T/ W SAK SNDS TVD=2470 THD=2795 OEP=lO92 B/ W SAK SNDS TVD=2960 TMD=3413 DEP=I469 9 5/8' CSG PT TVD=3160 THD=3665 DEP=1623 K-lO TVB=3300 THD=3842 DEP=1731 K-5 TVD=4600 THD=5482 DEP=2730 AVERAGE ANGLE 37 DEG 34 HI N TARGET - T/ ZONES C-A TVD=S890 THB=7109 DEP=3722 B/ KUP SNDS TVD=5978 THD=7220 DEP=3790 TD / LOG PT TVD=6137 THD=?420 DEP-3912 I I I 1000 2000 3000 VERTICAL SECTION I 4000 RECEIV£D S E P 2 0 1990 Alaska Oil & Gas Cons. Corn~ss't°tl Anchorage HORIZONTAL PROJECTION SCALE i IN. - 1000 FEET TAROET LOCATIONt 2l$0' FSL, 1360' FWL SEC. 23, TI2N, RSE TD LOCATIONt 2120' FSL, 1173' FWL SEC. 23, T I2N, RSE 2000 1000 1000 20OO ARCO ALASKA. [ne. Pad 30. Well No~ 23 Propoaed Kupaeuk Field, North Slope. Alaaica WEST-EAST 4000 3000 2000 1000 TARGET TVD-$890 TMO=?I09 OEP=3?22 SOUTH 592 WEST 3675 S 80 DE O 3722' (TO W T) \ SURFACE / 1000 ii SURFACE LOCATION' 2538' FNL, 245' FEL SEC. 23, TI2N, 9E :300 250 200 1 50 1 O0 50 0 50 ,,, I I I I I ,I I I 100 I 50 _ .,,, 100 _ 150 _ 200 . 250 _ --- --"3'4oo I I I I 1000 4200 I I 600 Joo 1 200 fi 'i '1 I ~ 1 ~00' I ! _ 5O _0 _ 100 _ 150 _ 200 250 300 250 200 150 100 50 0 50 100 DRILLING FLUID PROGRAM (3G-23) 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 15-40 4- 8 APl Filtrate 10-1 2 8- 10 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 Drillina 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: - 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 1870 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3G-23 will be 3G-20. As designed, the minimum distance between the two wells would be 64' at 560' (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. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 3G PAD o o So , J 6, , 8, . 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. /,,JPARUK RIVER UNI'~ 20" DIVERTER SCHEMATIC 5 6 I 5 4 3 2 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 TH E 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. 15" 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 2/6/90 .L ,J 7 '[ 5 4 ,,, J 13 5/8" 5000 t BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUMC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3(X)O PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RE~D THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER MMIT IS 45 SEC(]~DS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEl_ 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 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 PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3(X)O 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 NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PUM. OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND UNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3(X)0 PSi WITH KOOMEY PUMP, 13. RECORD TEST INFORMATION ON BLOWO~JT PREVENTER TEST FORM. SIGN AND SEND TO DRILENG SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2(X)0 PSI STARTING HEAD 2. 11' - 3(X)O PSI CASING HEAD 3. 11' - 3000 PSI X 13~/8' - 5000 PSI SPACER SPOOL 4. 13~5/8' - 5000 PSI PIPE RAMS 5. 13~5/8' - 5000 PSI DRLG SP(:X:)L W/ CHOKE AND KILL ENE$ 6. 13-5/8' - 5(X)0 PSI DO~JBLE RAM WI PIPE RAMS ON TOP, BUND RAMS ON BTM 7. 13-5/8' - 5(X)0 PSI ANNULAR SRE 8/22/89 DOYON 14 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (2) Loc <z 2 t/ ru 8 (8) '(~ ~hru i3) 10. /~, ~///. ~ - ~ / -~ ~ ~ ~ . (10 and 13) .... 12. 13. (14 thru 22) 14. 15. (23 thru 28) Company /~_.,.~ Lease & Well No. ' YES NO RE~S - Is the permit fee attached .......................................... -~ .... 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line ............... 4. Is well located proper distance from other wells ....... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ... 7. Is operator the only affected party ..................... 8. Can permit be approved before fifteen-day wait ......... Does operator have a bond in force .................................. /~ · Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... L Does the well have a unique name and number ......................... 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter 'system required ....................................... Is the drilling fluid program schematic and list of equipment adequate ~ ,, Are necessary diagrams and descriptions of diverter and BOPE attached. -~ ., · Does BOPE have sufficient pressure rating - Test to ~ooo psig .. /Z~ .,, Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. -~ (6) (29 thru 31) <6) Add: Geology: Eng ~n~eering: .cs, / rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. S HOP~E ., Additional Remarks: O ~Z Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file andto simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX~ .. No special 'effort has been made to chronologically organize this category of information. (NOTE: **** LIS READ **** MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SSDS DATE: 90/10/08 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: SSDS DATE: 90/10/08 ,ORIGIN OF DATA: 3G23 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** RECEIVED OCT ? 5 1990 %laska 011 & Gas Cons. Comrni~slon Anchorage ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 3G23.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/08 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** COMMENTS ** COMPANY: ARCO ALASKA INC.// WELL: 3G-23// API#: 50-103-20j~4// DATE: 3-OCT-90 LOCATION: 2538' FNL & 245' FEL, SEC. 23, TWP. 12N, RANGE_9<~, KUAPRUK FIELD, NORTH SLOPE BOROUGH, ALASKA, USA// RIG: DOYON 14// KB=90', DF=88.5', GL=53', LOG MEASURED FROM KB @ 90' AMSL// CO. REP.: PAUL WHITE// SSDS ENG.: KRELL// COMMENTS: DENSITY SENSOR FAILED AT 6923'. LOGS ARE NOT CALIPER CORRECTED DUE TO DENSITY FAILURE. NO TOOL WEAR COMPENSATION REQUIRED. ** 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 ORDER# DEPT EWR MWD FXE MWD NFO MWD NFl MWD NN0 MWD NN1 MWD NPS MWD RHOB MWD CAL MWD GRC MWD ROP MWD 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 HOUR 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 0 0 0 0 1 4 0 1 68 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 INCH 0 0 0 0 1 4 0 1 68 API 0 0 0 0 1 4 0 1 68 FT/H 0 0 0 0 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE 4 1 66 0 1 66 ENTRY 255 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 ORDER# LOG TYP CLS MOD NO. LVL CODE DEPT FT 0 0 0 0 1 4 0 1 68 EWR FXE NFO NFl NN0 NN1 NPS RHOB CAL GRC ROP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD OHMM HOUR P.U. G/C3 INCH API FT/H 68 68 68 68 68 68 68 68 68 68 68 ** DATA VERIFICATION (every 100 FT) ** DEPT EWR FXE NFO NFl NPS RHOB CAL GRC ROP NN0 NN1 3000.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3100.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3200.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3300.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3600.000 47.114 58.924 -999.250 449.000 2.680 8.820 62.432 408.000 -999.250 2360.000 2424.000 3700.000 4.333 1.282 475.250 47~.313 45.979 2.130 10.350 61.679 432.813 2331.500 2328.000 3800.000 4.396 .402 539.405 39.826 2.210 8.730 78.702 532.101 415.039 2467.595 2532.988 3900.000 3.812 .372 490.743 41.287 2.290 8.790 80.798 501.796 303.628 2439.165 2568.835 4000.000 40.586 3.558 .539 497.000 2.270 8.840 96.348 535.000 357.235 2488.000 2520.000 4100.000 39.242 3.492 .656 544.275 2.270 8.720 92.973 568.817 279.763 2473.083 2513.816 4200.000 3.667 .374 569.084 37.187 2.300 8.790 96.185 557.723 380.215 2534.385 2639.662 4300.000 36.561 3.011 .442 559.000 2.270 8.650 112.292 599.000 297.882 2632.000 2552.000 4400.000 35.104 3.479 .674 583.000 2.330 8.840 92.943 575.000 287.200 2696.000 2648.000 4500.000 35.093 3.256 .728 567.000 2.230 8.710 75.363 569.888 17~.408 2642.225 2744.000 4600.000 2.810 .757 543.000 37.538 2.530 8.480 97.727 559.000 188.549 2552.000 2632.000 4700.000 35.724 2.737 .709 599.000 2.650 8.420 110.098 583.000 214.867 2568.000 2664.000 4800.000 2.652 1.175 559.000 37.515 2.630 8.430 91.655 567.000 219.106 2584.000 2552.000 4900.000 34.311 2.615 .607 559.000 2.610 8.410 80.896 570.161 289.093 2769.483 2718.517 000.000 33.896 5100.000 33.725 5200.000 27.860 5300.000 36.197 5400.000 36.964 5500.000 35.987 5600.000 38.320 5700.000 31.358 5800.000 34.079 5900.000 33.739 6000.000 33.980 6100.000 33.611 6200.000 35.782 6300.000 36.042 6400.000 37.786 6500.000 36.922 6600.000 39.005 6700.000 37.317 6800.000 39.951 6900.000 44.045 7000.000 45.457 7100.000 33.148 7200.000 38.713 . . . . . . · . . . . . . . . . . · e · ® -999. · -999. . -999. 474 660 504 640 342 770 636 520 726 470 216 440 446 350 604 300 271 390 194 390 973 540 208 430 404 460 585 420 869 370 614 400 633 280 030 250 637 330 528 290 848 250 584 250 883 250 .887 8.440 .661 8.440 .509 8.430 .984 8.480 1.060 8.500 .440 8.570 .556 8.500 .729 8.610 .737 8.740 .536 8.700 .522 9.080 .543 8.780 .639 8.750 .622 8.600 .691 8.630 .941 8.830 .746 8.680 1.877 8.850 1.273 8.740 2.919 8.810 2.814 -999.250 2.004 -999.250 3.257 -999.250 661.913 148.003 607.000 110.209 767.000 154.818 663.000 147.793 664.543 149.122 543.000 107.381 519.000 101.586 623.000 97.891 623.000 94.613 615.000 92.289 579.892 86 690 591.000 94.940 543.000 102.730 559.000 102.157 543.000 122.383 535.000 114.659 561.745 119.772 676.511 175.770 597.109 149.800 509.004 99.862 502.000 113.126 597.796 71.284 544.051 89.916 603.346 271.205 583.000 219.210 727.000 215.074 647.000 193.359 639.188 215.074 623.000 269.575 599.000 296.266 615.000 302.930 583.000 196.701 615.000 253.502 599.595 249.609 623.000 254.255 575.000 238.008 551.000 236.316 551.000 233.789 615.000 171.177 529.980 156.063 682.094 215.769 591.873 122.344 514.106 40.382 510.000 19.470 586.843 110.878 555.713 29.135 2631.210 2680.000 2872.000 2520.000 2446.550 2712.000 2536.000 2776.000 2632.000 2648.000 2696.000 2728.000 2648.000 2712.000 2632.000 2616.000 2567.530 2447.396 2434.561 2371.559 2320.000 2776.878 2546.361 2661.827 2760.000 2808.000 2472.000 2478.550 2520.000 2536.000 2872.000 2744.000 2728.000 2742.541 2696.000 2712.000 2632.000 2552.000 2552.000 2488.000 2399.396 2396.701 2369.239 2312. 000 2809.616 2573.919 7300.000 2.772 5.023 533.188 518.696 2470.337 41.052 -999.250 -999.250 89.782 29.824 2503.607 7400.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 31.672 -999.250 7500.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** 429 DATA RECORDS ** FROM 3000.00 TO 7500.00 FT ** FILE TRAILER** FILE NAME: 3G23.MWD SERVICE NAME: SSDS VERSION #: V2.4 DATE: 90/10/08 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 2) ********** ** TAPE TRAILER** SERVICE NAME: SSDS DATE: 90/10/08 ORIGIN OF DATA: 3G23 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SSDS DATE: 90/10/08 ORIGIN OF DATA: FEWD REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** TAPE TERMINATED BY REEL TRAILER **********