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Home My WebLink About189-059MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-10 KUPARUK RIV UNIT 2K-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2K-10 50-103-20106-00-00 189-059-0 W SPT 5987 1890590 3000 2700 2700 2700 2700 800 1000 1015 1020 REQVAR P Guy Cook 6/11/2025 MIT-IA to maximum anticipated injection pressure per AIO 2B.017. Testing completed with a Little Red Services pump truck and calibrated gauges. This wells OA was bled from 1360 psi to 600 psi at 04:55 am on 6-11-25 prior to the MIT by the pad operator. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-10 Inspection Date: Tubing OA Packer Depth 1260 3460 3340 3330IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC250612075901 BBL Pumped:2.6 BBL Returned:2.4 Tuesday, July 22, 2025 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 27, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2K-10 KUPARUK RIV UNIT 2K-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/27/2023 2K-10 50-103-20106-00-00 189-059-0 W SPT 5987 1890590 3000 2725 2750 2750 2750 310 610 610 610 REQVAR P Kam StJohn 6/20/2023 MIT-IA to maximum anticipated injection pressure per AIO 2B.017 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2K-10 Inspection Date: Tubing OA Packer Depth 480 3490 3300 3260IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS230621141833 BBL Pumped:2.8 BBL Returned:2.7 Thursday, July 27, 2023 Page 1 of 1             MEMORANDUM TO: Jim Regg P.I. Supervisor `Zel 4, I Gln 1 FROM: Brian Bixby Petroleum Inspector NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 30, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-10 KUPARUK RIV UNIT 2K-10 Src: Inspector Reviewed By: P.I. Supry Comm Well Name KUPARUK RIV UNIT 2K-10 API Well Number 50-103-20106-00-00 Inspector Name: Brian Bixby Permit Number: 189-059-0 Inspection Date: 6/20/2021 ✓ Insp Num: mitBDB210623075542 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-10 Type Inj w TVD 5987 Tubing 2650 - 2650 _ 2600 , 2600 - PTD 1890590 Type Test SPT' Test psi 3000 IA 330 3450 - 3240 - 3210 BBL Pumped: 3.9 - BBL Returned: 3.7 OA 310 600. 600 - 600 Intervall REQVAR P/F P Notes: MITIA as per AIO 2B.017 Wednesday, June 30, 2021 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, June 26, 2019 P.I. Supervisor ' \ �Y I SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2K-10 FROM: Lou Laubenstein KUPARUKRIV UNIT 2K-10 Petroleum Inspector See: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-10 Insp Num: mitLOL190610170900 Rel Insp Num: API Well Number 50-103-20106-00-00 Inspector Name: Lou Laubenstein Permit Number: 189-059-0 Inspection Date: 6/8/2019 - Notes: MIT -IA to maximum anticipated injection pressure per AIO 2B.017 ✓ Pretest Initial I5 Min 30 Ylin 45 Min 60 Min X650 �e5o �e_o 1r0- -- 112£ 3300 3175 3150 470 - 670 690 - 700 Wednesday, June 26, 2019 Page 1 of I Packer Depth Well zK-10 'Type J ' T e In' w -'TVD — 5987 Tubing PTD 1890590 Type Testl SPT "Test psi 3000 -'I IA BBL Pumped: 2. ' ,BBL Returned z 5 OA Interval 1 REQVAR P/F P i Notes: MIT -IA to maximum anticipated injection pressure per AIO 2B.017 ✓ Pretest Initial I5 Min 30 Ylin 45 Min 60 Min X650 �e5o �e_o 1r0- -- 112£ 3300 3175 3150 470 - 670 690 - 700 Wednesday, June 26, 2019 Page 1 of I RECEIVED STATE OF ALASKA Al111A OIL AND GAS CONSERVATION COMMI SION DEC 0 6 2017 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ ' Other Stimulate N. Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ .erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Pr 6.1.0 91 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 189-059 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service ❑ 6.API Number: 99510 50-103-20106-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2K-10 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7,651 feet Plugs measured None feet true vertical 7,311 feet Junk measured None feet Effective Depth measured 6,724 feet Packer measured 6,326 feet true vertical 6,380 feet true vertical 5,987 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 115' MD 115 SURFACE 2,965 feet 9 5/8" 3,000' MD. 2934 PRODUCTION 6,772 feet 7 " 6,805' MD 6465 • Perforation depth Measured depth 6490-6500,6512-6547 feet True Vertical depth 6151 -6161,6173-6208 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 6,375' MD 6,035'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER HB RETRIEVABLE PACKER 6,326' MD 5,987'TVD SAFETY VLV-CAMCO TRDP-1A-SSA-(LOCKED OUT) 1,806'MD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A scoEU 0A,K 2 2.018 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 0 294 820 2570 Subsequent to operation: o 0 407 1028 2600 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory ❑ Development ❑ Service U Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL 0 Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG U 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: 317-141 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email:jason.burke©cop.com Authorized Title: Staff Wells Engineer / ) Contact Phone: (907)265-6097 Authorized Signatur= Date: vn //z/'g 4'0 Form 10-404 Revised 4/2017 Submit Original Only RBDV4�S /.----LC: 0 6 2017 • • 2 K- 10 DAD ACID STIMULATE DTTMST,JOBTYP SUMMARYOPS 11/24/17 ACID RIH TO 6587' RKB. CIRCULATE 28 BBL DAD ACID TO LOAD COIL. CLOSE CHOKE AND PUMP 100 BBL , TOTAL VOLUME, DAD ACID TO FORMATION MAKING CYCLE PASSES 6550' - 6480"AT PUMP RATE = 0.6 BPM, 3684 PSI, WHP =2389. DISPLACE COIL VOLUME WITH 3 BBL WATER+ 32 BBL SLICK DIESEL(COIL VOLUME+ 5 BBL OVER-DISPLACEMENT) CONTINUING CYCLE PASSES.. POOH. RIG DOWN. DSO RETURNS WELL TO INJECTION. MOVE TO 2K-25. SDFN. JOB COMPLETE. KUP 2K-10 ConocoPhillips ii. Well Attribut Max Angle!" TD Alaska,Inc, • Wellbore API/UWI Field Name Wellbore Status ncl C) MD(ftKB) Act Btm(ftKB) 0 ia)ps 501032010600 KUPARUK RIVER UNIT INJ 30.24 3,600.00 6,798.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date 2K-10,12/6/2017 9.11.09 AM SSSV:LOCKED OUT Last WO: 40.09 12/27/1989 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,706.0 7/24/2016 Rev Reason:TAG,SET/PULLED BOMB pproven 8/22/2016 HANGER W/GAUGES qr ', Casing Strings IB HANGER;311 _ 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 I I Casing Description OD(in) 'ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wt/Len(I...Grade Top Thread - SURFACE 9 5/8 8.921 35.0 3,000.4 2,934.6 36.00 J-55 BTC Casing Description OD(in) 4ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade 'Top Thread PRODUCTION 7 6.059 33.0 6,804.9 6,465.4 29.00 L-80 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection "`1" "a1"„an"TUBING 3 1/2 2.992 31.1 6,374.8 6,035.5 9.30 J-55 EUE8rdABMOD co NOUCTOR5 .441-,15,1,. ',36.0-110 F Completion Details/1i Nominal ID Top(ftKB) Top(WD)(ftKB) Top Incl C) Item Des Com (in) 31.1 31.1 0.01 HANGER FMC GENT IV TUBING HANGER 3.500 1,806.2 1,806.2 0.33 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE- 2.812 MALFUNTIONING(LOCKED OUT 7/6/09) SAFETY VLV,1606.2 '1 ?'F' 6,312.0 5,972.8. 2.15 PBR BAKER 80-40 PBR w/10'STROKE,4"SEAL BORE 3.000 6,325.7 5,986.5' 2.13 PACKER BAKER HB RETRIEVABLE PACKER 2.890 6,362.8 6,023.5 2.10 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 GAS LIFT,2,337.0 � 6,374.1 6,034.8 2.09 SOS BAKER SHEAR OUT,ELMD 6367'ON HES JEWELRY 2.992 ,, <, LOG 2/10/2010 Perforations&Slots Shot 3F` '1 Den • Top(TVD) Btm(WD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 6,490.0 6,500.0 6,150.7 6,160.7 A-5,2K-10 208/2010 6.0 APERF 2.5"Millenium HMX,60 deg.phase 6,512.0 6,547.0 6,172.7 6,207.7 A-4,2K-10 4/12/1990 4.0 IPERF 180 deg.Phasing;4.5" 0 Casing Guns SURFACE,35.0-3,000.4 . d I Mandrel Inserts x St li ati GMS LIFT;4,300,7 on Top(WD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1' 2,337.0 2,332.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 2 4,304.7 4,070.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 GAS LIFT;5,618.7IF 3 5,618.8 5,285.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 4 6270.1 5,930.9 CAMCO IMMG-2 1112 GAS LIFT DMY RK 0.000 0.0 5/15/1995 Notes:General&Safety End Date Annotation 5/31/2004 NOTE:WAIVERED WELL: IA x OA COMMUNICATION 7/6/2009 'NOTE:LEAKING BONNET RING REPLACED BY ASRC GAS LIFT;6,270.1 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR;6,3120 'III. PACKER;6,3257 NIPPLE;6,362.7. S05;6,374.0 APERF;6,490.06,500.0-.. (PERF;6,512.0-6,547.0 7 PRODUCTION;33.0-6,804.9 • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,June 28,2017 TO: Jim Rp �� P.I.Supervisor 7/7(i 7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA,INC. 2K-10 FROM: Chuck Scheve KUPARUK RIV UNIT 2K-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J2-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-10API Well Number 50-103-20106-00-00 Inspector Name: Chuck Scheve Permit Number: 189-059-0 Inspection Date: 6/24/2017 Insp Num: mitCS170625094050 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 2K-l0 Type Inj W TVD 5987 - Tubing 2550 2550 2550 - 2550 PTD 1 1890590 -Type Test SPT Test psi 3000 IA 1220 3400 - 3290 - 3250 - BBL Pumped: 2.5 ' BBL Returned: 2.5 OA 1200 1390. 1390 - 1390 Interval REQVAR IP/F P ,/ Notes: MITIA tested Per AIO 2B.017✓ SCANNED AUG 22T,; Wednesday,June 28,2017 Page 1 of 1 • SOF Tji� • y* y/,�s THE STATE Alaska Oil and Gas .4v 9� � TQ Conservation Commissi®n 0 ALl s jtrir 333 West Seventh Avenue T*',., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 (4'ALAS�� Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Wells Engineer scow AP1 9 �� ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-10 Permit to Drill Number: 189-059 Sundry Number: 317-141 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, /P20-4,7 - Cathy . Foerster Chair DATED this II y of April, 2017. RB®MS Lt, APR 1 2 2017 • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 6 2017 APPLICATION FOR SUNDRY APPROVALS Prs 4-/n 11 20 MC 25.280 AOGCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑✓ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Acid Stim ❑✓ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 189-059 y� 3.Address: 6.API Number: '�^ Stratigraphic ❑ Service 2t1 PO Box 100360,Anchorage AK 99510 50-103-20106 -Q-0(S 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 2 / KRU 2K-10 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588 Kuparuk River Unit/ Kuparuk River 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): 7651' . 7306' ` 6724' 6380' 4002 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 2965' 9-5/8" 3000' 2934' Intermediate Production 6772' 7" 6805' 6465' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6490'-6547' . 6151'-6208' 3.5" J-55 6375' Packers and SSSV Type: CAMCO TRDP-1A-SSA(LOCKED OUT) Packers and SSSV MD(ft)and ND(ft): 1806'MD&1806'TVD, Baker HB Retrievalbe Packer 6326'MD&5986'ND 12.Attachments: Proposal Summary Q Wellbore schematic D 13.Well Class after proposed work: Detailed Operations Program 2 BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑ • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/18/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG CI • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title Wells Engineer Signature - Phone 907-265-6097 Date fsia...„ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ .F4'9 C- Lit..irq Other: Post Initial Injection MIT Req'd? Yes ❑ NoD ` ��D17 Spacing Exception Required? Yes ❑ No 17. Subsequent Form Required: `Q '1.041 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:4..._//_/7 TL l� Submit Form and Form 10 403 Re ise 11/201 /�Approf 6pl+N0A and for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. Drilling& Wells ConocoMilhhps Well Intervention Alaska 2K-10 DAD 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 F103. 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 try to restore infectivity • Coiled Tubing: Spot DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, circulating at minimum rate until 6550' 3. Begin pumping DAD treatment. When treatment is 5 bbls from exiting the CT (depending on CT volume) shut in the backside choke and begin squeezing into formation. Chase the DAD treatment with produced water or diesel. a. Do not exceed 4500 psi surface pressure 4. As treatment is exiting begin POOH at 2 fpm up to 6480'. 5. RIH at 2 fpm back down to 6550' MD, and then begin POOH at 2 fpm until all the treatment is pumped. 6. After an additional 5 bbl of fluid has been injected behind the treatment POOH 7. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal April 5, 2017 2K-10 Well Work Procedure Page 1 of 1 • KUP INJ • 2K-10 ConocoPhillips i° Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Blot(ftKB) ,,„„,r.,;Praga, 501032010600 KUPARUK RIVER UNIT INJ 30.24 3.600.00 6,798.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-10,8/22/2016500:28 PM SSSV:LOCKED OUT Last WO 40.09 12/27/1989 Vertical schematic(actual) Annotation Depth(ORB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,706.0 7/24/2016 Rev Reason:TAG,SET/PULLED BOMB pproven 8/22/2016 HANGER W/GAUGES Casing Strings HANGER;31.1 I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread �o; CONDUCTOR 16 15.062 36.0 115.0 115.0 62.50 H-40 WELDED 1 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 35.0 3,000.4 2,934.6 36.00 J-55 BTC il Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.059 33.0 6,804.9 6,465.4 29.00 L-80 BTC Tubing Strings Tubing Description I String Ma...I ID(in) (Top(hKB) (Set Depth(ft..{Set Depth(ND)(...I Wt(Ib/fl) (Grade ITop Connection laawtaai. "" 'a1°'TUBING 3 11211 2.992 31.1 6,374.6 6,035.5 9.30 J-55 EUE8rdABMOD Completion Details .M/CONDUCTOR;38.0-115.0.4AlMN' Nominal ID Top(MKB) Top(ND)(ftKB) Top Incl 1°) Item Des Com (in) 31.1 31.1 0.01 HANGER FMC GENT IV TUBING HANGER 3.500 • 1,806.2 1,806.2 0.33 SAFETY VLV CAMCO TRDP-1A-SSA SAFETY VALVE- 2.812 • MALFUNTIONING(LOCKED OUT 7/6/09) SAFETY VLV;1,806.2 erl 6,312.0 5,972.8 2.15 PBR BAKER 80-40 PBR w/10'STROKE,4"SEAL BORE 3.000 I 6,325.7 5,986.5 2.13 PACKER ,BAKER HB RETRIEVABLE PACKER 2.890 6,362.8 6,023.5 2.10 NIPPLE OTIS 2.813"XN NIPPLE w/2.75"NO GO 2.750 6,374.1 6,034.8 2.09 SOS BAKER SHEAR OUT,ELMD 6367'ON HES JEWELRY 2.992 GAS LIFT;2,337.0 LOG 2/10/2010 Perforations&Slots • Shot Dens Top(ND) Btm(TVD) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date 9 Type Com • 6,490.0 6,500.0 6,150.7 6,160.7 A-5,2K-10 2/18/2010 6.0 APERF 2.5"Millenium HMX,60 deg.phase 6,512.0 6,547.0 6,172.7 6,207.7 A-4,2K-10 4/12/1990 4.0 (PERF 180 deg.Phasing;4.5" Casing Guns SURFACE:35.0-3,000.4-• 4Mandrel Inserts St on GAS LIFT;4,300.7 N Top(ND) Valva Latch Port Size TRO Run Top(810) (ftKB) Make Model OD(in) Sere Type Type (in) (psi) Run Date Com -I 2,337.0 2,332.3 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 2 4,304.7 4,070.0 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 3 5,618.8 5,285.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 5/16/1995 GAS LIFT;5,610.7 4 6,270.1 5,930.9-CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 5/15/1995 Notes:General&Safety End Date Annotation 5/31/2004 NOTE:WAIVERED WELL:IA x OA COMMUNICATION I 7/6/2009 NOTE:LEAKING BONNET RING REPLACED BY ASRC 11/2/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;6,270.1 PBR;6,312.0 •=a• • PACKER;6,325.7 II.• • NIPPLE;6.362.7 I SOS:6,374.0 APERF;8,490.0-6,500.0 --to mts- IPERF;6,512.0-8,547.0 se ma- PRODUCTION;33.0-6,604.9 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,June 02,2015 TO: Jim Regg � �I15'I S P.I.Supervisor r SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-10 FROM: Lou Grimaldi KUPARUK RIV UNIT 2K-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J�Z NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2K-10API Well Number 50-103-20106-00-00 Inspector Name: Lou Grimaldi Permit Number: 189-059-0 Inspection Date: 5/29/2015 Insp Num: mitLG150529141730 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2K-10 Type Inj W' TVD 5987 Tubing 1900 1900 1900 1900- PTD 1 1890590 • Type Test SPT Test psi 3360 IA 1000 3500- 3430 3410 - Interval IREQVAR IPF P ✓ OA 1063 1148 - 1160- 1162 Notes: Test required by AA-2B.017 Bled Gas from IA until fluid to surface Good test All required paperwork supplied prior to test. 2.0satallE,U Tuesday,June 02,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /'"(~~ File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED f various kinds [] Other Complete COMMENTS: Scanned by: Bevedy Bren(~~ Nathan Lowell [] TO RE-SCAN Re-Scanned by: Bevedy Bren Vincent Nathan Lowell Date: Is~ NOTScanned.wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: !'i)rt ()5f FILE # / f)41q fJr:ec\u/r~q "--.J To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ;333 W. 7th Ave., Ste. 100 ~ Anchorage, Alaska 99501 Voice (907) 279-1433 ¡Fax (907) 276-7542 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 14, 2011 TO: Jim Regg ') P.I. Supervisor 1 V t 1 42 1 k SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -10 FROM: John Crisp KUPARUK RIV UNIT 2K -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ` jam NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K - 10 API Well Number: 50 103 - 20106 - 00 - 00 Inspector Name: John Crisp Insp Num: miLICr110627154131 Permit Number: 189 - 059 - Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -10 ' Type Inj. I W TVD 5987 ' IA 960 1000 1020 1020 P.T.D 1890590 ' TypeTest SPT Test psi 1500 , OA 960 1810 - 1750 1740 -- Interval °TAR P/F P Tubing 2600 2600 2600 1 2600 1 Notes: MIT OA performed by CPAI that is not required by AA; no corresponding operator report. Told the Operator if they were going to PT the OA I wanted to witness. .3 bbls pumped for test. Thursday, July 14, 2011 Page 1 of 1 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) P I Scl— 01 Sent: Wednesday, July 13, 2011 11:48 AM ` ?' I3i� atk 2 K - 1 To: 'NSK Problem Well Supv'; DOA AOGCC Prudhoe Bay Subject: RE: 2K test pressure question Thank you; just a precaution to be careful with the use of "generic max anticipated injection pressure "; be certain it complies with our conditions of approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 ob +RI �� K i? 2O From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, July 12, 2011 7:29 PM To: DOA AOGCC Prudhoe Bay Subject: 2K test pressure question Hi John, So I tracked down Brent and asked about where the 3600psi on the 2K MITIAs came from. So apparently we like using 3000psi as a generic max anticipated injection pressure, and so 1.2x3000 = 3600. We like using 3000psi because it is usually the highest that water injectors will see. Even though 2K is typically 2800psi, there's a potential for it to go higher and so we want to be within compliance at all times. Give me a call if you want to discuss further Kelly Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 7/13/2011 • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) `"Reil littirr Kr Lit ZK —tL7 ___........ Sent: Monday, July 11, 2011 4:19 PM J9- OS`j To: NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA) Subject: RE: CPAI State Witnessed MITIAs - KRU 2K -03: AIO 2B.16 requires MIT to 1.2 times max anticipated injection pressure; most recent 90day TIO plot provided to Commission in monthly injection waiver report shows max injection pressure just shy of 2800psi (req'd test if this is anticipated max would be approximately 3360psi); unclear why report shows required test pressure of 3600psi w/o a matching test to that pressure - KRU 2K -10: AIO 2B.17 requires MIT to 1.2 times max anticipated injection pressure; most recent 90day TIO plot provided to Commission in monthly injection waiver report shows max injection pressure just shy of 2800psi (req'd test if this is anticipated max would be approximately 3360psi); unclear why report shows required test pressure of 3600psi w/o a matching test to that pressure - KRU 2Z -23: well name should be 2Z -23A Jim Regg AOGCC '�}} 333 W.7th Avenue, Suite 100 J W L U11r Anchorage, AK 99501 4 + � 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Sunday, June 26, 2011 1:26 PM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv Subject: CPAI State Witnessed MITIAs All, Attached for your records are the MIT forms for tests performed on Kuparuk Drillsites 2K and 2Z on 06/24/11 as witnessed by John Crisp. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907 - 943 -1720 / 1999 Pager 907 - 659 -7000 #909 7/12/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 28, 2011 TO: Jim Regg P.1. Supervisor e � ( 7 7 it SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K -10 FROM: John Crisp KUPARUK RIV UNIT 2K -10 Petroleum Inspector Src: Inspector Reviewed B P.I. Supry NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 2K -10 API Well Number: 50 -103- 20106 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr1 1 0628 1 1 0533 Permit Number: 189 -059 -0 Inspection Date: 6/24/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K -10 ' Type Inj. W ' TVD 5987 ' IA 1080 3500 • 3340 3330 - P.T.D 1890590 TypeTest SPT Test psi 1500 ' OA 980 1200 1190 1190 Interval REQvAR P/F P Tubing 2600 2600 2600 2600 Notes: 2.8 bbls pumped for test. MITIA as per AIO 2B.017 ' Tuesday, June 28, 2011 Page 1 of 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Thursday, June 02, 2011 5:16 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA) Subject: RE: Request permission for delay in testing 2K while SI Delaying MITs on 2K -03 and 2K -10 is acceptable. Commission preference is to do MITs while on injection; hopefully water supply to 2K pad can be restored as anticipated. Delaying the 2 MITs to be done in conjunction with the 4 -year pad test will allow for more efficient use of Commission Inspection resources. Also in support of this delay is the monthly TIO pressure data provided to the Commission for 2K -03 and 2K -10 as required in the admin approval; there have been no anomalous pressure trends identified. Please remember that the MIT anniversary date is set in those admin approvals and will not be adjusted by delaying these MITs. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 k M O" 1U % }, • Anc AK 99501 '' 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Thursday, June 02, 2011 4:58 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: Request permission for delay in testing 2K while SI Jim, As per our phone discussion, currently there is no water injection out to 2K pad and there are 2 rigs on the pad as well. The pad is due for its 4 year witnessed MITIA's this month. There are also two wells, 2K -03 (PTD 188 -120) and 2K-10 (189 -059) that were due for their AA compliance testing on 06/01/11. Both of those wells have been SI since 12/04/10. Water injection is tentatively planned to be restored to the pad this month. ConocoPhillips is requesting permission to perform the AA compliance testing and the pad testing once water injection has been restored to the pad. Please let me know if you have any questions. Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 6/16/2011 STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS.N RFpinRT 117E suNDRY WELL OPERATIONS 1. Operations Performed: Abandon ~ Repair w ell Plug Perforations Stimulate ~ Other ]'""` Alter Casing j°° Pull Tubing ~"" Perforate New Pbol '~"'; Waiver ~"` Time Extension Change Approved Rogram ~'"` Operat. Shutdown ", Perforate ~, Re-enter Suspended Well 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: Inc s Alaska Philli C Development "°°` Exploratory ~' 189-059 . , p onoco 3. Address: Stratigraphic ~'"' Service .API Number: 50-103-20106-00 P. O. Box 100360, Anchorage, Alaska 99510 7. Property Designation: ~ Well Name and Number: 10 2K ADL 25588 - 9. Field/Pool(s): Kuparuk River Field /Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured ~ 7651 feet Plugs (measured) None true vertical ~ 7311 feet Junk (measured) None Effective Depth measured 6724 feet Packer (measured) 6326 true vertical 6380 feet (true vertucal) 5987 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 115 115 ` ` SURFACE 3000 9.625 3000 2934 , / ~~~~ ~ 1~ PRODUCTION 6790 7 6790 6451 MAR 0 9 2010 ~~•~ Perforation depth: Measured depth: 6490'-65 0', 6512'-6547' True Vertical Depth: 6151'-6161', 6173'-6208' ~~ip~ „~+$. } (~ ,J {p ~ Tubing (size, grade, MD, and TVD) 3.5, J-55, 6375 MD, 6036 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER'HB' RETR. 6326 and 5987 TVD CAMCO TRDP-1A-SSA @ 1806 MD and 1806 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12 Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 948 Subsequent to operation 845 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory j Development Service .Well Status after work: Oil ~ Gas ~ WDSPL ~ S ~ ~ (~ Daily Report of Well Operations XXX GSTOR WAG'S` GASINJ WINJ ~` SPLUG 16. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none contact John Peirce Cad 265-6471 Printed Name John Peirce Title Wells Engineer Signature i,~ f ~ Phone: 265-6471 Date ~„ ~ .,, ~ O BDMS MAR d 9 ~~ ~~ Form 10-404 Revised 7/2009 _Q, 3•ll•!v Submit Olaginal Only ,.r' ~~ ,~n~ ,~ 2K-10 Well Events Summary " Date SUMMARY • 2/14/10 TAGGED @ 6708' SLM, DRIFTED / 10' 2.5" DUMMY GUN TO 6708' SLM. 2/18/10 PERFORATED 6490'-6500' WITH 2.5" MILLENNIUM HMX CHARGES, 6 SPF, 60 DEGREE PHASING. PERFORM HALF HOUR STOP CHECKS AT 6495' = 5271 PSI & 101 DEGF / 6394' = 5223 PSI & 96 DEGF r W ~ ~ts~. 41r.. CONDUCTOR, 115 SAFETY VLV, ~ 806 GAS UFT, 2,337 SURFACE,_ 3.000 GAS LIFT, 4,305 GAS LIFT, - 5.619 GAS LIFT, 6,270 PBR, 6,312- -- PAKCER, VI??L, 6.363 - SOS. 6,3]4 - TTL 6,375 -- APERF, 6.490-6.500 IPERF, __ _. 6.512-6.547 PRODUCTION, 6,]90 TD, 6.798 K UP ~ 2K-10 'Well Attributes ,Max Angle & MD TD I . Wellborn APWWI Fieltl Name _ _ MD (ftKB) Act Btm (ftK81 Well Statu 'Intl (°) 501032010600 I KUPARUK P:I/EF?UNIT INJ 30.24 3,600.00 6,798.0 Comment Rig Release Date Date Annotation iEnd Date KB-Grd (ft) ~H2.S ±ppml _ SSSV: LOCKED OUT ( I Last WO: 40.09 12/27/1989_ _ Annotation De i h ftKB End Date A ) End Date Last Mod By nnotation Last Tag: SLM I 6 I I 2/ I4f ~'(i lfl Rev Reason: 1 AG, ADD PERFS ~ Imosbor 2/20/2070 ,708.0 Casin Strin s - - -- -- _- _- T St q OD Str eg ID ~ Set Dep[h Set Depth (ND) String Wf String ', Casing Descr ption li~l (m) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade Siring TOp Thrd CONDUCTOR I 16~ I!i i167 35.0 115.0 115.0 62.50 H-00 SURFACE 9518 8.;'fS 0.0 3,000.0 2,934.31 36.00 J-55 .W.? PRODUCiION / (i 0`73 00 8,790.0 6,450.5 ~~ 29001 L-80 Tubing Strings . String OD tiering 10 Tubing D scription i lint 1 m Set Depth Set Depth (TV D) String Wt String Top (ftKB) (ftKB) (ftKB) (Ibs/ft) Grade String Top Thrd TUBING ,~ I. 31/21 .:+2 EUESrrJABMOD 9.30J SS 0.0 6,375.1 - Other In Hole (A ll Jewelry: Tubing __ Run & Retrievable Fish etc.) Top Depth' - , , -~- (TVD) Top Intl ToP (ftKB) (ftKB) ~ (°I De ~rrip tion Comment Run Date ID (in 1,806 1,806 O I 0.50 _ SAFE: 11' VL :1 Camco TRDP-IA-SSA (Note: Malfunctioning) LOCKED 4/11/1990 2.81 OUT 7/612009 2,337 2,332.3 15.86 GAS I-IFT MERWTMPD/1lDMYlBK//1 Comment: STA 1 5/16/1995 2.87 4,305 4,070.4 ~'~ 27.44 GAS LIFT MERWTMPD/1/DMY/BK//1 Comment STA2 5/1611995 2.87 5 B79 5,285.4 9.60 GAS LIF7 MERWTMPD/1/DMYlBK//I Comment: STA 3 5/16!1995 2.87 6 270 5,930.8 2.19 GAS L.IFI CAMCO/MMG-2/1.5/DMYlRK/// Comment STA4 5115/1995 2.92 6,312 5,972.8 2.15 PBR Baker'80-00' w/ 10' Stroke 4/11!1990 3.00 6,326 5,986.5 2.13 PAKCER Baker'HB' Retr. 4/11/1990 2.89 6,363 6,023.8 2.10~ NIPPLE _ __ __- Otis'XN'Nipple NO GO 4/11/1990 2.75 fi,374 6.0348 209' SOS ___ Baker 4/11/1990 : 2.99 6.375 6,035.8 2.09 TTL 4/11/1990 2.99 Perfora tions & Slots I Shot I Top (TVD) Btm {TVDI Dens Top (ft KBJ II Btm (ftKB) (ftKB) IftlC 6j Zone Date (sh-- Type Comment 6,4901 f 500 6, 150.7 i%16GJ A-5, 2K-10 2/18/2010 6 0 APERF 25" Millenium HMX, 60 tleg. phase 6.512', 6.547 6-l 727 _.:?d ;' % A-4, 2K-10 4/72/1990 40 IPERF x,180 deg_ Phasing; 45"Casing Guns Notes: General 8 Safety _ _ End Date I ~ Annotation !NOIE~WAIVERI:_II1~IId1:: L.L: 5131/2004 IAxOA COMMUNICATION 716/2009 NOT E: LEAKING I;iJ^1fJET RING REPLACED BY ASRC WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record /Shut-in Bottom Hole Pressure: 2K-10 Run Date: 2/18/2010 February 20, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-10 Digital Data in LAS format, Digital Log Image file 50-103-20106-00 ~~...~ 1~'- as9' ~ ~l ~~- 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax:907-273-3~3-~: ~ _ rafael.barreto~a h~lIiburt9n.com ; _ _, _ i J . ~ . ! ~'~ ~ ®~ Date: Signed: MEMORANDUM To: Jim Regg ~ l ~~ ~(I ~ )~,.~ P.I. Supervisor ~ 1 "t FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE; Monday, June 08, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-10 KUPARUK RIV UNIT 2K-] 0 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RN UNIT 2K-10 API Well Number: 50-103-20106-00-00 Inspector Name: John Crisp Insp Num: mitJCr090602153811 Permit Number: 189-059-0 Inspection Date: 5/28/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well zxao 1TypeInj~ ~ TVD s9s~ 'CIA 9~s ~ Iooo ~ Iolo_ Io2o _I_ D Ia9os9o iT si ~ Isoo~OA Iooo ~ Islo I~~o Ipso eTestrtsP I T P Test yp _ . . p Interval Ri:.QvAR p/F P ~ Tubing i zsoo zsoo _zsoo i zsoo __~ Notes• 2 yeaz test..3 BBL's pumped for test. Monday, June 08, 2009 Page 1 of 1 MEMORANDUM TO: Jim Regg ~~ ~~ ~l~-(v P.I. Supervisor ~~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, June 08, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-10 KUPARUK RI V UNIT 2K-] 0 Src: Inspector NON-CONFIDENTIAL Reviewed Bye P.I. Suprv ~~~ Comm Well Name: KUPARUK RIV UNIT 2K-10 API Well Number: 50-]03-20106-00-00 Inspector Name: John Crisp Insp Num: mitJCr090602153505 Permit Number: 189-059-0 Inspection Date: 5/28/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. WCII 2K-]0 Type Inj. W TVD s987 IA 1040 3000 ~ 2970 2985 P.T.D 1890s90 TypeTest SPT TCSt pSl 3000 OA 1000 1180 1210 1235 Interval oT~R p/F, P Tubing ~ zsoo zsoo zsoo ~soo Notes: AIO 2B.017 4.8 BBL's pumped for test. Monday, June 08, 2009 Page 1 of 1 Re , James B DOA 99 t ) From: NSK Problem Well Supv (n1617@conocophitlips.com] Sent: Wednesday, October 17, 2007 4:57 AM , To: Regg, James B (DOA) ~'"' ~ ~~~ ~ 1 ~ ~ Subject: Emailing: MIT KRU 2K-10 08-05-07.x1s ~~L• ~~~~~ Attachments: MIT KRU 2K-10 08-05-07.x1s ,~ MIT KRU 2K-10 OS-05-07.x1s (22... «MIT KRU 2K-10 08-05-07.x1s» Jim, Enclosed is the requested MITOA for 2K-10 PTD # 189-059, produced water injector. Let me know if you have any questions Perry Klein Problem GVell Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com ~~~~~ uc~ ~ ~ zoos 1 ` Regg, James B (DOA) • From: Regg, James B (DOA} Sent: Tuesday, October 16, 2007 3:32 PM To: 'NSK Problem We11 Supv' Subject: KRU 2K Admin Approval Requests Please send MITOAs for following: 2K-03 (PTD 188-120): MITOA dated 5/10/2007 2K-10 (PTD 189-059); MfTOA dated 8/5/2007 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 .~ ~' • :..^, `~ U ,~ l/ ~ ~I_~.,i.:~1 3~ ~ 1 J IJ'V%W C'dy-Lfi' (.-+~4I< L-' V6f,~., ff // , - ~~ ~ ~r`~ C`.~ i - ~~~(~~ ~ raj, rr ~ l 10/17/2007 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UN17 /PAD DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. K~aruk/ KRU 12K-10 asros/o7 _ _ ___ Rogers \~?E~~i ~ t~ Packer Depth Pretest Initial 15 Min. 30 Min. Well 2K-10 Ty e inj. W TVD 5,987' Tubing 2500 2500 2500 2500 Interval p P.T.D. 1890590 Ty etest P Test psi 1500 Casing 1250 1250 1250 1250 P/F P Notes: MITOA -not state witnesed OA 1210 1800 1760 1750 WeII Type Inj. TVD Tubin Interval P.T.D. Ty e test Test psi Casin P/F Notes: OA Well T e Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P!F Notes: OA Well Type In . TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well T pe Inj. TVD Tubing Interval P.T.D. Ty e test Test psi Gasing P!F Notes: OA D =Drilling Waste M =Annulus Monitoring G =Gas P =Standard Pressure Test I =Industrial Wastewater R =Internal Radioactive Tracer Survey N =Not Injecting A =Temperature Anomaly Survey W =Water D =Differentia{ Temperature Test J ,. i = wnai i est 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 911705 2007-0805_MIT_KRU_2K-10.x1s MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor l<æ(f "I {,I ù 7 DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2K-IO KUPARUK RIV UNIT 2K-10 Src: Inspector ósq \~a.; Reviewed By: P.I. Suprv 1)12-- Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-1O API Well Number: 50-103-20106-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070601183849 Permit Number: 189-059-0 Inspection Date: 6/112007 ;/' Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-10 Type Inj. w TVD 5987 IA 1200 3040 2990 2980 ¡ P.T.D 1890590 TypeTest SPT Test psi 1500 OA 1240 1400 1400 1400 I Interval OTHER P/F P ",,/ Tubing 2500 2500 2500 2500 i I Notes: Well is waivered for slow IA x OA communication. No communication noted during the 30 minute pressure test. A slow flange leak between the tubing spool and casing head developed near the end of the test period. An attempt to tighten this flange was under way when I departed location. eJeH s h!ti~ Ö^ r~~lÀI"I! c.<d.J... %'ef£eci , \ e,tltL i +v ()peJ¡~ l^ b 14 { D r cÞA1: re5P~~ b/.:;fol ¡/ ()e.Q ~ k & ~J wi Mg,..1 !1ppti)vkd¿ ]:A--;coA-- Q;"'1I\ÞlUv(¡úï.:k~ SCANNED JUN 2 0 2007 Wednesday, June 06, 2007 Page I of I Re: 2K -10 and Other Injector reporting Page 1 of • • Maunder, Thomas E (DOA) From: NSK Well Integrity Proj [N1878 @conocophillips.com] Sent: Thursday, June 07, 2007 4:05 PM To: jim_regg @admin.state.ak.us; Thomas Maunder Cc: NSK Problem Well Supv; Cawvey, Von; CPA Wells Supt; NSK Well Integrity Proj Subject: Re: 2K -10 and Other Injector reporting Attachments: CPAI Waivered injectors.xis ,.;. ti r Jim, The attached list discloses all of the active CPAI injection wells that have internal waivers. The purpose of the internal waiver program is to provide a systematic diagnostic approach to provide additional surveillance for wells that have been determined to be safe to operate however, may not conform to the well operating guidelines. Waivered injection wells receive additional scrutiny over any normal operating well including daily monitoring and an increased schedule of barrier compliance testing that ensures a minimum of two layers of protection between the formation and the surface. CPAI has historically endeavored to report all rapid TxIA or failing MIT -IA data to the Commission with in the required 24 hour period. CPAI has not traditionally deemed it necessary to report minor communication issues on wells that do not fail mechanical integrity tests. At the AOGCC's request, for commission work -load management prior to October 8, 2003, CPAI had a verbal agreement with the Commission to only report fast tracking or failed MITIA data and manage minor communication internally. During a meeting between the Commission and CPAI on October 8, 2003, CPAI gave a paper copy of all of the waivered injection well documentation to the Commission. However, since the main purpose of that meeting was sustained casing pressure on producers, the only injection reporting criteria discussed was that it needed to be discussed at a later date. Since then there have been several phone conversations and a few meetings that eventually directed us back to the specific language in the regulation "Whenever operating pressure observances or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must notify the Commission on the first working day following the observation, obtain Commission approval of a plan for corrective action, and when an USDW is not endangered, obtain Commission approval to continue injection," which means until administrative relief can be given, the notification and administrative approval (AA) of minor suspect communication is required. On June 4, 2006 CPAI applied for a blanket Administrative Relief request that would clarify and more clearly define reporting standards based on the type of annular communication present. CPAI has not yet received the AOGCC response to the relief request. In the mean time, between Oct 8, 2003 and now, the reporting of minor IAxOA communication on three wells: 2K -10 (189 -059), 1C -10 (182 -193), and 2V -02 (183 -161) was not done. Pending further discussion, AA requests can be initiated on those wells as required. All other wells on the list have been reported no later than the date listed in column F. Please note that the wells at the top of the list also have AOGCC AA's or 10-403 Sundry approvals to operate and there are 4 wells on the list that have been repaired with Seal -tite that remain waivered to increase operator attention and scrutiny. Except for some of the wells which also have an accompanying Sundry or AA, all the wells on the list passed a MIT -IA during the last scheduled test. CPAI looks forward to working with the AOGCC to more clearly define and clarify the intent of the regulation. Please reply back with questions or if any additional information is needed. Regards MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. 6/16/2011 Q c.9) Re: 2K -10 and Other Injector reporting Page 2 of 1 I • • Desk Phone (907) 659 -7043 Cell Phone (907) 448 -3114 «CPAI Waivered injectors.xls» From: NSK Problem Well Supv Sent: Tuesday, June 05, 2007 9:35 AM To: NSK Well Integrity Proj Subject: FW: Emailing: MIT KRU 2K 06- 01- 07.xls From: James Regg [mailto:jim_regg @admin.state.ak.us] Sent: Tuesday, June 05, 2007 9:30 AM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: Emailing: MIT KRU 2K 06- 01- 07.xls Thank you for the information. What troubles me about 2K -10 is there does not appear to be a standard applied to govern annulus pressure in this case. CPAI has an internal waiver (which does not show up on any list I can locate) and there does not appear to have been any notice given to the Commission about the indication of pressure communication (evident from the tracking IA and OA pressures from the TIO plot). Even if you apply a less rigorous standard to the injector than currently exists (see AIO 2B, Rule 7), we would (and I suspect CPAI would likely do the same) adopt the standard set for producing wells (see CO 494) - it just would not be consistent with the Commission's treatment of annulus pressures to do anything less than what is provided in CO 494. Allowing pressures to exceed 1000 psi in OA without notification does not meet the producing well standard; I do not find in our well files where we have been provided notice of pressures exceeding 1000 psi. We will revisit the request. Jim Regg AOGCC NSK Problem Well Supv wrote, On 6/5/2007 8:40 AM: Jim, I've enclosed the 90 day TIO plot for 2K -10 and a PDF scan of a request for clarification / administrative relief regarding reporting procedures and requirements on injection wells. 2K -10 is internally waivered for IA x OA communication. It passes an MITOA & MITIA but exhibits minor communication over time. The communication is very slow, undetectable with a standard MIT, but over long periods of time communication is evident in the trend plots. The well is waivered internally to increase scrutiny of the well. CPAI performs an MITIA / MITOA every two years, monitors and records the IA and OA fluid levels on alternate years, and records daily well head pressures. CPAI has not submitted a request for administrative approval to cover the continued operation of this well and others, with similar pressure communication issues, in anticipation that a blanket AA would be 6/16/2011 Re: 2K -10 and Other Injector reporting Page 3 of 4 • approved per CPAIs request dated 6/4/06. While dealing with 2K -10 I'd like to revisit the enclosed request for clarification and administrative relief regarding reporting procedures and requirements. What is the status of the enclosed relief request? Sincerely, Perry Klein Problem Well Supervisor office (907) 659 -7224 Cell (907) 943 -1244 Pager (907) 659 -7000 x909 n1617 @conocophillips.com Original Message .om: James Regg [ mailt . o:jim_regg @admin.state.ak.us] Sen Monday, June 04, 2007 2:01 PM To: NS' Problem Well Supv Cc: Tom M. nder Subject: Re: mailing: MIT KRU 2K 06- 01- 07.xls Please send 90 -da TIO plot for 2K -10 (PTD 1890590). Well appears to have some communicat.n to the OA; MIT done 8/17/2005 reported the well has a CPAI- internal wa er for IAxOA communication. According to AIO 2B, this well should be c. ered by an administrative approval. Jim Regg AOGCC NSK Problem Well Supv wrote, On 6/4/200 10:58 AM: «MIT KRU 2K 06- 01- 07.xls» Gentlemen, Enclosed are the results from 4 year MITIA testing 2K pad. Let me know if there are any questions, Perry Klein Problem Well Supervisor 6/16/2011 Re: Emailing: MIT KRU 2K 06-01-07.xls . . Jim Regg AOGCC NSK Problem Well Supv wrote, On 6/4/2007 10:58 AM: «MIT KRU 2K 06-01-07.xls» Gentlemen, Well appears to have some communication CPAI-internal waiver for IAxOA be covered by an administrative Enclosed are the results from 4 year MITIA testing for 2K pad. Let me know if there are any questions, Perry Klein 5CANA1ED JUN { 6 2007 Problem Well Supervisor office (907) 659-7224 Cell (907) 943-1244 Pager (907) 659-7000 x909 n1617@conocophillips.com Jim Regg <:Ü~!l_r.~.m~@ª_gX~!iP:~!9.:!~_~~~> Petroleum Engineer AOGCC 1 of 1 6/4/2007 2:01PM ) \ ,) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ,-:) \\e1tt 71(1D<;" DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA mc 2K-IO KUPARUK RIV UNIT 2K-IO o~o.. ~C\ '\ FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: ;'-'-1/ /) P.I. Suprv --Jt;;f-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-I0 Insp Num: mitCS050812190947 Rei Insp Num: API Well Number: 50-103-20106-00-00 Permit Number: 189-059-0 Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -'Well-"~lQTType Inj. ¡"wITVD--¡'-s987'-'iiAT"'1250"2170 .-- I 2120 'ï-z'ilo-¡-"'-¡'-'--- P.T~8'96590·ITYP;Te~t-r~"r· Test psi l'·-1496.75 I OA i -'l25O-t--132o-T"'- 1320..-·i--.-i320---1-----..-i.·--.---- ___c. .....-... ...J2:.,. ..__._...-L:.....___...._.L......:.....___. i \ --f-..·-·-·j--u-r·--·-·-~· '--'"'''--'''1-''' _.--- Interval 4YRTSTp/F P Tubing 2300 I 2300 I 2300 ! 2300 j ! _..___._.___ ____... "._... .~....____._.__..__....... .__...._.___L..__..__....--.I_.._ __ ...._-1_.._.__..--L--__.._._...__...-..L._______._ Notes: This Well has a Conoco Phillips internal waiver for IA x OA communication but appeared to pass this 30 minute pressure test. ~..".,"~"'ILL- t:,h,J C'"",,'¡~, "".j~: ¿ 0 Q'5 è:.... it' ¡,ï:¡. '1\~ NE fJ : - ,Jt~~(:I.' ~,I " ' ~:~"R~ Wednesday, August 17,2005 Page 1 of 1 Page 1 of 4A Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, June 01, 2004 a25 PM To: Maunder, Thomas E (DOA) Subject: RE: 2K -10 (189 -059) injector waiver Tom. We haven't done any work since 1995 Just the wellhead testing and MITs noted on the waiver. To explain the pressures, the well temp had been rising over the last few months The IA and OA track FTT. When the OA hit 1000# in 4/2004, it was flagged by our automation system The OA was bleed down and monitored A few more diagnostic bleeds were performed to verify the OA repressunng was not thermal. Wet integrity was investigated including bleeding the IA to evaluate OA response Marie Original Message From: Thomas Maunder [ma[Ito:tom_maunder @admin.state.ak.us] Sent: Tuesday, June 01, 2004 1:58 PM To: NSK Problem Well Supv Subject: Re: 2K -10 (189 -059) injector waiver Marie, Could you send an "operations summary" for this well. When I looked at our well file, aside from the most recent MIT, the most recent information is dated 9/29 /95. Was there anything unusual recently on this well ?? The IA and OA seem to get a little crazy recently. It does appear that the tubing and packer are competent. Tom NSK Problem Well Supv wrote: Tom, Requested plot attached. Marie Original Message From: Thomas Maunder [uaI ito: row m.nmdsr( d:n:_n.stste- ..f.us] Sent: Tuesday, June 01, 2004 7:16 AM To: NSK Problem Well Supv ` �6 ,- - Subject: Re: 2K -10 (189 -059) injector waiver ;; J L))'t / 0 f Hi Marie, Do you have an electronic pressure plot for this well ?? Tom NSK Problem Well Supv wrote: Tom, This is a notification of plans to waiver 2K -10 (189 -059) for minor IAxOA communication. The OA slowly builds pressure to equalize with the IA and requires bleeding. Attached is the waiver documentation. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659 -7224 <G2K -10 Waiver Injector 05- 31- 04.xls» C N � 6/16/2011 Notice of Kuparuk Waivered Well WELL: 2K -10 WELL TYPE: WAG DATE: 05 -31 -04 Injection Data: 1.5 MMSCFD 1000 BWPD Pressures: Tubing IA OA Inj: 3600 psi 975 psi 450 psi Shut -In: 3825 psi 950 psi 300 psi REASON FOR NOTICE: IA X OA communication TUBING x IA COMMUNICATION? YES NO XX • MITIA @ 2900 psi Passed 06/14/03, IA FL at surface on 4/26/04 • Tubing packoff Testing passed 03/02/98, IA x OA COMMUNICATION? YES XX NO • PPPOT -IC failed on 04/26/04, indicating the packoffs leak. An attempt to repair the packoffs failed on 5/27/04, • MITOA @ 1800 psi passed on 04/26/04 with an OA FL at surface; • Numerous OA bleed events are recorded. IMPORTANT CONSIDERATIONS /COMMENTS: • The well has shown numerous OA bleed events; • Well passed MITOA to 1800 psi, • Tubing has integrity based passing MITIA @ 2900 psi; • The leak may be in the well head. PLAN OF ACTION: XX Grant waiver to continue operations • Water injection and Gas injection allowed; • OA pressure can equalize with IA, not to exceed 1400 psi; • Bleed IA to Limit OA pressure; • Monitor well head pressures daily and log as per surveillance requirements into Setcim; • Perform the following waiver compliance testing: • MITIA & MITOA every 2 years • IA and OA FL every 2 years on alternate years as the MIT's • Shut -in and secure well if MIT fails or pressures indicate further communication problems. Problem Well Supervisor CPF Production Engineer Problem Well Supervisor Date: Date: ENDORSEMENT: CPF Supervisor Date: Wells Team Leader Date: Distribution: Send Original to: Problem Well Supervisor, NSK - 69 DS Operator CPF PE Wells File and schematic Central Files ATO Central Files Kuparuk r r v f / / \ GENERA L. TRN GNt1L y 1 N N U LUS PRESSURE TRENDS % 101. --rd. },—,- WLKRU2K -10 4000. 4000 200. ' — 4000. - -. -- 3600 - — _ _- -_ - -- _ _ - - -_ 3000. 3200 1 i 4000. 2800 - V' - I .... S 2400 _.. -- 2000 1 1600 ' 1200 5 )11/1// O. 800 g` li t . O. I 400 jt I O. 0 — — 0. PLOT START TIME MINOR TIME 11- APR -03 14:45 MAJOR TIME WEEK +10000:00:00 ERS 01 - JUN - 04_06 ;45. EMEISCI LM 1111111,1111 RT. • PI .. lint. 15- APR -03 17:45:46 SC TAG NAME DESCRIPTION ilRT[T.SITE WELL III WL2K -10 -CHOKE FLOW TUBING CHOKE 100_ • SCRATCH 38 FLOW TUBING PRESSURE 2411. NEXT WELL 2 k 1 0 • SCRATCH_38 FLOW TUBING TEMP 102. . PREV WELL - 7777? ?? - 77 ?? ? ?? ENTI OPERATOR - 7 ? ????? OW OPERATOR VERIFIED I SCRATCH_,.38 T11NFR a oTrrr TI pp F`? 806. ® SYSTEM AUTO ENTRY lir SCRATCH_38 OUTER ANNULUS PRES 806. III BOTH MEMORANDUM TO: Randy Ruedrich Commissioner Jim R egg P.I. Supervisor THRU: FROM' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2K Pad John Crisp Petroleum Inspector Kuparuk River Unit NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. 2K-05 I Type,nj.I s I ~.v.~. I ~ ITubing I ~oo I~oo I~oo I ~oo I,.terva, I 4 I I TypetestI P ITestpsil 3000 ICasing. I 1380I 2980I 2940I 2930I P/F Well[ P.T.D.I 1881180 Notes: OA 600 psi. pretest 680 psi. during test. 4.5 BBL. Pumped. We,,I 2K-06 IType,~j.I S I T.V.D. I S00S ITUbingl 23~0 123~0 123~0 I 2~o I,~terw, I 4 I P.T.D.I 1890820 ITypetestl P ITestpsil 3000 I Casingl 1320 I 3040 I 29801 2975 I P/F Notes: OA 950 psi. during test. 2.6 BBL. Pumped. w~,,I 2K-~O IType,nj.I ~ I T.V.~. I ~ I~"~'n~l ~° I ~° I ~° I ~o J,nterva,I 4 I ,., P.T.D.I 1890590 ITypetestl P ITestpsil 3000 I Casingl 410 I 2960 I 2910 I 2900 I P/F Notes: OA 200 psi. during test. 5.4 BBL. Pumped . We,,I 2K-~3 IType,.j.I S I T.V.~. I~ I Tubingl2450I~o I2450 I 2450I,~t~rva, I4 P.T.D.I 1890950 ITypetestl P ITestpsil 3000 I Casingl 1220 I 2940 I 2875 I 2860 Notes: OA 850 psi. pretest 1020 during test. 4.5 BBL. Pumped. We,,I 2K-,S I Ty,e,nj.I S I T.V.D. 15900 I Tubing12550 12550 12~50 12~0 I,nte~va, 4 P.T.D.I 1891080 ITypetestl P ITestpsil 3000 ICasing'I 1320I 2980I 2925I 2900I P/F _P Notes: OA 300 psi. during test. 5 BBL. Pumped. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING 4 year MIT's witnessed. No failures. Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed' 4 Attachments: Number of Failures: 0 Total Time during tests: 4 hrs. .c,c: MIT report form 5/12/00 L.G. 2003-0614_M IT_KRU_2K- 18_j c.xls 6/24/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state. ak.us and Bob_Fleckenstein@admin.state. ak.us OPERATOR: FIELD I UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2K 06/14/03 Sauvageau/Brake - APC John Cdsp Packer Depth Pretest Initial 15 Min. 30 Min. I I I I P.T.D.I~88~80 TypeTest Test psiI 1500 I Casing I 13801 29801 29401 29301 P/F Notes: Well 12K-06 P.T,D. I'1890820 Notes: Type Test Test psi I 1502 I Casing I 1320] 30101 29801 29751 P/F P:T,,D::II,890590 Type Test Test psiI 1500 I CasingI 4101 29601 29101 29751 P/F Notes: Welll2K-~3 I Type Inj P.T,D,I ~ 890950 Type Test Notes: T.V.D. 16138 I Tubingl 24501 24501 24501 24501Interval Test psiI 1535 I CasingI 12201 29401 28751 28601 P/F We,,12K-~8 P:T,.D,':I ~ 891080 Notes: TypeTest Test psiI 15oo I Casing I 13201 29801 29201 29001 P/F P,T,D, It891180 TypeTest Test psi I 1536 I Casing I 4001 29001 28751 28501 P/F Notes: PiT, D.I:t891300 Type Test Test psil 1551 I Casing I 13001 28801 28201 28001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_MIT, KRU_2K-05 06 10 13 18 20 24.xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6/25/2003 ~KRU 4 yr MIT's 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) [~MIT KRU 2T 06-14-03.xls[ Type: EXCEL File (application/msexcel) ,IEncoding: base64 ....................................................... ] Name: MIT KRU 2K 06-14-03.xls ~,MIT KRU 2r 06-]4-03.xls] Type: EXCEL File (application/msexcel) ] IEncoding: base64 1 of 1 6/25/2003 1:45 PI~ SEP-29-1995 10:05 FROM ARCO COMPUTER SERVICES Explov?,tion and Land Fax: (967) Z65-1688 Confirm: (987) 26~.-.469Z TO P.O. Bom 100360 AK 99510-0360 (9/}501) To: Location: ou otnS i ii ii i i ii I,ooation: ~ · .. Number of Pages includ/ng cover ,, ~- , Sender's Init: Xeroz Co]~es to: Nalne: Compauy-Hldg.-Hm. Jtddttto,,.-_! Comments/Message SEP-29-1995 10:04 FROM ARCO COMPUTER SERUICES TO September 29, 1995 To: Mr. Larry Grant AOGC From: Sandra Lemke AAI RE: database cross-checks Larry, Here's the scoop on Gull Island tt3 (Permit 91-0154). Sidewall cores were taken but no analysis or descriptions were done. I scoured through the conventional core report by Atlas(Core Labs, Inc.). and also called Core Labs(Perry) to confirm that they had not done SWC analysis on this well. We did in-house palynological work on the SWCores but this would be proprietary data to/kAl. Permit 89-0059 Kuparuk River Unit 2K-10. I gave you only the permit number that appeared on your AOGCC 'Alaska wells permitted' well printout but when I pulled the completion report I saw that this well has TWO permit numbers. The BP/Unocal portion of the borehole was drilled under permit 90-126. Could you check the data under that permit to see if directional survey data is available through the 'tail' section, 6798'-7651'? Get back to me when you can - a phone call will probably be the easiest and quickest f~ you. I/ Th an ks Lar ry~..~ Sahara LemkL~.//'"~'-~~ '.x 265-6947 TOTAL P.02 ') ) ~if}Jß/palisch 00863,70 DSE: m5¿f! ~ ?t'",- NS Central Files RTD 11 th Floor Files STIMULATION SUMMARY ,ð' KUPARUK #øp '.øii'I DATE: 5'-/7- 'i r- (If ' WElL:,,)t. -I ù AFC #: ,;1~" /)J R8¡L¿, PRESSURE SERVICE COIrREATER: PS -6)4UEa;O! ARCO REPS=p~ ( 5¿fI/:T()IIN S ANAL YSIS ACTUAL FRAC GRADIENT = ISIP I TVD TOP PERF + FRAC FLUID GRADIENT EXCESS ,FRICTION = FWHTP - ISIP - (TaG FAIC X MD TBG TAil) ~TFP VOl tiME RATF FWHTP lSJf FG lISIP1 X!=; FAIC f.a FG (pc) ~ I :300 '10. ) S1!"~ ~.3D ..90 ~ £t.¡oo ·cg7 g~ i t./ 3 to II z.c/to 2 ~O2..- ¿¡ð~ I ~ÎtJ ;J~-C , e¡ I 3 ~oo ~o,/ 5"( 3/- ,;}q;; 0 ,92- ~ 5"S"70 ,90 <e, I 12/PO $I y¿ ~ L( ~g <" 7-?J5 5' *2./, tf' ~~30 , 9"', tA 4U'Z.- IJ wll./ 0 *3~ ~Ioo-Jt ¡¿.s 5 7-35 ~~o9 ~~" -S- , q'z,.. 0 J{11? ~ 'l-v/*o ~1? ¡tJ 56,/0 ,9/ //,9 h ¿¡Ð. I t;;1t , ,;)970 ,12- -h." ~(~ '- ! ' , JIV <C/cÞ'l/~ s. '*7-D!J- 1$ 1,,£o~N"c/t;/µt TRFATMI=NT SUMMARY 1%1* TOTAL JOB VOLUME: EFFECTIVE PAD: EFFECTIVE SLURRY: PADSllJRRY RATIO: 2Y4O /302.11&2) .:33' 0 12-5' ..... PROP PUMPED: 12/18 1M4 lUTÞl /.302 9 2.c/tfð ,'''' , ,. PPA@PERFS: PFCP INW8J..8ORE; PROP IN FORMATION: PROÞ IN SURFACE EQUIPMENT: NOTF~: ,/ ) _J J W If-1O ~ ;2'';). 0; ;¡;/;/(~ Gt!-. IAJ ~ ¿6/5 ;D' ¿/pYIft-.. II ~ J ¡:::;r- 74 9~ ~ () , M/r> .=~ ôOO , . ::;~ lA/ I'1lJ d.l~'" <' I ~ ,-^", I ~ :> f7;;ø--" ø 7'" ~dJ /'1, , pv #IŸ1/ ~,,;e *,Â.. S:AIf- L. ~ d-..5Y-y ~ v .,L~. ?'- Ie:) .4i/"'-- 1)11' I+'t.jJ - <" ~ I +I"..r..£1 þ (./f- j),./....... A- 51:> - ..0, tÁ/ ¿,.1 ß I ./ .f - G/ r / /f L.~ r- J- ~ þ\oote, ,.", ~d /. - fir-' -s If 1-1--. ./ I f . #1.) ælJN-Y'S/~ ~ ~ tv\. Z~ S-r-g<' " ATTACHMENT 1:PUMP SCHEDULE KRU 2K·10 . AFC/CC 230DS28KL 80430 Sle p COWAEHTS , ( , 1 aD 0 (Î:" 1 "11Mb e \0 r- DIRTY VOLUME STEP CLIoI (BBl) (BBl) 300 300 ---- ---- DIRTY VOLUME STAGE CUt (GAL) (GAL) 12600 12600 FLUID TYPE ~ RATE (BPM) 40· STAGE VOL. (BBL) 300 --------~------ ~-- 20'aW---¡O..----1-0Õ- '--.fOO-------;¡2(jO~800 -----~-~öI_aw__-40¡-----rOO----500'--'-_mo'- 21000 20' GW 4õ'*----foo------sõ0 300 4200- 25200 ----- 40· 900 12600 37800 300 300 40· 300 '1870 12600 78540 300 Cony. MAX Breaker WHTP (I/Mgll) (PSI) 0.25 7100 -----------. PROPPANTIRS STAGE SIZE (lBS) ClEÞ.N VOLUME GROSS GSW (BBl) (BBl) 300 300 ODs! (BBl) -- "100 100 4023 20/40 96 96 100 100 300 300 - . ---- .-- RaIl EST. WHTPt: 3468 3729 4048 4430 4851 5310 5814 6343 Max TP 7247 7508 7827 8209 8630 8900 8900 8900 3360# Rock Salt 78540 12068# 20/40 1853 Wël.l AND TRF<\TlNG PRESSURE INFORMATION ffi.6.CGPADIENT= 0,90 BHTP= 5556 R.UIO GAADfENT = 0.4 4 3 ÆRF FRIC:z 500 MD TO TaG TAll= 6375 HYD HEAD: 2735 TVO TO TOP PERF: 6173 MD TO TOP PERF: 6512 TUSING HANGER= 3 1 TUBtNG SIZE= 3.500 CASING SIZE= 7.000 Stage '1 . HPBO 1 HP80 20. GW so. monitor prMaure, establish ISIP & closure prUlure (-30 mini.) Stage 12 . HPBD/Scour __ 2 HP80 --- 3 1 PPA 4 HPBDlFlush SD, establish ISIP (-15 mlna.) Stage .3 . HPBD 5 HPSO 20' GW SO, monitor preuUfe, establIsh ISIP & closure preuure (-30 mini.) Stage 14 . Dlvenlon/HPBDlScO\lr _______,_ 6 2PPGRocåSalt Slick/Gelled Diesel 5·10 10 910 420--~220 -840 Rock Salt 9- ~ GDSpecer --~ SlIcklGelledDlesel 5·:¡O----~O 920 420 38640 10 8 2PPGRockSalt SlIck/GelledDlesei 5·10 5 925 210 38850 420 Rock Salt 5 -h- ~ Sllck/Gelle:o~~~ ~~'1·~~---11~0~0 _-___ 11~01~3%0-- __ :¡~O_ ~;~~g===-____- 1~0 11 1 PPA 20' GW 4200 47460 4023 20/40 96 12 HPBDlFluah 20' GW V ~ 1 Q.Q..__--.J.23 0 330 4200-51660 100 SD, utablWl ISIP (-15 mlns.) _,__ ~tage .s . Dlveralon/HPBDlScour _____ 13 2 PPG Rock Salt Slick/Gelled Diesel 5·10 -----rS --------r-i-45 630 52290 1260 Rock Salt 14 ____.!i GO Spaçef Slick/Gelled Diesel -----s:1O----,-o-n---1255----------;¡-¿O-------s27~- 10 -~ i i -- ~;~~~,=~,-=- _n___='~ i~~~~:::~~~~~ -;:f~~- --'-)fIE ~ ~;~ --=---~--=-j~g---~~- ~~~-~g ~t;ROCk Salt ~ 17 HPØO -- --,- -'-iQ,r:iw -- .)-<i" . '1ÖO'--_--=jª7~----- ------=1~'º-º-,--=~!é.¡0_,' - 100 Ie IPftA 20. QW 30· 100 1470 4200 61740 -45~-2074o--9-6- la HpeOr'F\,*, 20; QW 30· 1ÓÕ 1570 3,Ú) -'-4200 -6594'0 -------~OO ~---~ - -. - - - - - -_._- -- -~- -- - - - ~- ------ - 10, ~ IIW (-1' .....) ~~.~ _--3.0 ..eo 20. GW SD, .-wtof pr...-, ~ rs¡p , cJoeUl'l pr__ (-30 mlna.} ·Pump at mÐ rate poaalble, TOT ALS 1870 « For Slick Water Friction Friction Frac. Praa 0,02 147 0,06 408 0,11 727 0,17 1109 0,24 1530 0,31 1989 0,39 2493 0.47 3022 TANKS REQUIRED. 3.89 GELLED DIESEL REQUIfIED. &ð BBlS PAOPPANT REQUIRED. 1206 Sf ROCK SAlT REQUIRED- 33&0' NOTES: 1 The above Max WHTPs aro based on an annulus contwning diesel with an annulus pressure of 3500 psi, and 70~ water. 2 When there IS 3500 ps¡ on caSIng. thare must be >2500 psi on tubing to keep from cOllapsing MMG ,II mandrel. :3 ActlJBI Max WHTP IS Max shown above PLUS FncUon Loss Weak 1X'Jlnlls corkscrew In lublng above packer 4 En:,uru that !I)ðrlj IS al lßa~1 20 OPM ....Or1h 01 Iflcoon Delore exceeding listod Max WHTP's (DO NOT Ðxcecd 8!)OO pSI). ·5. The dlvenlon ltag.. should ~ modJf~ .. appropriate, pending luccn. 01 the rock ult slugs. 1t3 Pump Ihe lock r.a11 SLß<Je lJ!;f1\J u-f16 turbine, ramp 10 30 BPM ahel Sdll cl6<lrs missile ~~ ldS~ Slage ~~eiT1ulr)jng lIulds away Dlspldce wlltl diesel AFTER 0blðll1illg IlfIallSIP & Pc Pi~ Time 12,1 6,0 4,0 3,0 2,4 2,0 1,7 1.5 5 10 15 20 25 30 35 40 1!ð-7 ~ b.1 S DI W. <= Bring at Jeast 150 bbis, <= Bring at least 150001, <= Bring at Jeasl 60001. FLUSH INFORMATION VOL TO TOP PERF- 60.4 0,0087 bbls.llt 0.0~82 bbls.llt 300 ---~---- 0.25 7100 -'0:2S-'6900' --~S----r1oo ------- 0.25 7100 ----~. 100 96 100 9 0.00 6900 10 0.00 6900 5 0.00 6900 5 0.00 6900 ----TIs-¡f 0 0- -~--~5--69ÕÕ-- ---0: 25--7100- 100 96 100 14 0.00 6900 1 0 ~õO 6900-- 9 0.00 6900 5--0:00 6900- -0:25-------¡f Õ 0- ---0:25 6900-- --1f:25~1oo --------~---- ------- ----_._~. 300 0.25 7100 1787 66 MODEL & FRAC. ORIENTATION INFORMATION TVD Perl, H (A3IA2) , It.= 35 Plain Strain, E'= 1,,~ Youngs Mod,. E.. 1.49 Av, Hole Angle Thru, Kuparuk= 2' Well Azimuth (f/North).. 25" Fracture Azimuth (f¡North)= 100 Well Orientation· Preferred= 15· Porosity= 22% 4/16/95 --- Dowell WElL NAME AND NUMBER 2K-10 POOlJAELO KUPARAK COUNTY/PARISH WELL DETAIL REPORT LOCATION (LEGAL) NA FORMATION A SAND STATE NORTH SLOPE ALASKA TYPE OF SERVICE PRIMARY TREATING flUID MATRIX TREATMENT SAND CONT FRACTURING _X_ OTHER OPERATOR NAME ARca ALASKA INC. SERVICE INSTRUCTlONS INmAL PSI 2920 PSI TVD 6173' HYD 2735 PSI 130291 PERFS Of PIPE FOR CONVERSION PURPOSES 24 BBlS EQUAL 1000 GALlONS ARRIVED ON LOCATION: 06:30 LEFT LOCATION: TIME OF DAY RATE BPM FLUID TYPE CLEAN FLUID Dirty VOL ) , DATE 5/17/95 DS LOCATION PRUDHOE BOTTOM HOlE AGE OF WElL TEMPERATURE _ NEW 165 _X_ OLD ALLOWABLE PRESSURE TaG 7100 CASING SIZE WT 7 26' TUBING SIZE WT 3112 9.3 PACKER TYPE BROWN TUBING VOlUME 55.4 OPEN HOlE DISPlACEMENT 60.65 CUM. PROP PROP. VOL SIZE #/GAL COO 3500 DEPTH 6790 DEPTH 6375 PACKER FT. ) 1 HEATMENT NO. 02-12-2745 TYPE OF WELL _OIL _GAS _WATER -2L-INJ. PERFORATED INTERVALS TOP TO BOTTOM It OF HOlES 6512 TO 6547 140 TO TO TO TO TO 6326 ANNUlAR VOL 167 CASING VOL 5.25 TOTAL· JOB DONE DOWN _C.TUB _X_TUB TO TO TO PERF. DIAMETER· IN. PERFORATED INTERVAL FT. PROP LBS. _CASING _ANN CSG PSI TBG PSI NOTATIONS " ~~'í\\\~~~;..'," :',," , ~ ~:~ '\""~~);ª' 1., 1 0: 13 1 0:33 30 1 0:43 40 11:26 40 11 :30 40 11 :32 40 11:35 40 11 :44 40 n:52 40 12:41 7 12:44 7 12:45 7 12:46 7 12:47 25 12:51 30 12:53 35 12:56 35 13:09 7 13:13 7 13: 14 7 13:17 7 13:20 25 13:25 35 13:28 3S 13:30 35 13:40 40 13:51 40 ,~ ' WF-2O WF-20 300 WF-20 300 100 100 WF-2O 96 101 WF-2O 100 100 WF-2O WF-2O 300 300 WF-2O GO 10 13 GO 10 10 GO 7 7 GO 5 5 WF-2Q 100 100 WF-2Q 96 100 WF-2O 100 100.6 GO 22.4 22.4 GO 12 12 GO 33 33 GO 5 5 WF-2O 100 100 WF-2O 96 100 WF-2Q 100 100 WF-2O 358.5 358.5 flUID 40 BPM AVERAGE INJECTlON RATES N2 CO2 TOTAL W/PROP 40 TREATING PRESSURE SUMMARY "MAXIMUM FINAl AVERAGE IMMED.S.O.P. 5800 5781 I 4800 I 2960 I PROOUC110N PRIOR TO THIS TREATMENT NA CUSTOMER REP: T, JOHNS 300 400 501 601 601 901 901 914 924 931 936 1036 1136 1236.6 1236.6 1259 1271 1304 1309 1409 1509 1609 1609 1967.5 WATER/ACID 1801 9 o 300 20/40 1# 4320# R.S. 2# 840# R.S. 2# 420# 20/40 1# 4332# R.S. 2# 1260# R.S. 2# 860# 20/40 1# 4377# FREEZE PROTECT PUMPS ONLY I I B8LS'OIL 2860 15 MIN S.I,P. TOTAL INJECTED 13029 LBS _X_TEST _STABIUZED PAD VOlUME FG 0,92 DS SUPERVISOR: RICK GALLEGOS SAFETY MEETING 1500 2700 SET TREESAVER 3230 6150 STEP 1 3460 5758 SD ISIP 2830 3313 5570 STEP 2 3428 5753 STEP 3 3446 5556 STEP 4 3450 5781 ISIP 2860 3405 5689 STEP 5 3441 5836 ISIP 2920 3100 3000 STEP 6 3368 2938 STEP 7 3350 2975 STEP 8 3332 3052 STEP 9 3350 4348 STEP 1 0 3460 4796 STEP 11 345S 5085 STEP 12 3464 5268 so ISIP 2929 3368 3098 STEP 13 3336 3000 STEP 14 3332 2900 STEP 15 3310 2900 STEP 16 3309 4091 STEP 17 340S 5236 STEP 18 3469 5144 STEP 19 3450 5309 ISIP 2947 3354 5314 STEP 20 3355 5781 so ISIP 2960 VOlUME flUID INJECTED I NITROGEN 45 BBlS QIJANTTTY PROPPANT' PlACED 'TOTAL ORDEREOIDESlGNED 12068 LBS CARBON DIOXIDE CCF TONS GALS "" PAD: PAGE _1_ OF _1_ PAGES PSI I · - t--, · -- I .---,---- n ..[.............. ' , - . . . . . . . . ~. . . . . .. .............. ... . . . .. ..... .. 10 ...............,............. ~ __ 14' 20 . ..................... . I . . o 10: 33 TIME-OF-DAY () . ."..",,,.. If....."............"............",....................."..... .... I........,..". ......,... .."......"..."."... 50 ~LUR-RA TE (BPM) ...................................... .}..................,...........................................................1 40: J I - ----- I ·'r - · .' ~- - -_. ,I Il--' . .......................... ........ ~.................... ~. . . . . . . . . . . . ·r . . . . . . . . . . . . . . ~ . . . . . .'. . . . . . . . . . . . . . . . . . ·1 30 - - '.'-', -.. --- ,--:.. J:. . ,., ~ ..................................... .....................;.......... .., ........... .1' .. .......... \.............. · ~ ' 20 ' -- r____,~__~. __-, ~, ___1 '- t --. - -.' ~6000 .- ... --..... --........... ' " - ¡,..... ,- .-: . . .:1' . . . .. .. ......................... I 6000-_ . .....,.... ..··..··............:..........·f.... _ -14000 .... .. ..... .. .... .. .... ..... .... .; .-.- _. " . '. i ' . . --- . :..... ,...-... ...... .:-.. ~.... .............. "I PSI 400 0 ~/'" #. ~ . . , . . . .'. . . . f'" . .. . ,. . , . .. .. ~'. , . . . .. k-' ___'0'_" --'~2 00 D . .. . .. .. .. .. .. .. .. .. .. .. .. . - : -_.-- -. '( . ' - ,- --~ .. ---. : .. .. .. .. .. .. . .. .. .. .. .. .. .. . .. . .. . .. .. .. .. . .. .. . , 2000 .... .. ........... ......... .....-JO :............................................: - ----. -~- o AN-PRES (PSI) .._' _ ,SOOO --:-- _.' , j ..........................................................~........................................................... / 8000 TR-PRES_~P~+) Dowel ARCO ALASKA INC 2K-10 HPBD PRUDHOE BAY l3 ( ! -¡ ; ~ : ~ ", " i - r: ~ ~:. - , PPR TREATMENT REPORT 17 May 95 ~) ,[\ 6000 2K-10 Pressure Data r ~ Composite ~ . 60 AJ 5000, J v ,- 50 ,.t t 4000 -..,.. Jet .~ r- ~ pp 40 ëñ ... -- c. ~ 3000 :æ ,--k \J Q. CIO ¡( II 30 a: l '- "-- "'---- '--{ Q) ... co r a: , 2000 --- 20 ~' 1000 ,- 1 0 -----~ - .... ~ , - WHTP o --- 0.00 ~. - Rate , ; o 50.00 100.00 150.00 200.00 Elapsed Time, mins 5/17/95 ~.... '~ ~m ;256~~si ~ '···_··~···········'--'\__·~-_.....~_A.'-- HPBD#1 5/17/95 Diversion#1 Elapsed Time, mins 40.00 I ' 30.00 25.00 20.00 35.00 , , HPBD#2 ., \_~.."'- ... - .. ... - ... - - - .."- HPBD#3 --.. -'·',,-,__2755 psi -,. Diversion# 1 - \ I' ... 2800 _n . ,--- --- ... -" - -" - ....'~,..., r..". --~- - - - ·SITP#6 - , , - ,,_ 2828 psi -''''''-- SITP#2 - - - - - -- SITP#3 - - - - SITP#4 - - SITP#5 HPBD'S @ 20 min. SD Ditt. #2 to #1 = 188 psi Ditt. #3 to #1 = 261 psi - -- --- -. - _._- --- -~ - ------- ------ SITP#1 2K·10 Pressure Data Composite SITp·s .:¡ 15.00 10.00 2400-- 0.00 r- 5.00 2500 _n 2600 -, Scour#1 .Ci) Q. ~"' ~ 2700 - II> II> ~ Q.. -... . 2900 " 1;." ~\ " ~" "- I" '" -" ',,- ,\.-\.... ' \ \ " ........ ,,-" - " ~ -- ~ - .. .. - - .. - ... "' - #2 '- '" .I' ~ ,,_....... Diversion -"'-~", -...-,....... .....-......, ' , 3000 - /\ . ~~""'''' - -..:. --= - - - -;.-,- -:.: :....-___ '7C~--::-_-:- - - - - - -" - - - - - ",........... - - - - - -, 50 ~---.\--,--- -~.~. ..- ,- - - - - - . " ~ Very little changej<50 psi increase from HPBD#3 to #1. , " , " I ' " I /' " ....I 1 : 5000 -. I " I : I : I : 1 ' : r, ';-r- ,,'....~- I I \/,1 I 1 ' I 4000 1 I ,.. , \ 1 1 I " I' , I I " I :, ,.. 3500 -I ' " ,.. ! I ,.: 3000 !r--/ , '-- 6500 6000 -- 5500 .- ëi) c. ~ :s 4500 U) U) C1) .... 0.. 2500 0.00 2.00 ,(~ 2K-10 Pressure Data Composite HPBD'S ^ I \ 1- \-- IL. -..c-.---.. ~. - I .. r 4.00 6.00 Elapsed Time, mins 8.00 I, , '- " ~--- ---------- ---~------ n 55 ..--- '·45 ~ 0.. -- 40 ~ .. co c: . - 35 ---- WHTP#1 ----WHTP#2 _ _ _ _ _ _ _ WHTP#3 ,3 0 Rate#1 - - Rate#2 - - - -Rate#3 -- n:=CC1C'=:'':-:'C.' .·,u·CL 25 10.00 - 5/17/95 ~'---- ---....,. ", Unocal Energy Resources Division Unocal Corporation 14141 Southwest Freeway Sugar Land, Texas 77478 PO. Box 4551 Houston, Texas 77210-4551 Telephone (713) 491-7600 UNOCALe DOCUMENT TRANSMITTAL September 3, 1993 ~ ~ £ÚC\/O TO: C/O Larry Grant FROM: Joel Alnes LOCATION: 3001 PORCUPINE DR. LOCATION: 14141 SOUTHWEST FREEWAY ANCHORAGE, AK 99501-3192 SUGAR LAND, TX 77459 ALASKA OIL & GAS UNOCAL OIL & GAS CONSERV AllON COMMISSION TRANSMITTING AS FOLLOWS DATA REQUESTED FROM ARCO 2K-I0 WELL, KUPARUK RIVER FIELD: MECHANICAL SIDEWALL CORE DESCRIPTIONS ROUTINE CORE ANALYSIS DATA RECEIVED SEP 0 7 1993 Alaska Oil & Gas Cons. Commission Anchorage PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy OF TIllS DOCUMENT ~~MIT~HANK YOu. RECEIVED BY: ~ p rfi ~ DATED: V 1:\ ^_",__ _" ,__, __^"^, __ _"_,.. STATE OF ALASKA Ab ~ OIL AND GAS CONSERVATION COMM~bo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 71' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1194' FSL, 933' FWL, Sec. 2, T10N, R8E, UM At effective depth 1204' FSL, 935' FWL, Sec. 2, T10N, R8E, UM At total depth 1334' FSL, 1087' FWL, Sec. 2, T10N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 7651 ' 7306' feet feet Plugs (measured) None ORIGINAt , -,., 6. Datum elevation (DF or KB) Effective depth: measured 6724' true vertical 6380' feet feet Junk (measured) None Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3000' 9 5/8" Intermediate Production 6790' 7" Liner Perforation depth: measured 6512'-6547' true vertical 61 72'-6207' 4 SPF, Cemented 900 Sx AS III & 186 Sx Class G 225 Sx Class G 180° phasing Tubing (size, grade, and measured depth) 3.5" J-55, 9.3#, ABMOD, EUE @ 6375' Packers and SSSV (type and measured depth) Baker HB @ 6326', Camco TRDP-1A-SSA @ 1806' 154' RKB feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-10 ]9.,.~Permit n ~¢~ ~,4~r/apg~a I.. ,~rt3number I10. APl number [;0-103-20106 11. Field/Pool Kuparuk River Oil Pool True vertical depth 115' 2932' 6445' 13. Stimulation or cement squeeze summary Measured depth 115' 3000' 6790' RECEIVED Intervals treated (measured) Treatment description including volumes used and final pressure 14. JUN 1 4 199t Alaska 0ii & Gas Cons, Commission Anchorage Tubing Pressure Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Subsequent to operation 550 960 0- 0- 295 0 - 1700 1400 2100 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Water Injector X__ Oil _ Gas Suspended Service -0- SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~~'d~''~ Title ~-[~)~'[- (~~~J~/~ Form 10-404 Rev 09/12/90 //J ELL 2K-10 PRODUCER APl # 501032010600 SURFACE LOCATION: 71' FSL, 94' FEL, SEC 2, 'T10N, R8E, UM TOP KUPARUK: 1195' FSL, 931' FWL, SEC 1, T10N, R8E, UM DEPTHS: REFERENCED TO 0' RKB TUBING SPOOL ELEV: 31' RKB ALL DEPTHS MD-RKB 16": 62.5# H-40 @ 115' 9 5/8": 36# J-55 @ 3000' TREE: FMC GEN IV 5000 PSI BAKER PBR: 3.000" ID @ 6312' BROWN HB PKR: 2.892" ID @ 6326' OTIS 'XN' NIPPLE: 2.75" X 2.813" ID @ 6363' SHEAR OUT: 3.000" ID @ 6374' L k, GLMI' GLM2: GLM3' GLM4: SPUD: 12/12/89 COMPLETION: 4/11/90 SSSV- CAMCO TRDP-1A-SSA ID 2.812" @1806' 2337' / 1.0" TMPD/DV 4305' / 1.0" TMPD/DV 5619' / 1.0" TMPD/DV 6270' / 1.5" MMG-2/DV 3.5" 9.3# J-55 EUE ABMOD IPC TUBING TAIL @ 6375' B A5 A4 A3 7": 29# L-80 @ 6790' '/'/////ll PBTD: 6722' HOLE ANGLE ACROSS KUPARUK = 1 DEGREES MAX HOLE ANGLE = 30 DEGREES @ 3600' VOLUME TO TOP PERF -- 60 BBLS 6512' 4 SPF ~. 180° PHASING ORIENTED 26° CCW 6547' FILL TAGGED AT 6564' (6/4/90) REVISION: 10/30/90 'ARCO Alaska, Subsidiary of Atlantic Richfield Compa~ WELL SERVICE REPORT JELL 'NTRACTOR REMARKS IOPERATION AT REPORT TIME ~z, eea~.,~'Z'~ .8edx/F ce~T'o.c AxlxleiLus' Fl~ :.. ; . ~.:- :,: '""ago .... "06100 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISS,ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown _ Re-enter suspended Well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate __ Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator 5. Type of Well: 6, Datum elevation (DF or KB) Development X ARCO Alaska. lnG, Exploratory _ RKB 154' feet 3. Address Stratigraphic _ 7, Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 71' FSL, 94' FEL, Sec. 2, TION, R8E, UM 2K-10 At top of productive interval 9. Permit number 1194' FSL, 933' FWL, Sec. 1, T10N, R8E, UM 89-59 At effective depth 10. APl number 1204' FSL, 935' FWL, Sec. 1, TION, R8E, UM 5o-103-2010§ At total depth 11. Field/Pool Kuparuk River Field 1334' FSL, 1087' FWL, Sec. 1~ TI ON, R8E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 7 6 51 ' feet Plugs (measured) true vertical 7306' feet None Effective depth: measured 6724' feet Junk (measured) true vertical 6 3 8 O' feet None Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 1 1 5' 1 6" 1 1 5' 1 1 5' Surface 3000' 9 5/8" 900 Sx AS III & 3000' 2932' Intermediate 186 Sx Class G Production 6 7 9 0' 7" 225 Sx Class G 6 7 9 0' 6 4 4 5' Liner Perforation depth: measured 6512'-6547' 4 SPF, 180° phasing P~ E 6 ~.~V E D true vertical .. ~r, 6172'-6207 Tubing (size, grade, and measured depth) 3 1/2" J-55, 9.3#, ABMOD, EUE @ 6375' ' :~¢~a 0ii & 6aS ConS. Packers and SSSV (type and measured depth) Baker HB ~ 6326'~ Camco TRDP-1A-SSA @ 1806' 13. Attachments Description summary of proposal _ Detailed operation program ~ BOP sketch_ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: November 20, 1990 . Oil ~ Gas ~ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service _Water Injector 17. I hej~by certify,.~hat the foregoing is true and correct to the best of my knowledge. Signed'~~ ~)o ~ Title ~'~,i~.~ ¢~4~~ ~ Date tt~".~/~"/t~ . FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApprov.al No. Plug integrity_ BOP Test_ Location clearance__ I ~'~""' ~/~::~ Mechanical Integrity Test ~ Subsequent form require 10- ~/¢ i ! ORIGINAL SIGNED BY LONNIE C. SMITH j~ Approved by order of the Commission Commissioner DateI 1 rm 09/12/90 Approved Copy ReturneO ~ SUBMIT TRIPLICATE Messrs. Kralick and October 29, 1990 Page 2 Drill Site 2K Initial Water Injection Conversions CC: Downhole 899381 Surface 899399 10/29/90 1) 2) 3) 4) 6) 7) 8) 10) 11) This wireline work should be completed approximately one week prior to the completion of the water injection piping work at DS-2H. The spool piece work inside the manifold building should be completed at the same time. MIRU Slickline and diesel pump truck. RIH and set SV in "XN" or "D" nipple. Wells 2K-06, 18 and 20 are currently on gas lift. Well 2K-10 has not been gas lifted. RIH and pull the bottom DV and replace with a CV in Well 2K-10. Pump diesel down casing while taking returns from tubing. Fill annulus with diesel. Casing displacement to bottom mandrel and mandrel depth are listed below: 2 K- 0 6 195 bbls 7361 feet 2 K- 1 0. 166 bbls 6270 feet 2 K- 1 8 186 bbls 7035 feet 2 K- 2 0 274 bbls 9056 feet 2-7/8" TBG RIH and pull all GLV's, OV's and CV's and replace with DV's. Ensure annulus is filled with diesel. Pressure test tubing to 2500 psi to ensure DV's are set. Place 2000 psi on casing while pressure testing to prevent tubing buckling. RIH and puli SV. RDMO Slickline. Prior to initiating water injection, a diesel/xylene spear should proceed to clean up the perforations. Pump 50 bbls of diesel with 10% xylene at 2 BPM. Initiate water injection at approximately 500 BWPD and gradually ramp up the injection rate until the WHP reaches 1500 psi. Keep the injection rate constant until Operations Engineering can perform a step rate test. Once the step rate test is complete, open wells to maximum injection pressure. STATE OF ALASKA ALA~rtA OIL AND GAS CONSERVATION CON,w~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 89-59/90-126 '3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20106 4 Location of well at surface 9 Unit or Lease Name 71' F.I~L, 94' FEL, SEC 2, T10N, RSE UM .......... -~'" .... -~ KUPARUK RIVER At Top Producing Interval i ! ,/;~klr~:.:~..' 10 Well Number 1196' FSL, 1220' FWL, SEC 36, T11N, RSE UM Surf. 2K-10 ~ At Total Depth '~3~ ~O ~1 ~iO~ j~~ ~ 11 Field and Pool ~FSL, ~ FWL, SEC~, T~, RSE UM KUPARUK RIVER FIELD 5 Elevation in feet (indicam KB, DF, etc.) 6 L~se Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154' ADL: 25588 ALK: 2674 ~ 2 Date Spudded 13 Date T.D. Reach~ 14 Date Comp., Susp. or Aband. 15 Water Dep~, i'f offshore ~16 No. of Completions 1 ~11/89. 12/17/89. 6/1/90. NA feet MSLJ 1 , 17 Total Dep~ (MD+~D) 18 Plug Back Depth (MD+TVD) 19 Directional Suwey ~20 Depth where SSSV set ~ 21 Thickness of permafrost I 7651' MD &7306' TVD 6724' MD & 6380' TVD YES ~ NO ~ 1806' f~t MD 1400' APPROX 22 Ty~ El~tric or Other Logs Run D IUSFUGR/SP/FDc/cNUcAUcBUGYRO 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP ~ HOLE SIZE CEME~ING RECORD AMOUNT PULLED 16" 62.5~ H-40 SURF 115' 24" 179 SX AS II 95/8" 36~ J-55 SURF 3000' 12-1/4" 900SX AS III, 186SX C~SS G' 7" 26~ J-55 SURF 6789' 8-1/2" 225 SX C~SS G . ,, 24 Pedorations open to Production (MD+~D of Top and BoEom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 6374' 6326' , , 6512' - 6547' 4-1/2" ~4 SPF MD 6172' - 6207' TVD ~6 ACID, FRACTURE, CEME~ SQUEEZE, ETC DEPTH I~ERVAL {MD) ~ AMOUNT & KIND OF MATERIAL USED SEE A~ACHED ADDENDUM 27 PRODUCTION TEST Date First Production JMethod of Operation (Flowing, gas lift etc.) I Date of Test Hours Test~ PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I !TEST PERIOD FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAV~Y-API (corr) Press. 24-HOUR ~TE 28 CORE DATA ~Brief description of lithology, porosi~, fractures, apparent di~ and presence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 6444' 6104' NA KUPARUK C BOTTOM 6451' 6111' KUPARUK A TOP 6477' 6137' KUPARUK A BO'I-rOM 6602' 6262' 31. LIST OF ATI'ACHMENTS GYRO, FRAC 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History- Initial Report - Daily Instructions: Prepare and submit the "laililt Rl~lf' on the first Wednesday after a well is spudded or workover operaflone are started. Daily work prior to spudding should be summarized on the form ;living inclusive dates only. District ARCO ALASKA INC. Field ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 Title COMPLETIONS KUPARUK RIVER 'UNIT ALK: 2674 IState AK l Well no. 2K-1~ Auth. or W.O. no. AK3650 Operator ARco Spudded or W.O. begun "1Date SPUD I Date and depth Complete record for each day reported as of 8:00 a.m. NOP~)IC ~1 12/11/89 I ARCO W.I. 55.8533 IHour Prior status if a W.O. 04/11/90 (18) TD: 7651 PB: 6724 SUPV:GB PREP TO RUN COMPLETION MW:10.6 NaCl/NaBr ACCEPT RIG FROM 2K-9 A 0600 HRS 4/10/90. ND TREE, NU BOPE, TEST BOPE. RU HLS PERF UNIT, RIH WITH GUN #1. STUCK GUN @ 6464', PULL FREE AND POOH, RD HLS. LEFT WHEEL FROM ORIENTATION ROLLERS IN WELL. RIH W/ BIT AND DC'S AND DP. 6.125" BIT AND 7" CASING SCRAPER WENT ALL THE WAY TO PBTD OF 6722' WITH NO PROBLEMS. POOH, LD BIT AND SCRAPER. RU HLS, PERF WITH GUN #1 6532'-6547', 4-1/2" CASING GUN, 4 SPF, 180 DEGREE PHASING, 36 GRAM AND 30 GRAM CHARGES. ORIENTATION WAS 16 DEGREES FROM TOP OF HOLE. POOH WITH GUN %1, ALL SHOTS FIRED. RIH WITH GUN #2, SHOT 6512'-6532', ORIENTATION WAS 25 DEGREES FROM TOP OF HOLE. POOH WITH GUN #2, ALL SHOTS FIRED. RD HLS. NU FLOW NIPPLE AND FLOW LINE. PREP TO RUN COMPLETION. DAILY:S44,112 CUM:$899,784 ETD:S899,784 EFC:$1,294,000 The above is cor~t For form preparation an.d~st~ribution, ~ see Procedures Manual(~ection 10, Drilling, Pages 86 and 87. . AR3B-459-1-D Number all dally well history forms consecutively las they are prepared for each well, Page no. ARCO O, ,~nd Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District ARCO ALASKA IN~C. County or Parish NORTH SLOPE Lease or Unit Title J~OL: 25588 COMPLETIONS Accounting cost center code State AK Field KUPARUK RIVER UNIT ALK: 2674 j Well no, 2K~10 Auth. or W.O. no. AK3650 Operator A.R.Co. W.I. ARCO Date 55. 8533 Spudded or W,O, begun SPUD 12/11/89 Date and depth as of 8:00 a,m. 04/12/90 (19) TD: 7651 PB: 6724 SUPV:GB Complete record for each day reported NORDIC #1 I otal number of wells (active or inactive) on this Dst center prior to plugging and bandonment of this well our I Prior status if a W,O. I RIG RELEASE MW:10.6'NaC1/NaBr RU TO RUN COMP STRING. PULL BOWL PROTECTOR HOLD SAFETY MEETING. RUN 205 JTSB 9.3#,J-55 EUE 8 RD AB-MOD IPC TBG. W/ TBG TAIL @ 6375', BAKER "HB" RET PKR @ 6326', BAKER PBR @ 6312', GLM'S @ 6270',5619', 4305', 2337', SSSV @ 1806', FMC GEN IV 3-1/2" TBG MGR. TEST SSSV C-LINE TO 5000 PSI DRAIN STACK, LAND TBG & RILDS, TEST TBG TO 2500 PSI, PRES ANN TO 1000 PSI F/10 MIN RELEASE, PRESSURES & BOLDS, PU & SHEAR PBR, RELAND TBG-RILDS, TEST SSSV-TEST GOOD, BLEED OFF PRES CLOSE SSSV. LD LDG JT, SET BPV, ND BOP, NU FMC XMAS TREE, PULL BPV, SET TP, TEST TREE, TEST PACKOFF, PULL TP, OPEN SSSV & PRESS ANN TO 2500 PSI F/15 MIN INCREASE PRESS & SHEAR BALL FROM SOS, BLEED PRES TO 0 PSI., DISPLACE ANN WITH 6 BBLS DIESEL, BULLHEAD 2 BBLS DIESEL DOWN TBG, SECURE WELL, RELEASE RIG 2400 4/11/90 DAILY:S162,759 CUM:$1,062,543 ETD:S1,062,543 EFC:$1,294,000 Old TD I New TD P8 Depth I Released rig IDate IK nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct · Date __ . Ti Drilling. Pages 86 and 87. Number all daily well history forms 'con,~e~'~l~"~'" ?~' j Page no. as they are prepared for each well. I AR3B-459-3-C Dlvl=~on of AllantlcRIchfteldCompanY ADDENDUM WELL: 5/16/90 2K-10 Frac KRU "A" Sand in 10 stages as follows: Stage 1. Stage 2 Stage 3 Stage 4 Stage 5 Stage *6 Stage *7 Stage **8 Stage **9 Pmp Pmp Pmp Pmp Pmp ISIP: Pmp Pmp ps~ 200 bbls YF240 Gelled H20 Pre Pad @ 25 bpm 5280-4180psi 60 bbls YF240 Gelled H20 Pre Pad @ 20 bpm 3850-3990psi 45 bbls YF240 Gelled H20 Pre Pad @ 15 bpm 3580-3810psi 30 bbls YF240 Gelled H20 Pre Pad @ 10 bpm 3450-3790psi 58 bbls Slick Diesel Flush; @ 35 bpm 4180-3580psi 2344 peal fric 0 Ivac grad: .73 1200 bbls YF240 Pad; @ 25 bpm 3640-4250psi 101 bbls YF240 Pad W/2# 16/20 Carbolite @ 25 bpm 4250-3960 Prop 111 bbls YF240 Pad W/44¢ 16/20 Carbolite @ 25 bpm 3960-3850 ps~ Pmp 119 bbls YF240 Pad W/6# 16/20 Carbolite @ 25 bpm 3850-3670 ps~ Pmp 126 bbls YF240 Pad W/8# 16/20 Carbolite @ 25 bpm 3670-3540 ps~ Prop 63 bbls YF240 Pad W/10# 12/18 Carbolite @ 25 bpm 3540-3855 ps~ Prop 15 bbls YF240 Pad W/12# 16/20 Carbolite @ 25-23 bpm 3855 ps~ Stage 10 Pmp 58 bbls Slick Diesel Flush @ 22-1/2 bpm 3855-3530 psi Tagged w/.28 mCi Sc-46/1000# sand - 20 mCi total Tagged w/2.2 mCi Au-198/1000# sand - 100 mCi total Cut R.A material 15 bbls before flush Went to flush early (24 bbls) when Nolte started up and dropping 2 bpm didn't change treating pressure Fluid to recover: 203 bbls Diesel & 1983 bbls H20 Sand in zone: 98,058# 16/20 Carbolite & 31,183# 12/18 Carbolite Sand in casing: 9244t 12/18 Dr~in~t~ Sidewall Core Descriptions - Arco 2K-10 well, Kuparuk River Field Mechanical Sidewall Core data was collected on December 25, 1989. Halliburton Logging Services collected this data for Unocal and BPX. RUN# 1 Depth Recovery 7138' 1" 7224' 1.5" 7228' 2" 7227' NR 7230' NR 7229' NR 7219' NR 7233' 1.5" 7260' NR 7229' 7260' 7350' 7357' RUN #2 1.5" 1.75" 1.25" 1.75" Description Claystone - med. brown color, silty, very soft, no shows Claystone - med. brown color, silty, firm, spotty, dull yellow sample fluor., it. yellow cut fluor. Siltstone - med. gray color, sandy, fair sorting, sub-ang to sub-rnd, glauconitic, lt. brown cut fluor. Siltstone - med. gray, fair sorting, firm, weak oil odor, yellow-white cut fluor. RECEIVED Alaska 0il & Gas Cons. sorting, rounded grains, f~-rm, weak oil odor, lt. yellow fluor in 20% of sample, streaming yellow cut fluor. same as 7299' Siltstone - med. brown, clay-rich, good sorting, rounded grains, firm, medium oil odor, 60% sample fluor. - lt. yellow, slow streaming, milky cut fluor. Siltstone - med brown, clay-rich, fair sorting, firm, medium oil odor, 60% sample fluor. - dull yellow, slow streaming, milky cut fluor. page 2 of 2 Sidewall Core Descriptions - Arco 2K-10 Well, Kuparuk River Field (continued) 7367 ' 1.5" 7374' NR 7389' NR 7440' 1.5" 7480' 1.75" 7513' 1.5" 7536' 1.25" 7554 ' NR 7560.5' 1.75" 7313.5' .75" 7296' 1.25" 7293' 1" 7177' NR 7165' NR 7145' NR 7050' NR Siltstone - med. brown to gray, clay-rich, poor sorting, sub-ang, to sub-round, med. brown stain, 50% dull yellow sample fluor., slow streaming, milky white cut. Siltstone - med. brown, clay-rich, fair sorting, sub-ang, to sub-rnd., med. brown stain, 10% dull yellow sample fluor., lt. yellow cut fluor. Shale - med. gray, firm Shale - med. gray - brown, firm same as 7513' same as 7513' Shale - med. brown - gray, silty, micaeous Shale - dark gray, faint cut fluor. Shale - med. gray, firm RECEIVED SEP 1995 Alaska Oil & Gas Cons, uommission Anchorage Attempted 29 mechanical sidewall cores, recovered 18. ! I 2K-10 SIDEWALL ROUTINE CORE ANALYSIS DATA BP RESEARCH WESTPORT LABORATORY Permeability Porosity Depth (ft) Nitrogen (mD) (%) Grain Density (gm/cc) I 7224 O.268 I 7229 rid 7233 0.522 I 726O O.229 8.57 19.62 19.56 14.73 2.66 2.66 2.67 2.67 I 7350 0.100 7357 0.157 I 7367 0.308 I 7440 0.926 10.18 11.98 12.30 12.59 2.69 2.70 2.70 2.68 I I I I I {nd = not determined} RECEIVED SEP O~ 199~ ~aska Oil & Gas Cons, Anchorage SUB. SURFACE DIRECTIONAl. SURVEY ~UIDANCE r~ONTINUOUS r'f]OOL Company ARCO ALASKA, INC. I I ii i I i i il Well Name 2K-lO (71' FSL,94' FEL,SEC 2,TION,R8E,UM) I III III i i Field/Location KUP^RUK, NORTH SLOPE? ALASKA ...... Job Reference No. 73628 WE ST/FRITZKE Oatq 30-DEC-89 Computed By: KOHRING SCHLUMBERGER GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA, INC. 2K-10 KUPARUK NORTH SLOPE, ALASKA SURVEY DATE: 30-DEC-1989 ENGINEER: WEST/FRITZKE METHOgS OF COMPUTATION TOOL LOCATION: TANGENTIAL- AVERAGED DEVIATION AND AZIMUTH INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. gIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH ~3 DEG 4 MIN EAST ARCO ALASKA, INC. 2K-10 KUPARUK NORTH SLDPE, ALASKA COMPUTATION DATE= 5-JAN-gO PAGE 1 DATE OF SURVEY= 30-DEc-igBg KELLY BUSHING ELEVATION= 154.00 FT ENGINEER: WEST/FRIT~KE INTERPOLATED VALUES FOR EVEN 100 FEET DF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE, SECTION SEVERITY NORTH/SOUTH EAST/WEST OIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET OEG MIN 0.00 0.00 -154.00 0 0 N 0 0 E 0.00 0.00 0.00 N 0.00 E lO0.O0 100.00 -54.00 0 2 S 8 4'7 W -0.30 0.00 0.17 $ 0.27 W ZO0.O0 200.00 46.00 0 11 S 55 27 E -0.30 0.08 0.30 S 0.11 W 300.00 300.00 146.00 0 15 $ 51 0 E -0.26 O.O0 0.52 S 0.18 E 400.00 400.00 2¢6.00 0 1:3 S 48 47 E -0.24 0.00 0.79 S 0.50 E 500.00 500.00 346.00 0 12 S 39 59 E -0.22 0.00 1.04 S 0.79 E 600.00 600.00 446.00 0 15 S ,40 48 E -0.27 0.00 1.35 S 1.05 E 700.00 699.99 545.99 0 16 S 22 42 E -0.41 0.30 1.75 S 1.27 E 800.00 799.99 645.99 0 16 S 7 24 E -0.66 0.00 2.20 S 1.40 E gO0.O0 899.99 745.99 0 19 S 12 53 E -0.97 0.20 2.72 S 1.49 E 0 21 S 10 I E -1.33 0.06 3.28 S 1.56 E 0 18 S 1 9 W -1.72 0.34 3.85 S 1.60 E 0 16 S 5 16 W -2.09 0.06 4.35 S 1.59 i 0 17 S I 56 W -2.47 0.19 4.85 S 1.56 E 0 17 S 3 49 W -Z. B5 0.07 5.32 S 1.51 E 0 15 S 11 20 W -3.23 0.00 5.78 S 1.45 E 0 14 S 18 8 W -3.60 0.28 6.19 S 1.35 E 0 15 S 33 41 W -4.00 0.00 6.59 S 1.19 E 0 20 S 31 43 W -4.49 0.15 7.00 S 0.91 E 0 22 S 45 39 W -5.09 0.00 7.45 S 0.52 E 1000.00 999.99 845.99 1100.00 1099.99 945.99 1200.00 1199.99 1045.99 1300.00 1299.99 1145.99 1400.00 1399.99 1245.99 1500.00 1499.98 1345.98 1600.00 1599.98 1445.98 1700.00 1699.98 1545.98 1800.00 1799.98 1645.98 1900.00 1899.98 1745.98 S 51 18 W -5.68 0.72 N 55 1Z E -3.88 7.&7 N 60 30 E ,g.18 4.22 N 55 6 E 29.05 4.30 N 53 20 E 55.75 2.33 N 47 23 E B9.OB 3.86 N 44 33 E 126.49 3.29 N 43 22 E 169.34 2.89 N 43 18 E 216.40 0.53 N 43 17 E 263.62 1.64 ZO00.O0 1999.98 1845.98 0 13 2100.00 2099.94 1945.94 3 39 2200.00 Z199.09 2045.09 10 7 2300.00 2296.70 2142.70 15 3 2400.00 2392.62 2238.52 17 15 2500.00 24~7.13 2333.13 20 54 2600.00 2579.84 2425.84 23 4 2700.00 2670.16 2516.16 27 31 2800.00 1758.39 2604.39 2B 9 ' Z900.O0 2846.54 2692,54 28 30 N 43 40 E 312.38 0.40 N 43 20 E 361.72 0.22 N 43 Z E 411.39 0.35 N 42 37 E 461.37 0.34 N 42 20 E 511.57 0.18 N 41 59 E 561.85 0.17 N 41 41 E 512.19 0.20 N 41 24 E 662.45 0.18 N 41 14 E 712.55 0.02 N 41 11 E 762.61 0.15 3000.00 2933.84 2779.34 29 32 3100.00 3020.82 2866.82 29 39 3200.00 3107.61 2953.61 Z9 54 3300.00 3194.23 3040.23 30 4 3400.00 3280.71 3126.71 30 11 3500.00 3367.15 3213.15 30 12 3600.00 3453.54 3299.54 30 15 3700.00 3539.99 3385.99 30 6 3800.00 3626.52 3472.52 30 4 3900.00 3713.07 3559.07' 30 2 0.00 N 0 0 E 0.31 S 57 48 W 0.32 S 2.1 3 W 0,55 S 19 10 E , \ 0.94 S 32 14 E } 1.31 S 37 9 E 1.71 S 37 49 E 2.16 S 35 58 E 2.61 S 32 22 E 3.10 S 28 41 E 3.63 S 25 ZB E 4.16 S 22 33 E 4.63 S 20 5 E 5.09 S 17 53 E 5.53 S 15 54 E 5.96 S 14 7 E 6.34 S 1Z 20 E 6.69 S 10 12 E T.06 S ? 23 E 7.47 S 3 58 E 7.84 S 0.07 E 7.84 S 0 33 E 6.67 S 1.45 E 6.83 S 12 17 E 0.32 S 12.32 E 12.32 S 88 31 E 11.23 N 30.52 E 32.53 N 69 48 E 7.7.74 N 53.43 E 50.20 N 62 33 E ~ 48.57 N 78.49 E 92.31 N 58 15 E 74.74 N 105.29 E 129.12 N 54 38 E 105.66 N 134.95 E 171.39 N 51 56 E 139.90 N 167.24 E 218.04 N 50 5 E 174.30 N 199.58 E 264.98 N 48 52 E 209.61 N 233.21 E 313.56 N 48 3 E 245.42 N 267.15 E 362.77 N 47 26 E 281.63 N 301.15 E 412.32 N 46 55 E 318.30 N 335.11 E 462.19 N 46 ZB E 355.32 N 369.02 E 512.28 N 46 5 E 392.59 N 402.78 E 562.45 N ~,5 44 E 430.11 N 436.36 E 612.71 N 45 25 E 467.74 N 469.70 E 662.88 N 45 7 E 505.40 N 502.79 E 712.89 N 44 51 E 543.08 N 535.79 E 762.89 N 44 37 E COMPUTATION DATE: 5-JAN-90 PAGE 2 ARCO ALASKAt [NC. 2K-10 KUPARUK NORTH SLOPEr ALASKA DATE OF SURVEY: 30-DEC-1989 KELLY ~USHING ELEVATION: 154.00 FT ENG[NEER: WEST/FR[TZ'KE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED D~PTH TRUE SUB-SE~ COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG M[N DEG MIN VERTICAL DOGLEG RECTANGULAR CgORDINATES HOR[Z. DEPARTURE. SECT[ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZ[MUTH FEET OEG/IO0 FEET FEET FEET DEG MIN 4000.00 3799.85 3645.$5 29 4100.00 3887.99 3733.99 27 35 4200.00 3976.68 3822.68 27 27 4300.00 4065.45 3911.45 27 25 4400.00 4154.23 4000.23 27 19 4500.00 4243.15 4089.15 27 10 4600.00 4332.12 4178.12 27 8 4700.00 4421.14 4267.14 27 5 4800.00 4510.71 4356.71 25 24 4900.00 4601.42 4447.42 24 35 N 41 15 E 812.28 N 41 55 E ~)59.48 N 41 51 E 905.67 N 41 45 E 951.71 N 41 29 E 997.71 N 41 13 E 1043.64 N 40 56 E 1089.07 N 40 36 E 1134.60 . N 39 25 E 117B.98 N 38 45 E 1220.97 2.67 0.03 0.10 0.00 0.32 0.00 0.17 0.30 2.37 1.12 580.49 N 568.50 E 812.50 N 44 24 E 615.79 N 599.86 E 859.66 N 44 15 E 650.19 N 630.69 E 905.82 N 44 8 684.52 N 661.39 E 951.84 N 718.91 N 691.95 E 997.81 N 43 54 753.26 N 722.18 E 1043.52 N 413 48 E 787.67 N 752.18 E 1089.13 N 43 41 E 8.22.17 N 781.95 E 1134.64 N 43 34 E B56.16 N 810.58 E 1179.00 N 43 26 E 888.89 N 837.05 E 1220.97 N 43 17 E 5000.00 4692.97 4538.97 23 4 5100.00 4785.64 4631.64 20 41 5200.00 4879.62 4725.62 19 20 5300.00 4974.78 4820.78 16 35 5400.00 5070.79 4916.79 15 26 5500.00 5168.04. 5014.04 11 52 5600.00 5266.15 5112.15 10 7 5700.00 5364..70 5210.70 9 4'7 5800.00 5463.20 5309.Z0 10 0 5900.00 5561.83 54.07.89 7 41 N 38 19 E 1261.06 N 37 35 E 1298.46 N 38 10 E 1332.50 N 42 28 E 1363.13 N 43 26 E 1391.09 N 41 44 E 14.14.29 N 40 9 E 1433.58 N 38 53 E 1450.52 N 38 39 E 1467.74 N 34 4 E 1483.70 0.92 2.80 2 1.20 3.79 1.02 2.20 0.42 0.86 3.71 920.35 N 862.11 E 1261.06 N 43 8 E 94.9.97 N 885.19 E 1298.46 N 42 59 E 976.98 N 906.14. E 1332.51 N 42 51 E 1000.45 N 925.89 E 1363.I5 N 42 4.7 E 1020.85 N 9,~5.00 E 1391.10 N 4.2 4.7 E 1037.87 N 960.77 E 1414.31 N 42 4.7 E 1052.45 N 973.43 E 1433.60 N 42 46 E 1065.58 N 984.19 E 1450.55 N 4.2 44 E 1079.03 N 995.01 E 1467.77 N 42 41 E 1091.81 N 1004.72 E 1483.74 N 4.2 37 E 6000.00 5661.13 5507.13 6100.00 5760.43 5606.43 6200.00 5860.25 5706.25 6300.00 5960.18 5806.18 6400.00 6060.11 5906.11 6500.00 6160.04 6006.04 6600.00 6259.98 6105.98 6700.00 6359.92 6205.92 6798.00 6457.85 6303.85 7 9 5 19 2 12 2 10 2 4 I 55 I 58 2 2 2 2 N 31 25 E 14.95.82 N 33 31 E 1507.31 N 36 21 E 1513.05 N 34 57 E 1516.85 N 24 22 E 1520.53 N 26 59 E 1523.97 N 23 34 E 1527.18 N 24 27 E 1530.51 N 24 27 E 1533.81 0.14 5.44 0.17 0.26 1.23 0.00 0.43 0.00 0.00 1102.26 N 1011.29 E 1495.89 N 42 32 E 1112.19 N 1017.49 E 1507.40 N 42 27 E 1116.91 N 1020.85 E 1513.15 N 42 26 E 1120.02 N 1033.08 E 1516.95 N 42 25 E 1123.17 N 1025.10 E 1520.63 N 42 23 F 1126.4.5 N 1026.63 E 1524.09 N 42 21 E . / 1129.51 N 1028.05 E 1527.31 N 42 lB E 1132.76 N 1029.4,6 E 1530.66 N 42 16 E 1135.93 N 1030.90 E 1533.98 N 42 13 E COMPUTATION DATE: 5-JAN-90 PAGE 3 ARCO ALASKA, INC. ZK-IO KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 30-0EC-1989 KELLY BUSHING ELEVATION: 154.00 FT ENGINEER: WEST/FRITZ'KE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED OEPTH TRUE SUB-SEA COURSE ME&SURED VERTICAL VERTICAL DEVIATION aZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE. SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEE MIN 0.00 0.00 -154.00 0 0 N 0 0 E 0.00 1000.00 999.99 845.99 0 21 S 10 1 E -1.33 2000.00 1999.98 1845.98 0 13 S 51 18 W -5.68 3000.00 Z933.84 2779.84 29 32 N 43 40' E 312.38 4000.00 3799.85 3645.85 29 1Z N 41 15 E 812.28 5000.00 ½692.97 4538.97 23 4' N 38 19 E 1261.06 6000.00 5661.13 5507.13 7 9 N 31 25 E 1495.82 6798.00 $457.85 630~.85 2 2 N 24 27 E 1533.81 0.00 0.06 0.72 0.40 2.67 0.92 0.14 0.00 0.00 N 0.00 E 0.00 N 0 0 E 3.28 S 1.56 E 3.63 S 25 28 E 7.84 S 0.07 E 7.8,4 S 0 33 E 209.61 N 233.21 E 313.56 N 48 3 E 580.49 N 568.50 E 812.50 N 44 24 L 920.35 N 862.11 E 1261.06 N 43 8 E 1102.26 N 1011.29 E 1495.89 N 42 32 E 1135.93 N 1030.90 E 1533.98 N 42 13 E ARCO ALASKA, INC. 2K-10 KUPARUK NORTH SLOPE~ ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN COMPU'TATION DATE: 5-JAN-90 PAGE 4 · DATE OF SURVEY: 30-DEC-i989 KELLY BUSHING ELEVA. TION: 15.4o00 FT ENGINEER: WEST/FRITZ'KE INTERPOLATED VALUES FOR EVEN 100 FEET DF SUB-SEA DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE. SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0o00 0.00 -154.00 0 0 N 0 0 E 0.00 0.00 O.OO N 0.00 E 154o00 154.00 0.00 0 9 S 47 5 E -0.31 0.00 0.22 S 0.22 W 254.00 254.00 100.00 0 13 S 53 26 E -0.27 0.00 0.41 S 0.04 E 354.00 354.00 ZO0.O0 0 14 S 50 49 E -0.24 0.00 0.67 $ 0.36 E 454.00 454.00 300.00 0 14 S 51 20 E -0.21 0.21 0.91 S 0.6,8 E 554.00 554.00 400.00 0 14 S 35 24 E -0.24 0.11 1.20 S 0.94 E 654.01 654.00 500.00 0 14 S 23 17 E -0.34 0.00 1.56 S 1.17 E 754.01 754.00 600.00 0 17 S Z1 43 E -0.53 0.08 1.99 S 1.34 E 854.01 854.00 700.00 0 18 S 8 47 E -0.82 0.30 2.48 S 1.46 E 954.01 954.00 800.00 0 19 S 1 33 E -1.16 O.OO 3.02 S 1.53 E 1054.01 1054.00 900.00 1154.01 I154.00 1000.00 1254.01 1254.00 1100.00 1354.01 1354.00 1200.00 1454.02 1454.00 1300.00 1554.02 1554.00 1400.00 1654.02 1654.00 1500.00 1754.02 1754.00 1600.00 1854.02 1854.00 1700.00 1954.02 1954.00 1800.00 0 19 S 4 15 E -1.54 0.14 3.5B S 1.57 E 0 18 S 6 1'7 E -1.92 0.03 4.12 S 1.60 E 0 17 S 5 13 W -2.29 0.00 4.62 S 1.58 E 0 16 S 3 37 W -2.68 0.20 5.10 S 1.54 E 0 16 S 9 57 W -3.06 0.08 5.57 S 1.48 E 0 15 S 11 24 W -3.44 0.22 6.02 S 1.41 E 0 15 S Z1 52 W -3.80 0.15 6.40 S 1.28 E 0 17 S 35 14 W -4.25 0.26 6.80 S 1.05 E 0 20 S 40 27 W -4.80 0.27 7.24 S 0.71 E 0 21 S 51 55 W -5.44 O.Z1 7.69 S 0.27 E 2054.02 2054.00 1900.00 0 52 2154.35 2154.00 ZO00.O0 7 43 2256.01 2254.00 2100.00 12 40 2359.63 2354.00 2200.00 16 3') 2464.68 2454.00 2300.00 19 35 2571.99 25 54.00 2400.00 22 26 2681.82 2654.00 2500.00 26 58 2795.02 2754.00 2600.00 28 10 2908.51 2854.00 2700.00 28 39 3023.17 2954.00 2800.00 29 32 N 41 46 E -5.58 4.97 N 60 14 E 1.38 6.17 N 57 24 E 18.76 5.58 N 54 12 E 45.19 0.93 N 49 35 E 75.91 5.10 N 45 O E 115.68 1.59 N 43 26 E 161.01 4.14 N 43 18 E 214.05 0.50 N 43 22 E 267.70 1.83 N 43 33 E 323.80 0.44 3138.20 3054.00 2900.90 29 45 3253.54 3154.00 3000.00 30 0 3369.10 3254.00 3100.00 30 9 3484.78 3354.00 3200.00 30 11 3600.53 3454.00 3300.00 30 15 3716.19 3554.00 3400.00 30 6 3831.75 3654.00 3500.00 30 4 3947.26 3754.00 3600.00 29 58 4061.63 3854.00 3700.00 27 42 4174.44 3954.00 3800.00 27 29 N 43 14 E 380.64 0.32 N 42 46 E 438.12 0.24 N 42 26 E 496.04 0.24 N 42 3 E 554.20 0.18 N 41 41 E 612.46 0.20 N 41 22 E 670.57 0.13 N 41 13 E 728.45 0.00 N 41 8 E 786.23 0.30 N 41 46 E 841.68 0.80 N 41 52 E 893.89 0.19 0.00 N 0 0 E O. 31 S 44 3 W 0.41 S 5 17 E 0.76 S 28 37 E -, 1.14 S 36 32 [ 1.53 S 38 0 E 1.95 S 36 59 E 2.40 S 34 4 E 2.88 S 30 26 E 3.39 S 26 55 E 3.91 S 23 43 E 4.42 S 21 11 E 4.88 S 19 53 E 5.33 S 16 46 E 5.76 S 14 53 E 6.18 S 13 9 E 6.53 S 11 19 E 6.88 S 8 46 E 7.27 S 5 36 E 7.70 S ! 59 E 7.72 S 0.09 E 7.72 S 0 42 E 3.83 S 6.12 E 7.22 S 57 59 E 5.34 N 21.75 E 22.40 N 76, 12 E 20.79 N 43.94 E 48.61 N 64 41 E 40.45 N 69.36 E 80.29 N 59 45 r 67.06 N 97.66 E 118.47 N 55 31 99.61 N 129.2.2 E 163.15 N 52 22 E 138.19 N 165.62 E 215.70 N 50 10 E 177.27 N 202.39 E 269.04 N 48 47 E 217.88 N 241.09 E 324.95 N 47 54 E 259.20 N 280.13 E 381.65 N 47 13 E 301.21 N 319.34 E 438.99 N 46 40 E 343.85 N 358.55 E 496.79 N 46 12 E 386.91 N 397.65 E 554.82 N 45 47 E 430.31 N 436.54 E 612.97 N 45 25 E 473.84 N 475.07 E 670.98 N 45 4 E 517.36 N 513.27 E 728.77 N 44 46 E 560.87 N 551.34 E 786.48 N 44 31 E 602.53 N 587.97 E 841.87 N 44 18 E 641.41 N 622.82 E 894.05 N 44 9 E COMPUTATION DATE: 5-JAN-g0 PAGE 5 ARCO ALASKA, INC. ZK-IO KUPARUK NORTH SLOPE, ALASKA DATE OF SURVEY: 30-DEC-1989 KELLY 5USMING ELEVATION: 154.00 FT ENGINEER: WEST/FRIT,ZKE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SE~ DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE. MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST gIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN 4287.10 4054.00 3900.00 27 25 4399.74 4154.00 4000.00 27 19 4512.19 4254.00 4100.00 27 11 4624.58 4354.00 4200.00 27 7 4736o86 4454.00 4300.00 26 50 4847.B0 4554.00 4400.00 24 50 4957.56 4654.00 4500.00 23 34 5066.04 4754.00 4600.00 21 413 5172.83 4854.00 4700.00 19 51 5278.28 4954.00 4800.00 16 58 5382.56 5054.00 4900.00 15 56 5485.65 5154.00 5000.00 12 4 5587.65 5254.00 5100.00 10 25 5689.15 5354.00 5200.00 g 44 5790.66 5454.00 5300.00 10 0 5892.04 5554.00 5400.00 .599Z.82 5654.00 5500.00 6093.54 5754.00 5600.00 6193.75 5854.00 5700.00 6293.82 5954.00 5800.00 6393.89 6054.00 5900.00 6493.96 6154.00 6000.00 6594.01 6254.00 6100.00 6694.08=~%i6354.00.:~200.00 6794 I 6454 0 '7' 6300.00 6798]0 6457]8 6303.85 7 58 7 B 5 39 Z 13 2 10 Z 3 I 56 1 57 2 Z 2 2 DEG MIN FEET DEG/IO0 FEET FEET FEET OEG MIN N 41 46 i5 945.77 N 41 29 E 997.59 N 41 1Z E 1049.00 N 40 52 E 1100.27 N 40 21 E 1151.29 N 38 52 E 1199.20 N 3~ 32 E 124~,32 N 37 44 E 1286.20 N 37 49 E 1323.48 N 41 35 E 1356.82 N 43 24 E 1386.36 N 42 3 E 1411.32 N 40 22 E 1431.35 N 38 54 E 1448.68 N 38 41 E 1465.12 N 34 48 E 1482.64 N 31 21 E 1494.95 N 3.3 9 E 1506.71 N 36 20 E 1512.81 N 35 7 E 1516.62 N 25 29 E 1520.32 N 27 4 E 1523.78 N 24 6 E 152,6.98 N 24 27 E 1530.32 N 24 27 E 1533.68 N 24 27 E 1533.81 0.02 0.32 0.06 O.Og 1.26 0.56 1.60 3.33 0.85 2.55 6~0.09 N 657.43 E 945.91 N 44 2 E 718.82 N 691.88 E 997.69 N 43 54 E 75)'.45 N 725.85 E 1049.09 N 43 47 E 796.14 N 759.52 E 1.100.33 N 43 39 E 834.88 N 792.79 E 1151.32 N 43 31 L ) 871.88 N $23.37 E 1199.22 N 43 22 E 907.19 N 851.67 E 1244.32 N 43 12 E 940.22 N 877.63 E 1286.20 N 43 2 E 9,69.85 N 900.55 E 1323.48 N 42 53 E 995.74 N 92.1.69 E 1356.83 N 42 47 E 2.26 1.41 2.41 0.45 0.7B 4.41 0.38 5.27 0.42 0.36 1.30 0.00 0.17 0.00 1017.42 N 941.76 E 1386.38 N 42 47 E 1035.65 N 958.79 E 1411.33 N 42 48 E 1050.75 N 971.98 E 1431.37 N 42 46 E 1064.14 N 983.03 E 1448.71 N 42 44 E 1077.77 N 993.99 E 1466.15 N 42 41 E 1090.92 N 1004.11 E 1482.68 N 42 38 E 1101.50 N 1010.83 E 1495.01 N 47 33 E 1111.68 N 1017.15 E 1506.79 N 42 27 E 1116.72 N 1020.70 E 1512.91 N 42 26 E 1119.83 N 1022.95 E 1516.72 N 42 25 E 1122.97 N 1025.00 E 1520.43 N 42 23 E 1126.27 N 1026.54 E 1523.90 N 42 Z1 E 1129.32 N 1027.97 E 1527.12 N 42 19 E 1132.57 N 1029.37 E 1530.46 N 42 16 E 0 00 ,?,/,I135.80 N 1030.84-..E 1533.85 N 42 14 .~ 0;00 ' , 135.93 N 1030.90/E 1533.98 N 42 13 f- ) COMPUTATION DATE: 5-JAN-90 PAGE 6 ARCO ALASKA, INC. 2K-10 KUPARUK NORTH SLOPE9 ALASKA MARKER 9 5/8" CASING TOP KUPARUK C B~SE KUPARUK C TOP KUPARUK A BASE KUPARUK A GCT LAST READING PBTD 7" CASING 79 DATE OF SURVEY: 30-DEC-1989 KELLY BUSHING ELEVATION: 15~.00 FT ENGINEER: WEST/FRITZ~E INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 71' FSL & 94' FEL, sECZ TION RSE MEASURED DEPTH TVO BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 3000.00 Z933.84 2779.84 209.61 N 233.21 E 6444.00 6104.08 5950.08 112~o68 N 1025.76 E 6451.00 6111.07 5957.07 1124.92 N 1025.87 E 6677.00 6137.05 5983.05 1125.75 N 1026.Z8 E 6602.00 6261.98 6107.98 1129.57 N 1028.08 E 6672o10 6332.03 6178.03 1131.$6 N 1029.05 E 6724.00 6383.90 6229.90 1133.56 N 1029.81 E 6789.00 6648.86 6296.8.6 1135.66 N 1030.77 E 6798°00 6657.85 6303.85 1135.93 N 1030.g0 E ARCO ALASKA, INC. ZK-IO KUPARUK NORTH SLOPE, ALASKA MARKER TOP KUP~,RUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TO COMPUTATION DATE: S-JAN-gO PAGE 7 O~TE OF SURVEY: 30-DEC-~989 KELLY ~USHING ELEVATION: 154.00 FT ENGINEER: WEST/FRIT~E SURFACE LOCATION = 71' FSL & 94' FEL, SECZ TION RBE TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MEASURED OEPTH BELOW KB 1124.68 N 1124.92 N 1125.75 N 1129.57 N 1133.54 N 1135.93 N 1025.76 E 1025.87 E 1026.28 E 1028.08 E 1029.81 E 1030.90 E 6444.00 610~.08 5950.08 6~51.00 6111.07 5957.07 6~77.00 6137.05 5983.05 6602.00 6261.98 6107.93 6724.00 6383.90 6229.90 6798.00 6457.85 6303.85 FINAL WELL LOCATION AT TO: TRUE SUS-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 6798.00 6457.85 6303.85 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 1533.98 N 42 13 E SCHLUMBEROER O I RE C T I ONAL SURV E Y COMPANY ARCO ALASKA, INC. NELL 2K- 10 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED 30 - DEC - 89 REFERENCE ?3628 _- 2K-lO ~' FSL, 94' FEL, SEC 2, '~ ,ON, R8E, UM) ~'~RIZONTAL PROJECTION NORTH ! 400 REF '7962~ $CRLE : 1/200 IN/FT 2OO 1000 800 6OO 400 200 NEST -200 2OO 400 600 8OO 1000 1200 1400 EP:IST &. 2K-lO F Si, 94' FEL, SEC 2, ~ON, R8E, UM) -~-?RTICAL PROJECTION 22:3. - ! 000 -SO0 0 0 SO0 1000 ISO0 2000 2500 3000 43. m SCALED IN VERTICAL OEPI'I'~ HORIZ SCALE : 1/SO0 IN/FT Pl II PROJECTION ON VERTICAL PLANE 43. - 223. ,, i AOGCC GEOLOGICAL MATEFIIALS INVENTORY UST ! check off or list data as it is received ] '.o; ! ~/--'~'/~o drillin§ histo~/' su~ey I ~ ~" tests I ~re desri~tionl cored inte~ls ~re anal~is d~ ditch inte~ais digital data LOG TYPE RUN INTERVALS SCA~_E NO. i i /, I -- ~" ,, i ARCO Alaska, inc. Date: June 22, 1990 dUN 2 G 1990 Transmittal g: 7793 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. signed copy of this transmittal. 1Y-30 1L-10 2K-10 2C-13 Pulse Echo Cement Evaluation Pulse Echo Cement Evaluation Tracer Chek Experimental NORM Tracerscan Please acknowledge receipt and return one 6-5-90 8345-9164 5-31 -90 7087-9122 6-2-90 6350-6555 5-24-90 6895-7075 Receipt Acknowledged: Date: DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) (' WEll: ') K -I ~ TUO l' PERFS: tl71 , ~D" PERFS: 6512 HOLE ANGLE l' PERFS: / f7 SA~" P£R' I~T£RIJAL A b š/2 - 1- 7 .' ~ \ ~ C>)> (>I, 2.00B dïGk~\N\ED ,j~,N ~ Q:» ACTUAL UOLUME ~ flUln STG/LU~ !rt.-!4~ JLJS. QL _I ) (,S- Ilk. ~ RÞJ( ~ --- _I J'f- þh.ft IS/I' 12~o1 ~ _I ro -" ,...¡-J.. ~ f/Â Â. IJJJL I , ~I /~O() - 2,tÎ: ~ 1/ J..LL.I / JI/ <I-¥ -L!.- J.1L¡/#Z ~þ! /,,'1' ~ J.5L/ /513 ~ 'I --12-1/7t;J - 1)# IJ ;;26 ~ --3.L/ I j7 S} I). j:, ~I 1'7.3 51ft., þJL Rw;~ /3:34: _/ ..s:LI/9'10 5/l 1£1.2 _I -' EFF. PAD: /" 00 J,LJ{ 1A tl.II WHTPR: 1 ISIP: 1 LEAK OFF: ([",) olr' S'tC)3~) NOTE 5: Pr! - ~) ) f/ l~'" ( 5 MIN. /13 ~ (' 8, 1 2 ,.., r- / '-" ./ . :): _ A 7" ; - IV f f-.. - c ~" ~ . tu:1/Z' ICUPARUIC STIMULATION SUMMARY "> DATE: 6 /1 /1/7 CONTRACTOR: PS . ; 1/ ARC a REP: ST¡?ßloA//tJi../E,V//f.V6L.- AFE It: AK3b~O COMPANY Typr OFNSITY PHASL~; !lL{ I II D 11 (¿.J,'''J 4- 5/'1 I/J J& v p/ "){11Y elf Alt~,...t"~ o E 51 C RAft PRESSURE PROP. PROP. A~N, UOLU ~ 1.~IT/~lQ ~ CQ~r. JlLL PRESS. lli.2 / -J.'J- SZfl 1 I-/~IJ .2V!?- '36 ç- l 2L 1211!.J .f(;oo Jóo 0 .2:-J _I _I ~ 3ts"o I fJ..30 3ð~' /,too / .lL. iliE..I4Oð I /( /2() ~.2 9.JSo !.æ-I 2.L 575/13?1/ / ~ /20 .0 jf?7;;q 7»/ /~/ :. ')- 3?n I }(5? / I (0 ;)0 93 :.:); } 1:::_.., .1.£. '5662 / YS4J' /6/2,) 7.r 4 /.7 ] 7 - ,) ..'.L..,I 1-1...2-, ' 2.L 221..1 ]h()(. '2f? /o.~ J()~O !1t2-1 ~ ~()oo 1 11. It JI. "'5 - k-/ J.±.. _I -, _I J:L.¡ _I -, -' -' EFF. SLURRY: 67] ¡j,& EFF. PROP: l]ð¡/6] ~..'". 1D. fllI . 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IO,'4Ç II : 4-0 ¡JT Td rooo II : ff)' fJ(.1 ; h ?r<- ~ ßA 12 ',If ß~1; '" PaÁ I) lab 8(,; " :J.tI IJ:ý(J Cv..+ fd ¡(kJ~ 1>',3~ f { t.S h ç7 b~IJ I S I LJ fI (J ;or I 4-0 () fJ S /' /fJP ~"yl'J I (~~ fr(. -r.., ,.~¡J(J;rt I I j bblJ S/'oy-f ðt- f~rf j, I c) ........ ,/-~ ,1.. \.,/ \'" ) , / .. / { ( FRArTIIRUTIMllungN FIl:l n rAI rill ATI nNS WELL: 2 K-( ð EN&R. REP: 5T~ß7iOU¡ÍðvE# DATE: FOREMAN: t /1 /90 AA/{,I- E #' 11JF" , nATA: ,~D TBG TAil: .~D TO PERFS: TUD TO PERFS: (,?71- 6 )"/ 2, 6/72 ,4-3 ,7() FLUSH UOlUME · FRRC fLUID GRAO: ASSUMED fRAC GRAO: FRAC fLUID TBG fRIC: I?~f<. ¡Ç 10 25 YF) +0 ïK ¡¡;;- /30 S/}< :ßL /65 235 3~? (TI' Ill/")-(MD Tla TAil) .. (CS& 18l/")-(MO TT to TOP PERf) - (IllS UNO£RFlUSM) (,00'17)( 6]71) -f- (.0382'f13i)- 2 - S-7uls PSI/FT PS t " FT PSI/fT 1. C~lr"tATt "lIlSN unLUM' flUSH UOlUME · 2. CRLrJ'LATt £HPrrTfft fUrl LHrl1 TlltlTINa ""sultrJ {1t1K1pr1: SIfT, · (A..um.d frle Gred)· (TUD to ,.rfl.. 4- 3.1 0 PSI Tbg FMe· (Tbg Frle LOIs) · (MD Tbl Till) iQ.. . Joo Hydrostltle'rlslur. · (Fluid SAd)· (,TUD) WHT'£ · SHT' .. P(tbg (Me) - Hyd' 3. P~[ - ,~" / ISIP C~LrtlLATlaNJ~ · 114-7 j}JL - I q I 2 · :2 tsf 21"IJ PS I PSI PS I · WHT'... 3 S- /0 PSI (ftctuII WN1P I.forl SO for ISI'. I S I' ;2.3ff PSI ,]ç-r- :214+--ISI' ACTUAL FRAC GIIOIENT · (Fluid Inen 6t7L. ------ J ¡J'o 2J +/--. TVD -. EHCESS FIICTION · wm. - ISI' .. TlI FIIC . /1/2. . .73 '0 . P S II FT PS I 4. pðrr FUr rlt ral..TIINt: ;2.1.) ~ff1 wml. '5 §] 0 'SI (IIctue' WHTP ..for. SD for ISI') ISI' . 217~ 'SI })"4- 2/7)" ISI' ACTUAL FRIIC 6"~DIEN' · (rtúl4 Snd)" ------ b/7Z- TUD ... E H C E S 5 F R I CTI 0 H · Win? tI - IS 1 , - n, F R I C . J)"Jo - 2/7rJ - /721 /7/ o . PSI / FT PSI I ... If [HCESS FRICTION IS lESS THAN SOO 'SI. THEN PROCEED WITH fRAC ... IF EHCESS t;\ICTION IS IIIITtI T1fIN 500 PSI. CHICIC 1'01 IISTlICTIONI aPERIIT10NI EN8IN[ERINI FRACTURE TREATMENT QUALITY caNTROl CHECIC liST o ATt: b ! I If 0 WELL: 2r-lfJ ENG I N( Eft: fTR AT 1;) AI F'OREMIIH: ¡4~6L E# / CONfiRM ON lOCATION flUID UOlUMES/TANIC STRAPS OR EQUIUAlENT r'o1ETHOO: TANir . 'afT PPlIMI ,. a IT L1l! I I I' UllI JOI £ltI JOI u..1U )(~ ßfr~cL~J ST" ", us ~ (TI.. C OM' I" tsaJllfs TANK STIt", UOl UMI · OEUIATlON M£TERED UOlUMI - SANG UOLUMI ·1.. rUI OlfFEIUNTll1l V ,,,(_ Joe IlL QUillin Tlnl ca.-.'lrna "HI WI~IIIII ~E11"lEØ FLUID COM'OSITION NOTtD: t..,./" FLUID SAMPLES EHRMIN£D/TAICEN: /'PRO"flNT [>eRMINID, S"M'l£S TAKEN v--- UISUlll ""I'''I'',..CI OF GELLED flUID: HO...OIINGUI mllþlte, OntEII V;"FtTV MIni....: ME£TIÞ~' 'lllCI DISI'HITtD SHOULD CIIT"snO'HIC fAilURE OCCUR. O'TlaNS I' WILLI S1""t TO SCJlltH OUT. O'TI aNI I' '''"C TRtATINI "t(SSU..IS ""1 TOO HIGH. / flOW MrnJlS, Q[NSlTaMrnJlS, 8ND '''[SSURIINS~UM(NTS fUNCTIONING. i...-/ CU....ENT ,,,oCEDURe CHICKID "HO DISCUSSED Wlnt D.S. su,t"UISOR ANO CONTRACTORS (EU£JI't'ONI waRKINt WITH SIIMI PROCEDURE) BACKU' EQUIPMENT ON lOCATION / I /" CH[CIC Wlnt '(..Ulel COM'IIN., TO COHI"I... IR(AICIR TlMIS PRE fl"'C lOIS R(QUIR(D POST fRAC lO'S "(QUIR£D COllECT FlllD CO" 'OR 'tiCkET: THEATtJlS lOt STIli' CH""T SANa CH"IT T.~( ST..' .. þI4£T11 CI)II4PIRISIN '.r .ELL ;"(-/1 ..11 {/J/IJ ,." .IIHI T~C. C1J«OOS smA, /. . (;c-J (1'1 2. tj" 'J I ' f ///1 r- V' 1// iQI'Rl ÇTIAF'ED U'l~..._._...._._._--- .-. JOLIME :if f40 4-fÇ +~~ 1740 ¡ttn 151. ~~I: . sr~'·~ I J'$"II 1. J'4-" l I' 4- /1 5' "I' TOrAI. m.,£1 .'ME - å ruiN M£ItI- ~ JilT' ~En:. · MutA R[~ INGS ct[~ 11m UOl'~[ 1 t:t f) 5ðcJ 4-ð- f) 44) f).ç IOJ ~ ç- C~D41S . ( / )::. P f L ..." (J 0 h -bl ( CtJ~M[N1S /,.) Jj/¡ ¡:Lß Ç1 ¡'~/r !);.( J).JL 3Gf4- ð $DIPS . 30S r )"2. f- t7 .::; J ì 1- åSTI"" ðCl ~ MmR - r-::::7 ~~I billllV M[1tI- J 74--IJ &f?- =-LJjj .IIM& '.. MnD R[IIJ lNG' TRNC . STM'·. ...IM[ Cl[~ 11m aJMMIN11 ;'OT1l. m.,tIIŒIM[ · ~cua~~· ~ JilT? HETtI · ð m.. · ~.'/~lffiN MrnH- âSTItPSl àl] IN ~ · 1M.' Mill! ~no A[RIJ INliI !'ØNC . STMp·. JOl'~( CU" IIRn ¡tIN. ~..,(. ...1£. b cu.~ M[1tI. b (JIlT' MElD- CQMM[NtS ð STA" - ðS1I."ðtl£AN MrnR- ðS1I'-'l allllY M[1tI - ~no A[RIJ INiI S~'II .. JOllf-4( W" 11m 71h ~1 7' 5'1 I,f j' )11 ~ f 7'JI/ 77 ]'J/I 77 Tlt'II. 511.,[1101.1...£ -'15'1 SRNI &Q. - J J 0 I 'J Las I q S-~ laS/ail· /37 ~ ClIIN M(1tI . SlNJ UIl . .~srJOM ..nlllS · - à aim Mmll- ÇANO 001 · rlr ~ P.... - IT"1I..nII T~C· cn~MIN1S 57 +- S-L /7 T 77..... J/I< ¿)JL- fLA PSI- 113 (}f ]91- -;. J.3.Â4- ð m.. - ;;2.40- JSJ = l(ó7 c;w /37 C L Àm..1 ðtl ~ M£1tA . I r) Cf ) / k /-'Ii ÃS1IIPl/&ØII1YMmI- 91 ;;A . I . -I _I 1 WATER GEL ac w'ELL J /< -10 _ ~'.' VENDOR D5 D~ TE ,// /90 SYSTEM Yf J,4-0 A~CO REP srli'A T10Al SERVICE CO REP){, CtCJ/rhdh I. ~ROPPANT MESH /bD) SAND/QR8õldE SAMPLE Jr MESHsCRfEN SI ZF 1.. COMMENTS 5 r; "'fIe ~ k eÞ1 2. NA TER SOURCE FIL TRATION .1 ' [. ..J. (fiF-/ r'/~~:.Jd./er / () ¡,<';c. ron 3. LAB TESTS W / ,JOB WAfER: VORTEX CLOSURE Iill BATF: X-L!NKF~J~CT /ßRFAKER OR BRFAK TlMf COMMENTS P AD GEL SLURRY GEL BREAKER OT'-jEQ ! ~FO' 4. SASE GEL MIX: I /b / t.,jA FINISH GELLING JOB GAL/M~L)t. TI M ~ JI.t12. JI.t12. tœ.Q.. X I I NK c¡ ~{)O 100 t ..1:2- .1 TANK 1Z m -r ±~.' ~~ - .: 1::,-" VISUAl APPfARANCF /COMMFNTS ( /('It '-, , '1 1/ /;.;..1< s (,¡V,h--<.. ( j;:..., ,¡, ¡:. ( J, (. 'J ~ .s I!": C ' I J I ) wi ho -.r- S. L1 NEAR GEL DATA: TANK TIME ~MPlE FANN 35 READINGS ~ ð RPMS 1Z T ~ ~ TED lIt1£. Qtl Q.Q.Q. 3.Q.Q. 2f9. J..Q.Q. --i- l -1-.1 '1¡';'} (~J ~ 11 ji it it 1= +- 3 ~ 11- 3J 1£ 2:.2- S- ..L +._ 11: B 1t jt * * + 1= COMMENTS / ,/1 , J ;;L )0 b«1-. :)'1/ r"..A ,'1 ..... .-- .., " ) " i ~A 9. NOTES: 6 Jtf I /~j' J ;; ,,1 '. ./jr FLUSH 1? PPA , 0 pp" 8 PPA 6 PPA 4 PPA ? PPA PM P RE:.,- =W. AGE IN HOURS '. -, ô. GEL BREAK TIMES -- -- -- ì ' -, ,- - T1L. -li':-.!- / .~ E- -L- tJ /{ ,ðf-j/,f7/',J .L .~.~~ //-;:" ;' - ..:...:...:D... - / r-l - qç 1.:2- - 'i )-,J. 7/,; V-I.- I) .' )D .L -L I I CJ-r:'1 / jJ~'.: - ./ 7, CROSSLINKED SLURRY GEL DATA ...........................................................PPA USED IN TESTING. /2 C ,J '1P ðf/ / ~ . T^~~( SAMPLE XLlNK ACi VORTEX LIP (f # I.Et1f. ill:1f. BAlE. RATE ..oli. CLOSURF ..lL OF' DJ:SCRI PTION/COMMFNTS GEL DE~RIPTON/CÛMMENTS /ððJ:(" r":>.::.i ~J"~ /j)} r; ;/ ~---J- J (.hA ' ~.J if ~1'1,¡,~ "þ~".j. .r'~,,", ~~j,I';'Uf'''';:''d~ VI(J .po tJ,A air /"ú ~/,,. r-//ð.;l /tr J ;'.;." . /"~ -}-. rL ,; A;¡ /;fJ;)) _.cl/'-t -,of 14 . TANK SAM P L E XLINK ACT YORTEX lIP~ # I.Etl. m BAIT. a&E. f1- CLOSURF ...£I- I Jlil.- . S ..l -L 1..l / s~( ~ -2- ~ 'f;çs- ..:L 1- _ /(ð/, ~ .L ~ I!l.:.& .L ,/,2.. I' ~ .L IU!!- .L I 1!L II !ð /1 ...L !11:- !(},'/Ç L .L 'U- ,I I I I 6 CROSSliNKED PAD GEL DATA........,.., ..................................................................PIPE TIME (PT) = ARca REP 5' T¡f ¡17TO)/ SERVICE CO REP h. Cj,~P,tlh VENDOR 0 f SYSTEM rf24-o 'NELL Î K-I ø :'~. DATE ell/90'" WATER GEL ac { ( - - ~ = -. :~ ¥~ . --- ~..:.: :~~ ~ ~ : '" ~'::';:I ,/ =::·G? ~~ ': -l __ .. ,1-,: ::0'.....; --~ ------..... _ ,- .::: '.'ì -:' -......,> - -- ARCO AI..kl, Ino Date: May 22, 1990 "Ie Cod.: Well File: ...~ "',.. 2K-10 Interna' Corr..pondlnc. Subject: Kupsruk Well 2K·10 Initial Fracture Procedure From/Lac.tlan: A. J. Bond ATO-1186 relephone: 265-6849 To/Lac:atlon: P. J. Archey ATOw1448 Attached Is the fracturing procedure for KRU Well 2K-10. Well 2Kw10 Is a 3·1/2" single completion which is nearly vertical across the Kuparuk interval. Radioactive tracer taQQinQ and post-fracture logging Is recommended to take advantage of the straight wellbore. The proposed fracturø treatment consists of a , 200 bbl pad and 710 bbl slurry of Dowell's YF240 gelled water frac flurd, containing 99,000 pounds of 16/20 Carbo-Lite and 46,000 pounds of 12118 Carbo-Ute as a tail·ln. The treatment Involves \hQ following vendors: ~8rvir.. ('Á\~"Y ~ontAr.t Pumping Service, gelled Dowell fluld(YF240) Chuck Miller 561-1324 Electric line unit, Tr2!cerscan HLS IOQ with !emperatu re tool Mike Walker 261-7730 Radioactive tracers. injection Pro- Technics pump Petr9dat Pressure Gauge Petredat Larry Taylor (713)496-3734 Bob Allen 561..2107 The purpose of the radioactive tracer tllgglng and temperature logging as well as the downhole pressure gauge Is to determine the following fracture parameters; 1 ) Fracture initiation pressure 2 ) Fracture closure pressure 3 ) Tubing friction during pad and slurry staoe$ 4) F'ropped height snd total fracture height 5} EffectIveness of oriented perforations Pro-Technics must be given suffIcient lead tlme(approximataly one week} to provide them enough time to ship the radioactive tracer material in the correct amounts. The Safety and Training Department has been made aware of the radioactivQ tracer portion of thi3 procedure and will be provldlno any necessary feedback in regards to that part of the fracturing program. ~ A&aMa It\c. II . .~...., ~ Att..-.c ,,~~ ..~,~..... { ( ~'··~'/-2:-· =2 .=.~ ~~: -22 :::.. _r=':'¡:'_r< =.~.:~? ..~~~ P. J. Archey May 22, 1990 Page 2 =- ~.,:: ~~~ ~~: -"-- =:-::~ =~: If you have any questions or comment'. please contact me at the number above or Mark Pearson at 265-4166. c:Z-L }. ~ OperaHons Engineer Attachments 00: J. R. Brandstetter M. E. Eck C. M. Pearson G. K. Phillips O. Stota O. S. Stoltz A. RamlrezJG. Umb R. Sloan/J. Krallck B. FontenoVJ. ~obinson G. PawluklW. Carter S. Gls·ser/S. Kruse G. FordiD. Knutson T. Austln/M. Silverman O. Corry/C. Jumper O. Riffe/P. Hail .JA2- ) jJ S ßOò2..D ~~L.e:~ jfl ~ I A TO-' 1 70 ~ A TO- 1176'7'.... ATO-1100 ATO-1170 ATO-1402 A TO-' 440 NSK (Fax'd/Malled ..J~_ NSK NSK NSI< NSK(Front Cover Only) NSK(Front Cover Only) NSK(Front Cover Only) NSK(Front Cover Only) NSK by _) · -""":'" - -~ ........ (-"::'...J- -:;...:..... ::. -' -..........-.:::. : =- : ~ J' -r-'j' ::'.'iJ.;ï' ¿::~ __ 4'..J" ::.....:.... _-'.... -....._..J -- ' - - - ~ P. J. Archey May 22, 1990 Page 3 Kuparuk Wall 2K.10 wen Specification. 5/22/90 CO: AK3650 Wellhead (FMC Oen IV) SSSV (Baker FVL) GLM's(Merla 1") GLM's(Camco 1.5") Packer(Brown HB) "No Go"(Otls "XN") Tubing Tall ~ A Sand Perforations f SPF Tagged Fill(11/11/1?) peTD Maximum Hole AnQle Hole Angle Across Perfs T ublno Casing Flush Volume to A Sand Perfs TVD Depth k) Top A Sand Perf NOTe: AU Depths are MO-RKB. 5000 PSI MAWHP 1806' 233T, 4305\ 561 g' 6270' 6326' 6363' 6374' 6512'·8547' 6722' 300 @ 3600' 1 0 @ 6500' 3 1/2·, 9.3 Ib/tt 7", 26.0 Ib/ft 60.0 BBlS 81 72' Gelled Water Fracture Fluid SpecifiC8tions 1) The base fluid will be clean fresh water with 20/0 KCL added. 2) The Gelled Water FluId System which will be utilized is: Dowell Non·Delayed Cross·Unk Borate HPG System(YF240) 3) The system will be mixed at 40 Ibs of polymer per 1000 gallons fluid. The Pad fluid and initial sand stages are to include 5% diesel for leak-off control. 4) pH of cross-linked gel should be 9.5 ± 0.2 pH units. r'"Î <. 5} Biocide will be InCluded In the base fluid. '-----., 6) Breaker concentration should consist of 0.5 Ibl1000 Qal in the pad and(2 1b/1000 gal In the Slurry stages unless on-site quality control requirements dictate ô1herwisø.--- ( '·:.:.~-2:::-' :..~ .=.-J ~-::2~ :::"!_;='':'';=':_'f =:'..~? 2=:4 -~;_ '~I:: :-0·-; ~-== ...:.:~S =='==,.' .::~-=: --- -- P. J. Archey May 22, 1990 Page 4 Kuparuk Welt 2K-10 Data Frac and Initial Fractur. Procedure 5/22/90 CC: AK3650 PRF;·FRA~ ~U~K' !NF= NOTE: The pre·frac sllckline is designed to be performed 14 hours prior to beginning the fractur. treatment. The dats collection timing of the Petredat gauge must be modified If the sllckllne timing Is different. 1) M1RU Slickline. If tubing is to be displaced with dleaet prior to performing the wlrellne work, please displace with slicked diesel to prevent friotion problems during the Initial frac1ure breakdown. 2) RIH w/tublng end locator and tag fUl. 3) RIH w/standing valve and set in "XN- nipple. Standing valve is needed to insure that the Petredat gauge Is not lost downhole while being run and to pressure test tubing. , 4 ) RIH and pull DV at 8270' RKB. 5) RIH and set Petredat gauge In 1·1/Z' mandrel at 8270' RKB. Petredat gauge should be programmed to record data In the follOwing sequence. Tim 8 Period Time Increment 14 hours 10 hours Remaining Memory 1 hour 15 seconds 1 hour The time periods are set up so that the fracturing operation will begin approximately when the Petredat gauge begins to record data every 15 seconds. Amount of 1 hour sampling can be adjusted as necessary to coordinate pre-frIO sltckllne work with start-up of the fraoture treatment. S) Pressure test tubing to 3000 pal to ensure Petredat gauge is set. Approximately 1000 psi must be placed on the annulus during pressure testing to Insure the aoo~ 'yleld limit of the tubing is not exceeded. RIH and pull SV. 7) ROMO snckllne. pR,PPpç:n FRMn JRI= TRFATMFNT 8) MIAU fracturing equipment with ball sesler dropping capability. MIRU HLS. 9) Install largest ID "tree saver" avallabte. NU lubrlcator(Cross-Over between tree saver and lubricator will be necessary). 1 0) Carry out all fluid quality control proc:edures(Onslte Operations Engineering). Check Carbo-Lite pH and for fines due to excessive handling. Obtain a sample of the - ,-~=-~ ~~~ é: :..: ~.:.: -:J '3 : J: ..: ~r=':';::I~.< =, '"'::= - "-"" î::::: ~ ........-- -=1_ .. ,I:: :-L.3r:' 2 S:: - - ~ ='3=:~ -,- P. J. Archey May 22. 1990 page 5 1 1 ) Carbo-Ute and the gelled water with breaker from the pad and slurry stages. Record the proppsnt weight before and after the treatment. M I RU Pro- Technics equipment to Inject RA tracer material. Both the pad fluid and the " ~! 1 ^ J: proppant will be tagged with radioactive tracers for fractur. height determination. 7' JtJ,' ¡.} I L' Pro- Technics Engineer will also be onsite to quality control post·fracture loggIng. L'; ('~~¡ .';/ .¡ The radioactive tracer program will consist of the following: )1 L ;//,'1 ,~, ~ {~ . t- r' I l f t. L, )v/( ~;M' NOTE: Pro-Technics requires approximately one w..k of lead time to ship the appropriate amount of RA tracer to the slope. I The proppant tracer(S - 8 Pµo stages} 'will be Scandium-46 at a cancentration of 0.28 mCl/Mlb for a total approximate tracer amount of 20 mCi. ) I L. v' tf..f~ ,- ~ The proppant tracer(10 . 12 ppg) will be Gold-198 at a concentration of 2.2 I..- ~,)," c-I( ¡""./- ", ~"'l) Ie:; ~" mCi/Mlb for a total approximate tracer amount of 100 mCt í-f¡1 . fr..(( t .I ' I , r. ,I' t . Please note that the tracer ma1erl&1 InjectIon should be shut down approxlma1ely 15 bbls before flush is called to insure the tracer material is displaced from the surface equipment. 1 2) Pump fracture treatment per the attached schedule. Expected wenhead treating pressure and other trac paramøt9rs are IIstød below: WHTPE. 4200 psi Casing Pressure- 3500 psi during propped fracture treatment Annu1us contains 1 C.S pp<J complotlon brIne. F (3ctU ra Gradient=- 0.7 pgl/tt (6172' TVD) Estimated Tubing Friction- 400 psi/1000 ft (6375· MD)@ 25 BPM Estimated Tubing Friction- 300 paV1000 ft (63751 MD)@ 20 BPM Recommended Max Treating Pressure- 7000 psi (900/0 yield limit of tubing assuming aforementioned casing conditions.) ~ If treating pressure rlurfno p~ exceeds 6000 psi, confer with OperatIOns Engineering and consider available options Of shutting down the job. NOTE: If treating pressure begins to rise while sand ,tages tire being pumped through the tree saver, cutting pump rate should be considered to reduce friction and lowQr treating pressure. 1 3) 51 well and rig down frac &quipment(EXCEPT FOR TREE SAVER). All tlUI(!s should bü ~ at IW te 110· f on the 6ut1aœ. , .' I This )00 IS intenUooaJly W1defG\&hod by 2 W. The bIef1dør tub 5l\ould be bypas.sod ~ ~ StilQe 10 ~houJd ¡ndude a \'ObJ:aø ad¡u~ 101 sudaœ ~UI bct'MJeA 1M ~ aBd ~tom8IIIr. II Stages 1 and 3 2hrough 5 wil a!5a c:onWn 5% Arctic 0iø5e. by VOIUfW tor ~ II¥id loss 00ln1l01. '1' ,II " J S&ages 4 hough 9 are Gelled W"'œf wiIh 2 1bI1000 pi bi8Mer and .11houI áI'ca lour. S&ages 1 & 3 we Gelled Water Mil 40 1bII1000 pi aiica lour afId 0.5 1bf1000 P ÞnNIksr. KUPARUK WELL 2IC-IO'A' SAND FHArCTUR£ PUMP SCHEDULE GElLED WA TEll FRACllJRE TREA1IIEHT $/16/»0 1', / / ;., ·....7- .,' .' / .. ~~ ~RATE PJ¥:>P-~ B8LS IA.t Pffi I. , I ,II lJl (. , II, I· ISIP --........ .-....-.. .-... - -- --.. ..--- -- .--.-.. --- - -....... ---.. - -- - ~ -- a 120D/ ISg3 453 16120 .. CAßBO-UTE 8492 1101 1703 1653 16120 .. CARBO-UTE 18567 1301 1833 1763 16120 M CARBO·LßE 29895 1501 1983 1893 16120 ... CARBO-lIT E 42230 170f2153 2043 12118 ... CARBO-UTE 26231 901 2243 2213 12118 .. CARBO-UTE 1 9779 601 2303 2303 0 58 J 2361 2363 16120.. CAR8O-UTE - 99184 LBS 12111 M CARBO-UTE - 46016 L8S '1' (.1 I , , I III I t' .1 , II I, III (, J lJ I ÎI I· 11 I , I I ,'J 1·1 395 0 2001 200 0 601 260 0 451 305 0 301 335 0 58/ 393 I- . 60 26D 32D 365 III . I 'II "J I ") I-J I HIT PEfFS 96lS DIRTY \Q..UME SlG/ClJM PROPPANTWT U3S Pf03pAHT œscRlPnON I" 25 0 20 0 15 0 10 0 25 0 SHUT DOWN FOR 25 0 25 2 25 .. 25 6 25 8 25 10 25 12 25 0 )1ES: ~ 1 and 3 ttvough ~ Me Gelled W.... TOTALGEL.1..fD WATER - 2005.3 eeLS TOTAl DIESEl. 81.3 B8l.S TOTAlSUCK~CSiFt - 116.0 aa..s-eSV 3 GtN PAD 1 200.0 .. GW wJ2 PPG 101.1 5 GW wl4 PPG 110.5 6 GW wI6 PPG 118.ð 1 GW .,¡ø PPG 125.7 I GN WJ10 PPG 62.5 a GW ./12 PPG Ji.2 ~ S""- (/ 10 SlJQ( DIESEL fUJSH .O+SV --.. --..........-... --...... -.. ---- - ----- ---- ---" ...- - --------.. 58.0 SUCK O&E.SEL FlUSH 2 200.0 60.0 4S.0 30.0 GW PRE-PAD GW PRE-PAO GW PRE-PAD GW PRE-PAO FlUID DESCRIPTION STÞí:ìf - - ! - Î - -... - ..... , " -. ~ ... --- .' -..= 4 -- . -, - .....¡- - - - - - - -- -:.= ~ - - - - - ~ P. J. Archey May 221' 1990 Page 6 1 . <. . (dr)~J \y ~s~ . ,( r \.. / --< ) )~ ...... ,,¡J, , . )', f,\ r<m FAA~n~ I O\~ 1 4) ~un post·fr8C tempgraturQ and spøctral gamma ray \ooa. Begin logging as soon as practical atter the fracture treatment Is completed. Log the temperature pass first to Insure good f(3ctU(e height data is obtained. Log spectral gamma ray logs across fractured interval. 1 5) Repeat temperature log three times with 1 hour jntarvals bQtw~H}n runs. 1 6) POOH with logglng tool$ and RD HLS. 1 7) RJg down tree savor. P<.Å'iT FRAÇTlJRF SJ LÇKlINF= 1 8) MIRU ~\lckltne. RIH and t!Q f111. 1 9) RIH and pull the Petredat gauge from 6270' RKB. RIH and set DV at 6270' AKB. 20) Download Petredat data and deliver to Opera.tlons Engineering. 2 1) ROMO aUckUnt. ( - -~:-' ~2 - . '. ~ . -. .-- .'" .-_-".,.0; -" ..- '- - '-" -- -- . .-. -.....- - - . '.."- -- --- - - - - P. J. Archey May 22, 1990 Page 7 pO~T FRACTlJRf= FI ()WRA~K(J1S.?K) 1. Establish baselines for comparison by visually Inspecting choke and performing NOT of erosion prone areas, Immediately down stream of choke. all etbows and all tee~, that will be exposed to flowback fluids. Document these Inspections on the attached Flowback Log. 2. Obtain representative fluid samples from the pad. slurry. and flush stages during th e fracture treatment. 3. Operations Engineer.. Place samples in hot water bath at 1500 F to observe break time. 4. After the design break time and after verifying that the gel hss broken in the water bath, Oper!tions En~ineer will contact Production Foreman to initiate start of flowback. If gel has not broken, DO NOT ATTEMPT FLOWBACK. Contact Anchorage Engineering to discuss options if gel remains unbroken. 5. Open well up flowing to the test separator, the Initial targeted nominal rate should be 200 BLPD. Set low flow rate alarm for 50 BLPD. Set high flowrate alarm on test separator for 800 BLPD. On bottoms up, verify that gel Is broken. It excessive proppsnt or unbroken gel Is present. SI well and contact KOE Coordinator. Do not exceed !OO BLPD for the first 12 hours of flowback. After the first 12 hrs, open th e choke and flow well at 500 BlPD for the next 12 hrs. Record rates. choke settings and WH~$ on Flowback Log. S. After the first 24 hrs of f10wback, decrease wellhead pressure in 50 psi increments at regular time intervals (minimum two hours) until the well Is producIng at header pressure. LIMIT THE FLOW RATE INCREASe TO NO MORE THAN 750 BlPD IN A 24 HOUR PERIOD. Reset high flowrate alarm to stay below erosional velocity as predicted by the table provided by Corrosion Engineering and shown below In step 7. Alarm setting should be based on the maximum flowrate for the average GLR from the first 24 hrs of flow. If GLR changes again by more than 250 scf/cbl, change high flow rate alarm as appropriate. Record rates, choke settings, and WHP's during the flowback period on the Flowback Log. Take BS&W samples at bottoms up after" every choke change and/or every a hrs and record results on the Flowback Log. If excessive prqppant or unbroksn gel Is found contact KOE Coordinator. - ~ - - - -- - - . '-..... ~..../. --' P. J. Archey May 22. 1990 Page 8 - - - . -. - -,- - -". -" ..... - - ,- - -- 7. Inspect the choke Internals visually, and perform NDT on the erosion prone areas, the $-riser and down stream of the choke. twice during the first week and weekly thereafter until it is confirmed that an erosive condition does not exist. Maximum flowrates should be limited to those ~p8clfled In the fo1lowing table, if these maximums are exceeded choke the well back and inspect the erosion prone areas. GAS LIQUID PAm 300 SCF/BBL 500 1000 1500 2000 3000 5000 4" CHO<E MAXIMUM F1 C'J.N AA~ 3500 BLPO 2800 2000 1500 1300 1000 700 8. Flowrates are to be increased over the maximums outlined in the previous table only after a non-erosive condition Is verified through Inspeotlon and confirmed by Corrosion Engineering. Document on the Flowback Log. If erosion In the piping or choke body is identified. the well will be choked back to the previous non·erosive rate until some Indication Is obtained that the solidi production has decreased and an assessment of the damage has been made. Appearance of any erosive conditions win trigger more extensive monitoring than stated above. t 9. Once the FTP has returned to normal line pressure, send all Flowback Logs a::d Ot:~i:)( pertinent Information to KOE Coordinator. NOTE: Documentation of choke changes. all inspections, shake out results. etc., in addition to the flow data on the Flowback Log. will be very helpful In further refining the erosion pot9ntlal and appropriate monitoring plane. ( .....,' - .:...-- "'- - .' , -,:::. --. "-~ - . -. :.~- -- '.'-' ......- ::':~_;:':'¡:'I_r-. ~.~I~;:: ..2=...: --..... ,--- . - . -- --- - = :'=..' .: --- -- WELL 2K·10 PRODUCER API # 501032010600 SURFAce lOCATION: 71' FSL. 94' FEL. see 2, T10N. RSE. UM TOP KUPARUK: 1195' FSL. 931' FW~ see 1, T10N. Rse. UM DEPTHS: REFERENCED TO a RKB TUBING SPOOL ELEV:31' RKB ALL DEPTHS MO·RKB , 6-: 62.5' H-40 @ "5' TREE: FMC GEN IV 5000 PSI j z l ....J SPUD: 12112189 COMPLETION: 4/11/90 sssv: CAMeO TRDP.1A·SSA ID 2.812- @ 1 BOG~ .. GLM1: 2337' I 1.0· TMPD IOV GLM2: 4305' J 1.0· TMPD IDV GlM3: 5619' I 1.0· TMPO IDV ~ GLM4: 6270' I 1.5· MMO-2 IOV 9 5/8-: 36. J-55 " 3000' .. j ...J ..J BAKER peA: 3.000- 10 e 6312' BROWN HB PKR: 2.892- 10 @ 6326' X) OTIS 'XN' NIPPle: 2.7S" X 2.813- 10 0 6363' z SHEAR OUT: 3.000- 10 "8374' u B A5 A4 - · · · · · · · - A3 3.5- Q.3I J-55 EUE ABMOO IPC TUBING TAil @ 6375' HOLE ANGlE ACROSS KUPARUK . 1 DEGREES MAX HOLE ANGlE . 30 DEGREES @ 3800' VOLUME TO TOP PERF . 60 BBLS e512' 4 SPF @ , so- PHASING OReNTeD ~ CCN eS47' 7-: m L~80 4) 87;0' k / /) / / / / Jt. FILL TAGGED AT 1111' PBTD: 8722' REVISION: 4/17/! f7J.1 FracTEC+ PUMPing ParaMeter Recorder' TREATMENT RE?ORT 01 JUN 90 lIMe. HH:MM:SS 11:31:51 11:32:131 11:3(::::16: 11:32:16 11:32:26 11:32:40 11:32:50 11:33:013 11:33:10 11:33:20 11:33:30 11:33:40 11:33::,1d 11:34:00 11:34:10 11:34:20 11:34:30 11:34:40 11:34:50 IT: j ~ : d ¿ : 11:J/:41d: 11:3/:40 11:37:50 11:38:00 1..1:3g:1..0 1::~;:,2a 11:38:30 11:38:40 11:38:50 11:39:00 11:J~:1\::j 11:39:21 11:39:31 11:39:41 11:39:51 11:413:01 11:40:11 11:41d:1~: 11:40:22: 11:40:32 11:40:42 11:40:52 11:41:02 11:41:12 11:41:22 11:41:32 11:41:42 11:41:~2 11:42:02 11:42:12 11:42:22 11:42:32 fOI-~LUID AN PRES (PSI) 29~9 2959 (~)- 29~9 2959 2959 2959 29:,9 2959 2959 2959 2959 29~9 2959 2959 2959 2959 29~9 2959 '-'959 ,,- - (1¿:D- (1¿J)- 29~9 2959 2959 2959 ......... -.... ~:ï:)-:: 2959 2959 2959 2959 2~~~ 2959 2959 2959 2959 29:,9" 2959 (j)- 29~9 2959 2959 2959 29~9 2959 2959 2959 2959 29:,9 2959 2959 2959 2959 IR SLUR 101 PRES RATE SLUR (PSI) (EPM) (EEL) 110 0.0 13.0 110 0.0 0.0 SIAr.l1 JOtt 110 0.0 110 0.0 118 0.0 110 0.0 110 0.0 115 0.0 1543 0.2 15136 0.2 1456 0.0 1428 13.0 1410 0.2 1396 0.5 1387 0.0 1378 0.0 13/3 0.2 1364 0.2 ~ :,:; 5 0 . ø ~Aù5t. ~t.SIf1~1 f1r,l:.~ ~AUSt. 12~¿ 1d.1d 1d.3 1282 0.7 0.4 1712 0.0 0.4 15gB 8.3 0.4 ~ ; -j ":: ~ . ~' a . ~ 158a 0.a 0.4 1698 0.0 0.5 1703 0.0 0.5 1694 0.0 0.5 168~ 1d.0 Id.~ 1685 0.0 0.5 1675 0.0 0.5 1671 0.0 0.5 1666 0.e 0.5 166¿ Id.ø Id.~ 1657 0.0 0.5 ~~~5SU~~ I~SI LIN~S 18:'4 0.1 Id.S 2751 0.1. 0.5 3795 0.1 0.5 4949 0.2 0.6 :'983 0.0 0.6 7109 0.2 0.6 7993 0.1 0.6 8473 0.0 0.7 8574 0.0 0.7 8S28 0.0 0.1 8487 0.0 0.7 8450 0.0 0.7 8418 0.0 0.7 838& 0.0 0.7 1 88L IOI-SLU~ 0.0 0.0 0.0 0.0 0.0 0.0 o . 1 0. 1 0.1 0.2 0.2 0.2 0.3 0.3 0.3 0.3 0.~ r J.l'r"" .III f-JROP '10' CON PROP (PPA) (LE) -1. ~ -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2. -1.¿ -1.2- -1.2 -1.2 - 1 . 2 - 1. 2 -1.2 -1.2 -1.2 -1.¿ -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 -1.2 1 B8L 'r RIC PRES (PSI) ~ o o o o o o o o o o o o o o o 3 o o ..RCO AI "'''K~ ., r H ..."1J n 1~.... 2K-10 PAK Ø2-0~-g255 BH PRES (PSI) ~ o 'RDA1SiG IN6 SLUR (PPG) (EEL) ~ 6.8 8.2 o 6.8 0.~ o 2289 o 2289 o 2283 o 2283 o 2289 o 2289 92 2202 o 3727 o 3667 63 3~:,9 o 3599 o 3580 63 3508 o 3562 g 3~~3 o 3553 63 3481 o o o o 2 a o o o kf o o ø o Ø" o ø ..:1461 o 3461 o 3892 o 3882 ': 2 ':3 ~"/ d ,":11 ~ , ~ 123 374.2] o 3859 o 3882 o 3878 o 3~l'j o 3864 o 3859 o 3855 ø 3850 o 3~41 o 3837 o 60 o 7S o 75 o 46 o 68 o 71 o 81 o 46 o 0 o (] o 0 o 0 o 0 o 0 IOl-~\o(ð~ 3836 4764 4764 5928 (221 8142 9491 10364 10717 10/26 10680 10639 113598 10598 - ·,1 ':) . ::'1 r:1 . ~': - ~,! - . o . : 'S " :[ 6 . 31 6.8 6.9 6.9 6.9 6.8 S . 3 6.3 ,. "" ':J.~ 6.9 6.9 §. :~I b . :', S . '?I - . - -' .. ." .~ .. - 6.'3 6.9 6.8 6.9 6.9 6.9 6.9 6.9 (.0 6.9 6.9 6.9 7.0 7 . >J ., ·""\1 --, I .'~ "7 . '~II I . .~I: 7 " . '- 7 . 1 ( . 1 7 . 1 7 . 1 7 . 1 7.1 ~ L8 - - "- . - 8 .~ 0. 1 3.2 0.2 0.2 a . :: 8 . :: a . ~ 0.3' g.? ¡ - 0. :-1 ,"') =- ~ . -' 0.:' 0.5 0.5 0.5 0.5 8.:) 8.S 'a . 3 0.S n c- 0- . . ,J . - J.7 0.7 0.7 0.7 - - - - - - - - - - - - ~ FracTEC* PUH~in9 ParaMeter Recorder IIMI:. HH:MM:SS 11:43:0:> 11:43:15 11:43:25 11:43:35 11:43:46 11:43:~6 11:44:06 11:44:16 11:44:26 11:44:36 11:44:46 11:44:56 11:45:06 11:45:16 11:45:26 11:4~:36 11:45:46 11:45:56 1.1:46~06 11:4(;:16 1Tf~ô: 26 11:46:36 11:46:46 11:46:56 11:47:06 1"'4/""- . _., ..':11 11:47:25 11:47:39 11:47:49 11:47:59 11:48:0~ 11:48:19 11:48:29 11:48:39 11:48:49 11:48:~9 11:49:09 11:49:19 11:49:29 11:49:39 11:49:49 11:49:59 11:50:09 11:50:19 11:50:29 11:~0:39 11:50:49 11:50:59 11:51:09 11:51:19 11:~1:29 11:51:,]9 11:51:49 11'C::1~c:;q ( - - - - - - - - - - - - AN PRES (PSI) 2959 2959 2959 2959 2959 2'3~9 2959 2959 2959 2959 29~9 2959 2959 2959 2959 29:,9 2959 2959 2959 2959 2~3'3 2959 2959 2953 2953 "'...-:¡ ::j').I 3025 3057 3093 3051 299b 2983 2971 2965 2953 ¿~~j 2965 2983 3008 3026 3014 3002 3002 3020 3008 3014 3026 3014 3044 3020 3032" 3014 3038 i~14 If< SLUIo( PRES RATE (PSI) CBPM) 832/ 0.1 9009 0.0 9014 0.0 8981 0.0 8954 0.0 a921 0.0 8904 0.0 8748 0.0 1584 0.0 540 0.0 ~l2 0.0 1383 0.0 1401 0.0 1392 0.0 1383 0.0 1383 0.0 1378 0.0 1378 0.0 1378 0.~ 1378 13lC:! 1378 1378 1378 1378 ~ 424 2713 3507 4729 5274 :'123 4917 4637 4340- 3923 jc:!:>:> 3827 3832 3909 3964 4033 4111 4097 4120 4152 4166 4216 4230 4221 4225' 4212 4221 4212 4230 0.0 0.0 0.0 0.0 0.0 a · =1 S . :3 13.0 22.7 26.0 26.e- 26.9 26.7 26.5 24.0 ¿4.8' 25.3 24.4 24.9 24.4 24.:> 25.0 24.7 24.7 24.6 24.6 24.7 25.0 25.0 24.9 24.9 24.9 24.7 24.9 TREATMENT REPORT 01 JUN 90 lOr PIo(OI-' 101 SLUR CON PROP (EEL) CPPA) (LE) 0./ -1.~ 0.7 -1.2 0.7 -1.2 0.7 -1.2 0.7 -1.2 a.l -1.2 0.7 -1.2 0.7 -1.2 0.7 -1.2 0.7 -1.2 0./ -1.2" 0.0 -1.2 0.0 -1.2 0.0 -1.2 0.0 -1.2 0.0 -1.2 0.0 -1.2 0.0 -0.3 0.0 -0.1 r.: . -_. - 8 . 1 ~.Iâ ~.Ø" 0.8 -8.1 0.8 -8.0 0.0 0.0 0.0 0.0 a.l -8.0 0.7 -0.0 2.7 -0.0 5.8 -0.0 9.9 0.0 14.c! -0.Ø 18.7 0.2 23.2 0.1 27.5 0.0 31.7 0.0 :j~.~ -\:j.0 40.0 0.1 44.1 0.0 48.2 0.1 52.3 0.0 :>6.4 0.0 60.6 0.0 64.7 0.0 68.8 0.0 72.9 0.0 (/.0 0.0 81.1 0.0 85.2 0.1 89.4 0.1 93.5 0.0 9(./ ~.0 101.8 0.0 106.0 -0.0 110.1 0.a { - - - - - - - - - - - - ARC a ALASKA INC. 2K-10 PAK 02-Ø4-g2S5 I- ¡.( I C I, B H iR D H '1 PRES PRES I n6 !,~_ (PSI) (PSI) (PPG) ,-- o 1~ 10488 7.1 o Sl 10455 7.1 o 0 11216 7.1 o 0 11188 7.1 o 0 11156 7.1 o 0 11124 (.1 o 0 11097 7.1 o 0 11074 7.1 o 0 6062 7.a o 0 2720 6.9 ~ 0 2(43 6.9 o 0 3553 6.9 o 0 3553 6.9 o 0, 3580 S.? o 0 35 7 1 7:: . ':1 o 0 3562 ~.: o 0 3562 7:, .~I o 0, 3558 0 .=', o 0 3558 6.9 ø ø 3558 6.9 ~ ~ ~~~~ 6.9 o ø 3558 6.9 o ø 3558 6.9 o 0 3558 6.9 o 0 3558 5.8 a g 3~')a ~.~ a 2 4 7 3 <4 4 a ~ . =1 o 472 4740 7.a o 790 4951 7.1 6 1220 5890 7.7 6 1210 619~ 8.~ 15 1328 5982 8.5 37 1333 5792 8.6 S3 1293 5529 8.6 60 1259 S 181 :3 . 7'. 61d 12 :, ~ :> 0 9/ :3 . ~ I 69 1279 5076 8.~ 89 1279 5076 8.= 96 1246 5161 :3.7' 102 1266 5277 8.6 10~ 12:'4 :'409 8.6 114 1260 5512 8.6 118 1267 5599 8.6 129 1257 5605 8.6 130 1249 5640 8.6 131 1249 :>663 8.6 135 1255 5707 8.6 142 1271 5705 8.6 156 1271 5705 8.6 162 1271 5700 8.5 164 12/0 ~/0¿ 8.6 165 1270 5693 8.6 166 1270 5693 8.6 167 1261 5710 8.:' 0., 0.7 0.7 0.7 0.7 a .' ~.7 :Ã 7 ~ . , a.7 ~.7 0./ ra.e ;1 ï .-.1 . ._ ~J . ,- IÃ ,-, ~. ..- 0.0 0.0 0.0 13.0 ~ . ..~. - - . 2.7 5.8 9.9 14.2 18.7 ., ~ 7' ~ J . _ ~...... :-1 '- 56.4 60.6 64.7 S8.8 72.3 77.a 81.1 85.2 ag.4 g3.5 '3/ . 7 1 :a '1 . :~ L '.='~' . " . , ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - f7:!1 Frac TEC* TREATMENT REPORT ARC a ALASKA P¡C I 01 JUH 9a 2K-10 PUMPing ParaMeter Recorder PAK 02-g4-0255 IIM!:. IAN II-< 'SLUI-< 101 ~~O~ lOr 'r ~IC 'BH I-<DA1 !Si G PRES PRES RATE SLUR CON PROP PRES PRES I~6 SLUR HH:MM:SS (PSI) (PSI) (EPM) (BEL) CPPA) (LB) (PSI) (PSI) (PPG) C39L) 11:52:34 3081 4212 24.9 124.6 0.1 18~ 126~ :;ó9j a.6 124.¿ 11:52:44 3020 4207 24.9 128.8 0.0 188 1269 5689 8.6 1 ~ 8 . :~ 11:52:54 3014 4212 24.9 132.9 0.0 188 1269 5703 ::3. S 1 :' :: . ~ 11:53:06 3008 4207 24.9 137.9 0.0 190 1283 5693 3 . ~I - 11:53:15 3014 4198 25. 1 142.1 0.0 191 1270 5684 11::;3:26 3632 4207 2~. 1 146.3 0.0 1'32 12(6 - ~ ï- :':)1:::::' 11:53:36 3014 4198 25.3 150.5 -0.0 192 1283 5671 - - - 11:53:46 2983 4184 25.0 154.7 0.1 198 1282 5657 - 11:53:56 2996 4180 24.9 158.9 -0.0 202 1268 5653 j . :1 11:54:06 3020 4157 24.7 163.0 0.0 202 1253 5645 8.~ . 11:j4:16 31338 41(~ 2~.1 16(.1 0.13 2132 1263 564~ 8.j lS7.~ 11:54:26 3057 4180 25.2 171.3 0.0 204 1275 5651 8.6 171.3 11:54:36 3002 4175 24.9 175.4 0.0 206 1267 5664 8.6 175.4 11:54:46 2996 4170 24.7 179.6 0.1 222 1268 5658 8.S 179.:: 11:54:56 2996 4170 25. 1 183.7 0.0 234 1261 5656 ~ ,- 1'33.7 ~ . '::1 11:~~:06 3020 4193 2j.3 18/.9 -g.0 23::> 1269 j6~/ a . ,;~ ~.::, .:: ... - I . _' 11:55:16 3038 4184 25.0 1'32.1 0.0 235 1276 5655 ..., ,- 1::J? :j . ::; "'" ../ - . - 11:55:26 3051 4180 24.9 196.3 0.0 235 1276 56513 8.S 136.3 11:55:36 3002 4189 24.9 200.4 0.0 239 1275 5656 8.6 200.4 ,- ~11: S 5 : 4,5 31222 3822 20.1 2g4.0 0.0 242 11:>2: :: ~.:'J. 8.5 204.0 11: ~~: 56 ·--.:r~~i¿0 3/13 18.6 20/.1 0.01 24~ 1019' ~422 8.6 20/.1 11:56:06 3038 3804 18.5 210.2 0.0 244 1019 5422 8.S 218.2 11:56:16 3057 3951 19.7 213.4 0.1 250 1016 5539 8.:' -- 1 I ' ":'.l:.- 11:56:26 3008 4038 20.6 216.7 0.0 257 1065 5664 8.r: ~~ 1 ~ 11:55:?S ?014 4024 20.6 220.2 0.0 262 1102 56'31 ':. ~¡ _I .. _ ~'~:SS:4S ~ 2 ~ 2. ~J2 .::1 2,~ . ~I j ~ ':¡ ," a.a 2S~ 1~g2 - ,- - ,--. - - - -. -- - ....¡ _ _ -' . ,':] -,' -' -' -! 11:5é:5,; 2333 :J3S3 2 'a . 2 22?J 2 . 1 2:;7 1 aj 3 =- ~ ~ ~I 11:57:06 2996 3992 19.9 230.3 0.0 273 1069 5565 - . 11:57:16 3014 4033 20.1 233.6 0.0 275 1080 5681 :3 . S' 11:57:26 3026 4056 20.7 237.0 0.13 279 1088 5714 8.5 J -. c....J 11:~/:36 3038 4033 20.4 2413.4 0.0 28~ 1094 ~,(134 8.6 248.../ 11:57:46 3020 3978 19.8 243.8 0.0 290 1077 5652 8.5 243.8 11:57:57 3008 4001 19.9 247.4 -0.0 290 1072 5680 8.6 247.4 11:58:09 3026 3996 19.9 251.4 0.0 292 1065 5682 8.5 251.4 11:58:19 3038 3996 213.1 254.7 0.0 293 1072- 5680 8.5 254.7 11:~8:3~ 31326 391::t/ 2~.~ 2~1::t.4 ~.1 ~økf 1~'(tf ~66~ 8.6 2~8.4 11:58:41 3002 3882 18.8 262.0 0.0 307 1036 5634 8.S 262.3 11:58:52 3008 3736 16.3 265.2 0.0 310 945 5560 8.6 255.2 11:59:03 3014 3552 14.4 268.0 0.1 315 836 5476 8.5 268.0 11:59:14 3026 3690 14.5 270.6 0. 1 323 853 5588 8.5 270.5 11:~9:2~ 31338 3l~8 14.8 2/3.3 0.1 33kS 861 S644 8.6 2/3.3 11:59:35 3051 3781 15.2 275.8 0.0 335 861 5644 8.6 ':)¡,- -: ':...- -'.. '- 11:59:45 2996 3781 15.2 278.4 0.0 335 877 5656 '3 . S -, ~ - - 11:59:56 3002 3772 14.9 281.1 13.0 341 871 5661 I~ ::"1 '_' .. - I 12:00:06 3014 3795 15. 1 283.6 0.0 342 864 5664 I:' =- 12:00:18 3020 3(9~ 14. 'j 286.6 0.0 342 86~ j6(2 - - 12:00:29 3032 3813 15. 1 289.3 0.0 343 865 5681 - - . 12:00:40 3044 3818 14.9 292.1 0. 1 349 873 5692 ,-, - :) . 12:00:51 2990 3832 15. 1 294.8 0. 1 357 864 5700 :3 . :' 12:01:02 2990 3822 14.9 297.6 0.0 364 863 5720 8.6 -: ::¡ 12:~1:14 30132 38134 14. / 3130.~ 0.0 36j 864 ~/13j 8.6 30g.S' 12:01:26 3014 3818 14.7 303.4 -0.0 365 857 5712 8.6 303.4 12:01:37 3014 3511 11.3 306.0 0.0 366 6ge 5687 8.6 306.0 12:01:47 3020 3502 10.2 307.7 -0.a 367 6913 5687 8.5 307.7 -, -, , 3'; , 3 '3 4. i 394.1 394.1 394.1 334.1 3'34.1 3'34.1 394.1 3'34.1 394. 1 3~4.1 ::~-+. ~ 381.3 386.2 390.4 3g3.3 3g4.1 : :¡ : .., " -' , . - - - - : ) ~ -= - I _. _ 3~ 3 :> 2 ::j 356.8 360.9 365.2 369.4 - - - 325.3 326.3 323.S 330.2 3 3 1 . ~~ :¡:¡: =- 323.= 6.9 6.8 6.9 6.8 6.9 6.9 6.8 6.8 6.8 6.8 6.8 6.9 6. :3 6. '? 6. :~I b- ':' . '... S L- ':) . I:t . t- . ': - - - ,- r: . I: ~ . ...1 6 . 3 6.9 6.9 6.9 6.8 ,- q 1:1 . _ :J.-: ,3 . 7.5 7.5 (' . 1 6.9 6.9 6.9 6.8 8.6 8.5 8.6 8.6 8.6 :3 . ~I 1- ..I :. , : 8.5 8.6 "ROH 1 I ì~6 _ , CPPG) 1<:..;_ 8 . b 3 l 3 .- ~ B.5 314.'3 8.5 316.5 8.5 313.2 3.5 328.: :3.:> 32:.3 ~~IC ~H PRES PRES (PSI) (PSI) 3/~ 62~ ~124 372 633 5776 374 651 5789 378 643 5807 380 651 S808 381 643 5816 381 643 5807 383 635 5810 387 634 5839 389 633 5849 392 634 ~862 394 633 5863 395 625 5880 395 625 5880 395 641 5900 39~ 626 59:1 395 634 S9Sa 395 659 5956 395 895 6133 395 1278 5985 j~~ 116~ ~6~4 395 1234 5638 395 1273 5495 395 1295 5300 395 1295 5300 39~ 1251 )099 335 1255 4335 395 1279 4895 395 1273 4774 395 1285 4703 ~~~ 126~ 4~9~ 395 0 4549 395 0 4604 395 0 4590 395 0 4585 ~~~ 0 4~(6 395 0 4571 395 0 4571 395 0 4567 395 0 4567 39~ 0 4:>62 395 0 4558 395 0 4558 395 0 4553 395 0 4553 39~ 0 4~49 395 0 4544 395 0 4544 395 0 4544 395 0 4539 39~ ~ 4:>j~ 395 0 4535 395 ø 4530 395 e 453e ""N. ARca ALASKA H~C I 2K-18 PAK Ø2-~4-~255 ----- -- (' I IMe: AN Ilk! SLU~ fO I t-I~Ot-l 10 I PRES PRES RATE SLUR CON PROP HH:MM:SS (PSI) I(PSI) CBPM) (BBL) CPPA) (LB) 12:02:20 3051 36~~ g.~ 313.~ 0.~ 12:02:30 2996 3694 10.2 314.9 0.0 12:02:40 2971 3699 10.0 316.6 0.0 12:02:50 2977 3708 10.0 318.2 0.1 12:03:02 2930 3708 10.0 320.3 0.0 12:03:12 2996 3699 10.0 321.9 0.0 12:03:22 3002 3699 10.0 323.6 0.0 12:03:32 3008 3708 9.9 325.3 0.0 12:03:42 3a14 3722 10.0 326.9 0.1 12:03:52 3026 3736 9.8 328.6 0.0 12:04:02 3032 3140 9.8 330.~ 0.1 12:04:12 3038 3740 9.8 331.8 0.0 12:04:22 3044 3754 9.5 333.5 -0.0 12:04:32 3051 3790 10.0 335.1 -0.0 12:04:42 3038 3781 9.7 336.7 -0.0 12:04:~2 29a3 3836 9.9 338.3 -1.1 12:05:02 2990 3845 9.9 340.0 -1.3 12:05:12 3008 4102 13.9 341.9 -1.3 12:05:22 3020, 4408 18.5 344.7 -1.3 12:0:::·"J.... -:'"'\"'SI 4546 ..;:27..5 3~9..Ø -1.2 12: 0~: 42 - .~.;';-~--- "1~~~ 2¿..a- 3~¿.1:; -1.2 12:05:52 3002 4234 24.7 356.8 -1.2 12:06:02 3008 4157 25.6 360.9 -1.2 12:06:12 3014 4042 25.9 365.2 -1.2 12:06:22 3020 3859 24.8 369.4 -1.2 'L 2 : 2 S : ~ ,2: 3 2 ~ :: 3~ a 'j 2) . 2 3 ( 3 . ~ - 1 . 2 12:aõ:~2 3a32 3772 25.2 377.7 -1.2 12:06:52 3032 3708 25.0 381.9 -1.2 12:07:02 3038 3703 25.7 386.2 -1.2 12:07:12 3038 3635 25.6 390.4 -1.2 12:0/:22 300a- 1914 t.0 3~~.q -1.¿ 12:07:32 2996 2339 0.0 394.1 -1.2 12:07:42 2990 2321 0.a 394.1 -1.2 12:07:54 2990 2307 0.0 394.1 -1.2 12:08:04' 2990 2303 0.0 394.1 -1.2 12:0~:14 2990 ¿¿~d 0.~ ~~4.1 -1.¿ 12:08:24 2983 2294 a.a 394.1 -1.2 12:08:34 2983 2289 0.0 394.1 -1.2 12:08:44 2977 2289 0.0 394.1 -1.2 12:08:54 2977 2284 0.0 394.1 -1.2 12:09:04 29tl 2¿80 0.0' 394.1 -1.2 12:09:14 2971 2280 0.0 394.1 -1.2 12:09:24 2965 2280 0.0 394.1 -1.2 12:09:34 2965 2275 0.0 394.1 -1.2 12:09:44 2959 2271 0.0 394.1 -1.2 12:09:~4 29~9 22(1 0.0 394.1 -1.2 12:10:04 2953 2266 0.0 394.1 -1.2 12:10:14 2953 2266 0.0 394.1 -1.3 12:10:24 2953 2262 0.0 394.1 -1.2 12:10:34 2947 2262 0.0 394.1 -1.2 12:1~:44 2941 22~! 0.Ø 394.1 -1.2 12:10:54 2941 2252 0.0 394.1 -1.2 12:11:0A 2941 2252 0.0 394.1 -1.2 12:11:14 2941 2252 0.a 394.1 -1.2 TREATMENT REPORT 01 JUH 90 ~ FracTEC* PUHPing ParaHeter Recorder - - - - - - - - - - - - - - - - - - f - - - - - - ,- - - - - - - - - - - - - - - - - - - - - - - f7:Q Fr~cTECf PUMPing ParaMeter Recorder IIM~ HH:MM:SS 1¿:11:4/ 12:11:57 12:12:07 1 2: 12 : 1 7 12:12:27 12:12:3/ 12:12:47 12:12:57 112:13:07 12: 13: 18 12:13:29 12:13:40 12:13:50 12:14:01 12:14:12 12:14:22 12: 14:33 12:14:43 12:14:54 12:15:05 1¿:1~:1~ 12:15:26 12:15:37 12:15:47 12:15:57 ~~..1:::.;;" --....-.- l2:~-:;:~'? 12:16:27 12:16:38 12:16:49 12:16:~9 12:17:09 12:17:19 12:17:29 12:17:39 12:1/:41j 12:17:59 12:18:09 12:18:19 12:18:29 12:18:39 12:18:49 12:18:59 12:19:09 12:19:19 12:19:29 12:19:39 12:19:49 12:19:59 12:20:09 12:¿0:19 12:20:29 12:20:39 12:20:49 TREATMENT REPORT 01 JUN 9a AN I ¡.¿ SLUt.¿ lOr PROt-J lOr PRES PRES RATE SLUR CON PROP CPSI) CPSI) CEPM) CEEL) CPPA) CLB) 2928 2243 0.0 394.1 -1.2 2928 2239 0.0 394.1 -1.2 2922 2239 0.0 394.1 -1.2 2922 2234 0.0 394.1 -1.2 2916 2234 0.0 394.1 -1.2 2916 2234 B.g 394.1 -1.2 2916 2229 0.0 394.1 -1.2 2910 2229 0.0 394.1 -1.2 2910 2225 0.0 394.1 -1.3 2910 2225 0.0 394.1 -1.2 2904 2220 0.0 394.1 -1.2 2904 2220 0.0 394.1 -1.2 2898 2220 0.0 394.1 -1.2 2898 2216 0.0 394.1 -1.2 2898 2216 0.0 394.1 -1.2 2892 2211 0.8 394.1 -1.2 2892 2211 8.0 394.1 -1.2 2892 2211 0.0 394.1 -1.2 2885 2207 0.0 394.1 -1.3 2886 2207 '1. .:: -:-' "'..~ " ~ 2886 -. C:¿d~'-""- r.h ~-j~l -1.3 2880 2202 0.0 394.1 -1.2 2880 2202 0.0 394.1 -1.2 2880 2202 0.0 394.1 -1.2 2874 2197 0.0 394.1 -1.2 ~ ; ';' ..:1 2~ ; ('1 -] . .~ ~ :; 4 . ~ - ~ . 2 ~ j 7 ~ ~ '~ 3 7! ,= . 2 ~ 3 ~ . ~ : . 2 2874 2867 2867 286/ 2861 2861 2861 2861 28~~ 2855 2855 2855 2849 2849 2849 2922 2971 2977 29(1 2971 3002 3002 3014 3020 3014 3014 3008 2193 2193 2193 2188 2188 2188 2188 2184 ¿1~4 2179 2179 2179 2175 ¿ l'(j 2175 2179 2179 2175 21/0 2175 2815 2994 3401 3644 3580 3575 3507 .. 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 t1.k:1 0.0 0.0 0.0 0.0 ' 0.0 0.0 0.0 0.0 0.0 0.0 0.0 4.7 12.6 19.8 26.0 25.1 25.4 25.4 394.1 394.1 394.1 0.0 0.0 0.0 0.0 0.0 t1.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.3 1.8 4.4 8.6 12.9 17.1 21.3 -1.3 -1.2 -1.3 -1.2 -1.2 -1.3 -1.3 -1.2 -1.3 -1.2 -1.2 -1.3 -1.3 -1.3 -1.3 -1.2 -1.3 -1.2 -1.3 -1.3 -1.2 -1.2 -0.9 -0.1 -0.0 -0.'1 0.1 - - - - - - - ARca A~ASKA ¡ ~~C I 2K-la PAK 02-Ø4-0255 lJH RDA 1 '$1 G PRES IN6 SLUR (PSI) CPPG) C33L) 4~21 6.3 334. ~ 4521 6.9 3g4. ~ 45 1 7 ~ . ':; : ? ,! 4 5 12 S . :1 45 '12 4 S 12i 4512 45J7 4507 45Ø3 4j83 4498 4498 4494 4494 4494 4489 4489 4484 4484, 441::14- 4480 44813 4480 4475 It- ¡.¿ I C PRES (PS I) 39j 395 395 395 395 39:) 395 395 395 395 39~ 395 395 395 395 39~ 395 395 395 395" 3lj~ 395 395 395 395 3;:; -=I:~ - ....:J'J 395 395 395 o o o 13 ø ~ o o o o o o o o o o o o o o o ø ø 12 ~ o o o o a o o o o 8 o o o o o o o o :. ._,0 ~ 13 o o o o o o o ø o o 1;3 o o o o o o o o o o o o 327 606 993 1311 1311 1269 1277 ...._ '., _ A'\ , a -2 ,1 ,)- '-'I' -... ' - 1 . __I -.. - :i 4475 4471 4471 44'(1 4466 4466 4465 4462 446¿ 4462 4457 4457 4452 44:>2 4452 4452 4457 4457 4452 4448 4288 4632 4530 4~62 4562 456e 4581 - - . ~ . :-~ S . '3 6. '3 6.8 6.8 6.9 -- ~ :J.:: 6. ~ -- ..., ,..., - -1O... 6.8 6.9 6.8 6.9 6 . '~ 6 .3 6 . ::1 I- - -' . 6. 3 6.9 6. 'j 6.8 6.9 6.8 6.9 6.8 6.9 6.9 6.8 6.9 6.8 6. 'j 6 .? - -.i r: '..J . _, o . j 6 . '3 ( . 0 7.4 8.3 8.5 - , 334. ~ 3'34.1 334.1 3'34.1 334. : 3j4.~ 334.: 334.1 394.1 394.1 334.1 3?4. ~ -, ,-. , ,,- .:. J- . 0.8 0.0 0.0 0.13 0.0 0.0 0.0 8.8 0.03 a.a ~J . .: '-I -. :¡ .: '.-I . ..) 1 'J ,~ ,-.j 17. 1 21.3 - - - - - - - - - - f7J:} Frac TECi PUMPing P~r~Meter Recorder 11M!:. ~" - - - - - - - - - - - - TREATMENT REPORT 01 JUN 30 ( - - - - - - - - - ARC 0 A LA'; K A I ~¡ ¡: I 2K-1Ø PAK ~ ,-~~~.~::: :J. ... ...". AN PRES CPS I) 3038 3051 3063 3020 3020 3038 3051 2996 3008 3020 3032 31351 31351 3014 3025 3038 3051 2996 2996 :¡. 3008 jt:ji:::~ 3032 3044 3026 3020 ~2:2):SS i 3J32 12:25:25 I 3ð3:3 2990 2996 3008 3~i:::0 3032" 3032 3002 3014 3032 3038 3026 3002 3008 3020 3032 3038 3008 3020 3026 3038 3038 3014 3026 302b 3038 3051 3057 I~ ~LU~ 101 PRO~ 101 PRES RATE SLUR CON PROP (PSI) CBPM) CBBL) CPPA) (La) 23.9 36.~ -0.~ 23.9 40.13 13.1 24.7 44.0 0.1 25.1 48.2 0.1 24.7 52.3 -0.0 24.6 56.4 0.0 24,9 60.6 0.1 24.7 65.1 0.1 24.3 69.2 0.1 24.7 73.3 0.1 24.g (/.9 0.1 25.7 83.8 0.13 25.5 88.5 0.1 25.3 93.6 0.1 25.1 97.8 0.1 2).3 102.0 0.1 25.3 107.1 0.1 25.1 111.3 0.0 25.0 116.3 0.1 25.1" 122.1 0.13 ¿4.5 126./ ~.~ 24.8 130.8 0.1 24.6 134.9 13.0 24.9 139.1 13.0 24.B 144.0 0.0 4221 24.9 148.6 8.a 2S.a 152.7 a.a 25.a 156.9 0.0 25.0 161.0 0.0 24.8 165.6 0.0 2:'.0 l(~.b ~.ø 25.0 175.i 0.0 25.2 179.3 0.0 25.4 184.0 0.0 24.8 188.6 0.0 ¿4.( 11:L::I.:> ø.~ 25.1 197.7 0.0 25.0 202.3 0.0 25.1 206.9 0.0 25.0 211.5 0.1 2:>.~ 21~./ 0.1 25.2 220.7 0.1 25.0 225.3 0.0 25.2 230.3 0.1 25.2 235.3 0.1 24.6 239.) 0.1 26.9 243.9 0.0 26.5 248.8 0.0 25.3 254.0 0.0 24.9 258.6 0.1 2~.1 262.8 0.0 25.1 267.4 0.0 24.9 272.0 0.0 25.3 276.2 0.1 t-~IC BH 'RLï1~ PRES PRES I ~'6 ¡_,::_ CPSI) (PSI) C?PGJ i:.:',:~, 1~ 1221 4864 8.~ 3S.~ 23 1221 4864 8.6 40.0 34 1222 4993 8.5 44.e 49 1256 5174 3.5 49.2 58 1272 5250 g.s S2.3 ~8 1244 5336 3.= s;.~ 62 1272 5464 8.5 oa.s 80 1267 5545 8..6 ~5.: 92 1259 5632 8.S 53.2 108 1260 5671 3.6 73.: 11'( 12/1 ~l0g 8.6 77.: 139 1292 5719 8.S 83,~ 148 130 1 5722 8 . ':. ::):,-' 16 8 12 9 5 5 7 1 5 :3 . ~ I 184 1281 5706 - 19~ 1281 5(86 206 1288 S69~ 214 1287 5677 c.~ 222 1268 5679 8_~_ 2 3 3 12 7 t.;: .. - J i. 2 :.. _ ¿4¿ li:::~'( :51:) l3 - , d. 6 -, j,-¿;:(' 249 1274 5672 8.6 130.8 258 1260 5696 8.6 134.9 264 1267 5698 8.6 139.1 271 1257 5711 8.5 144.0 2/'3 l~S/ 3/1; ~.: ~'::::.:: 23 a 127 :3 57 : ~ _ . _' ~ :- 2 . - 285 1275 5731 a.5 156.3 295 1261 5749 8.6 161.0 304 1274 5732 8.6 165.6 311 12'(4 ~lj6 8.6 l('O.~ 321 1276 5748 8.6 17:.: 329 1278 5737 8 . ~, l""'~ 3 3 6 1290 5 7 39 :3 . sl 346 1282 5733 8 = 3:,d 12~8 ~(20 ':: 357 1275 5731 8.. 361 1275 5749 8.¿' 366 1282 5737 8.6 ~ 379 1289 5731 8.6 2"11..,· 391 1289 ~(40 8.6 400 1274 5750 8.5 407 1282 5737 8.6 413 1282 5724 8.6 439 1282 5737 8.6 4:'3 12~8 :>(34 8.6 460 1322 5821 8.7 467 1354 5803 8.6 481 1317 5711 8.5 494 1280 5694 8.6 499 12~2 ~'(33 8.~ 262.~ 503 1280 5744 8.6 --~ 511 1267 57S~ 8.51-- 534 1286 5747 :3 .-:' HH:MM:SS 12:21:25 12:21:35 12:21:45 12:21:55 12:22:05 12:22:15 12:22:25 12:22:36 12:22:45 12:22:56 12:23:0/ 12:23:21 12:23:32 12:23:44 12:23:54 12:24:04 12:24:16 12:24:26 12:24:38 12:2,4:52 1i::::2~:03 12:25:13 12:25:23 12:25:33 12:25:45 12:26:16 12:26:26 12:26:37 12:26:49 12:27:00 12:27:10 12:27:21 12 : 27 : 32' 12:¿'(:44 12:27:54 12:28:05 12:28:16 12:28:27 12:28:3l 12:28:49 12:29:00 12:29:12 12:29:24 12:29:34 12:29:44 12:29:55 12:30:07 12:30:18 12:30:28 12:30:.39 12:30:513 12:31:130 3653 3736 3896 3941 3955 4al5' 4088 4138 4175 4216 4234 4257 4248 4225 4212 4216 4202 4193 4184 418~ 41(~ 4184 4189 4216 4193 4234 4239 4239 4225 42j9 4257 4253 4244 4234 4¿~4 4234 4253 4248 4248 42:>/ 4248 4239 4239 4239 4244 4404 4299 4216 4225 4239 4253 4253 4253 21:>./ 220.7 225.3 230.3 235.3 233.3 243.'3 248.a 254.'~ 2S8.S - - - - - - - - - - - - - - - - - - - - - - - - - - - -- f7J:} Frac TEC' TREATMENT REPORT ARC a ALASKA INC. 01 JUN 30 2K-10 )uHPing ParaMeter Recorder PAK Ø2-Ø~-Ø255 TIM~ AN ' ¡..¿ SLU~ 101 f-J~O~ 101 r~IC tjH '}.¿ D A 1 SIG PRES 'ÞRES RATE SLUR CON PROP PRES PRES I~16 SLUR HH:MM:SS (PSI) (PSI) (aPM) (BEL) (PPA) (LB) (PS I) (PSI) (PPG) (BBL) 1~:31:jb 312120 4244 25.3 291.3 0.1 ~a:J 12è/ j/1j 8.5 .,--~ ,-::1-. 12:31:50 2983 4239 25.1 297.1 0.0 602 1288 5732- 8.S 2?.... 12:32:00 2990 4244 25.1 301.3 0.0 606 1280 5726 8.-;-" :';' . - - 12:32:11 2996 4239 25.1 305.9 0.0 612 1280 5730 - ' _I . _ 12:32:21 3002 4230 24. '3 310.1 0. 1 619 1282 57-' . - - ,c:.- - - 12:32:31 3008 4233 24.'3 314.2 8.a 62j 12S6 57?S' - - 12:32:41 3014 4230 25.1 318.4 0.0 630 1281 S72~3 - - 12:32:52 3026 4253 25.1 323.0 0.0 540 1281 5734 ,~ - .J . 12:33:02 3002 4244 25.0 327.2 0.0 649 1282 5743 ::¡ - -' . -:1 12:33:12 2990 4239 25.0 331.4 0. 1 658 1275 5735 8.? J : 12:33:23 2gg6 4230 2:J.0 33j.9 0.0 66~ 12/:' ~/31 8.6 335.? 12:33:33 3002 4230 25.0 340.1 0.0 667 1267 5734 8.7 340.1 12:33:44 3008 4234 25.1 344.7 -0.0 675 1282 5724 8.6 344.7 12:33:55 3014 4239 25.0 349.3 0.0 677 1275 5740 8.6 349.3 12:34:05 3020 4248 25.0 353.5 3.0 S80 1282 5733 8.S 353.:- 12:34:1~ jg32 42':)3 2j.1 3':)/./ 0.0 683 12/~ :>749 8. ,SI 337.7 12:34:26 3014 4253 25.0 362.3 0.0 591 1275 5754 8 . sl 3S2.: 12:34:37 2983 4253 24.6 366.8 0.1 708 1262. 5762 8.6 366.ë 12:34:48 2990 4253 24.8 37,1.3 o .·t 726 1275 5754 8.6 371.3 12:34:59 -I,J~2. ; .., -1 24.8 3}-5.';9 -,0.·13 742: 1274 576'3, 8.5 375.J . _ ( J..' -~¿:3':): 10 3002 42:>3- 24.S' 380.4 0.1 (:, 1 1¿'t4 :,'(:,5' --~_.., tj . t j (:I '''; . -t{ 12:35:20 313138 4262 24.8 384.6 0.0 762 1274 5755 8.:3 ?3..1 ~ 12:35:31 31320 4262 24.9 389.1 13.0 769 1267 5766 8.- : :J - 12:35:41 3026 4262 24.9 393.3 0.1 780 1274 5760 8 . t::i 12:35:53 3032 4252 25.3 398.3 0. 1 794 1274 5"'~~ :3 ( ..)-' ~2:jS:2j I ~ 2 2~! ..:J.::: ~ ') . '~ 4~2.~ J . ,2 :Jd) 12j/ - .., , ..,\ .: -':::1 ..) ( .... ( 12: 35: ~4 I 2332 :J < - ':17 1 ¿j . 2 ~ 1 ') ~'~ 7 ~ :::::- -, :::::- ..1 -~':),' :... '1 . j ~ 0::... I . _ 'j~- ..J --' ~ - . 12:36:24 3002 4262 25. 1 411.3 0.0 820 1294 5734 3 . 12:36:35 31308 4267 25.1 415.9 0.1 828 1287 5746 8.6 :- 12:36:45 3008 4267 24.9 420.1 0.1 844 1274 57613 8.7 4 2 ~j. , 12:jb:~b j~2~ 4262 24.9 424./ 0.1 8:':' 12/4 :'/60 8.6 424.7 12:37:136 3020 4257 25.1 428.8 0.0 868 1274 5769 8.7 428.8 12:37:16 3032 4257 25.0 433.13 0.0 874 1275 5749 8.6 433.0 12:37:26 3038 4271 25.0 437.2 0.0 881 1281 5752 8.7 437.2 12:37:37 3014 4271 25.0 441.8 0.1 889 1275 5763 8.7 441.8 12:3/:4( 3~~a 42:' 'I" 2~.td. 44:'.9 0.1 9~1 1¿82 ~(~6 8./ 44:'.9 12:38:00 3014 4257 25.1 451.4 0.1 916 1275 5758 8.6 451.4 \ 12:38:14 3020 4248 25.1 457.2 0.1 932 1275 5749 8.6 457.2 : 12:38:24 3026 \4253 25.3 461.4 0.0 933 1281 5739 8.8 461.4 : 12:38:34 3032 4262 25.1 465.6 0.0 938 1288 5741 8.6 465.S 12:j¡j:44 31338 4248 2:'.1 469.8 0.0 943 1282 S/4/ 8.6 of ~,S . ': 12:38:54 3044 4234 25.0 474.0 0.0 950 1282 5729 8.6 ..1~": - 12:39:05 3002 4248 25.1 478.6 0.1 974 1282 5729 :3 . ~ 12:39:15 2996 4244 25.3 482.8 0.0 986 1275 5740 3 . -, 12:39:28 3008 4207 25.0 488.3 o . 1 1000 1289 5712 ' -: ~ - 12:39:413 3014 4239 2:'.2 493.2 0.0 11304 12/6 ')/11 -- - 12:39:51 3020 4271 25.6 497.9 0.0 1006 1294 5762 I:: . _ 12:40:02 3020 4221 25.1 502.5 0.0 1011 1274 5750 'd . -J 12:40:13 3026 4244 25. 1 507.1 0.1 1029 1273 5733 8.S ~ - 12:40:25 3038 4257 25.3 512.1 0. 1 1049 1281 5743 8.7 S12.~ , i2:4Ø:j~ 3038 424t3 2:'.2 :'16.3 0.0 112162 128b :'/41 8./ SlS.3 12:40:45 3044 4234 25.1 520.5 0.0 1065 1281 5725 8.7 520.5 12:40:57 3014 4248 24.8 525.5 0.0 1081 ' 1274 5732 8.7 525.5 12:41:07 2977 4244 25.2 529.6 0.1 1092 1276 5739 8.7 529.6 "" I' - - - - ,,' ~ - - - - - - - - - - - - - - - - - - -- --... - -- f7:t1 FracTEC' ~uMping ParaMeter Recorder TREATMENT REPORT 01 JUN 30 IIMt. HH:MM:SS 12:41:44 12:41:54 12:42:04 12:42:16 '12:42:26 12:42:3/ 12:42:47 12:43:00 12:43:12 12:43:22 12:43:33 12:43:43 12:43:55 12:44:06 12:44:17 12:44:2( 12:44:39 12:44:49 12:44:59 12:45:16 1¿:4~:¿6 12:45:38 12:45:48 12:45:59 12:46:13 AN PRES CPSI) 29'3b 3002 3008 3014 3a20 3026 3032 3038 3044 2971 29'('( 2977 2983 2983 2990 2996 3002 3008 3014 3020- 30¿5" 3032 3038 3038 3044 1~:4;:24 I 3'a44 12:45:34! ,233a 12:46:45 12:46:56 12:47:06 12 : 4 (' : i( 12:47:27 12:47:38 12:47:48 12:47:58 12:48:09 12:48:19 12:48:30 12:48:40 12:48:51 12:49:02' 12:49:12 12:49:22 12:49:32 12:49:42 12:49::>3 12:50:03 12:50:15 12:50:25 12:50:37 12:~0::,0 12:51:02 12:51:"15 12:51:27 2996 2996 3002 3~~2 3008 3014 3020 3020 3~26 3032 3038 3038 3044 30~1 3057 3057 3020 2996 2996 2996 3002 3008 3008 3014 3020 3025 3032 I ~ SLU/o( I 01 ~~OP PRES RATE SLUR CON CPS I) CEPM) CEEL) CPPA) 4253 25.1 ~4~.0 0.1 4248 24.8 549.2 0.1 4244 24.8 553.3 0.1 4248 25.0 558.3 0.1 4248 25.0 562.5 0.0 4244 2:'.0 ~6(.1 0.0 4267 25.1 571.3 0.0 4257 25.1 576.7 0.0 4244 25.0 581.7 0.1 4244 25.0 585 . 9 ·0. 1 4248 2~.1 ~90.:' 0.1 4230 24.9 594.6 0.1 4244 25.1 599.6 0.0 4248 25.0 604.2 0.0 4230 25.0 608.8 0.0 4230 2~.1 613.0 0.1 4234 24.6 617.9 0.0 4244 25.0 622.1 0.1 4253 25.0 626.2 0.0 4248 24.8 633.3, 11 42~.:f 2~. ~ 6:f(. 4-' - 071- 4244 25.0 642.4 0.1 4248 25.0 646.6 0.1 4253 25.0 651.2 0.0 4248 25.2 657.0 0.1 4239 2).2 651.6 0.a 4234 25.a ;65.3 a.a 423a 25.0 670.4 8.1 4239 24.8 674.9 0.1 4244 25.0 679.1 0.0 42~4 2~.\:S 6I:f~.i 0.1 4239 24.8 687.8 0.0 4239 24.8 692.3 0.0 4248 25.0 696.5 0.1 4234 24.8 700.6 0.1 4¿~~ ¿4.b (~~.1 ~.1 4257 24.8 709.3 0.0 4262 25.0 713.8 0.0 4253 25.0 718.0 0.0 4244 24.8 722.5 0.0 4244 24.8 (2/.1 0.1 4257 25.0 731.3 0.0 4267 25.2 735.4 0.1 4276 25.4 739.7 0.0 4257 25.0 743.9 0.0 4239 2~.2 (48.) 0.1 4221 24.8 752.7 0.0 4230 24.6 757.6 0.1 4234 25.0 761.8 0.1 4244 24.8 766.7 0.1 4230 2~.0 (/2.1 0.0 4239 25.0 777.1 0.0 4239 24.8 782.4 0.0 4234 25.0 787.4 a.l 101 PROP It- R I C PRES CLa) CPSI) 114~ 1281 1155 1274 1176 1274 1187 1276 1196 1274 1203 1281 1209 1281 1216 1281 1229 1281 1247 1281 12:,9 12/4 1271 1281 1283 1273 1295 1274 1305 1276, 1324 12(4 1334 1274 1345 1268 1352 1261 ~ ~ 7?, 12,68 13~4 1¿6~ 1406 1276 1419 1276 1435 1276 1451 1282 146/ 12':32 1472 :27S 1480 1276 1499 1268 1509 1274 1~¿1 12/4 1536 126B. 1545 1268 1558 1268 1574 1274 1~':j4 1¿6kf 1605 1269 1614 1269 1628 1277 1634 1277 1648" 1269' 1660 1277 1677 1277 1688 1293 1691 1290 169:, 12 (I" 1705 1277 1711 1261 1726 1269 1735 1269 1(:'6 1269 1764- 1261 1767 1268 1772 1268 1\ f A~Ci"l "'I ~...... ;"i 'J .......,j~r1 .··.1 2K-10 PðK {"¡j-~'''-,1:·:: n 'J. .1, .... IE H 'R D H 1 PRES rt'!6 ";:'L, CPSI) CPPG) (9õL~ ~/34 8./ S4S.~ 5750 8.7 549.2 5745 8.6 553.3 5739 8.7 558.3 5741 3.7 SS2.~ 5 '( 4 3 ,3 . '( S S ? . : 5743 8.5 571.; 5757 8.7 37S.? 5743 8.S 331.7 5734 8.7 535.3 :'(32 a.1 S90.~ 5734 8.6 =:~.: 5733 :3 . -'1 5750 3 . -I 57.;18 = ~727 5736 " 5 7 38 ,3 . (" 5758 8.6 t_ 5752 q:7 533.~ ~t5~---ü-. r"- -'-oJ J(. 4 5735 8.7 642.4 5744 8.7 646.6 5748 8.6 651.2 5737 8.7 657.3 ~ / 2 8 j .=1 :; ; ~ . ~ 5 7 3 5 3 . 71 :; :;: . : 5726 5743 5741 ~/j2 5743 5747 5747 5745 ~(46 5746 5769 5752 5747 ~/~0 5738 5747 5754 5739 ~'1"42 5733 5717 5737 5746 :'/41 5745 5747 5743 :3 . 7 8.7 8.7 8./ 8.7 .:J .:! '-' . '-'; ;3. - !3 ':1 '- .:J 1_' , 8. ...., 8.6 8.7 8./ 8.7 8.7 8.7 8.5 8.6 8.5 8.5 8.5 8.6 8.6 :3.7 8. ~I :3 . .: s7a.~ 674. '3 679.1 S :3 3 . ~ ~I '3:' . :, . , -:-l _ 722.:- (2/.1 731.3 735.4 73g.7 743.'3 (4:3.5 752.7 757.t: 751. :3 7;6.7 ~~'~. ~ ~....,...., ,. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - f7J.1 Frac TEC~ TREATMENT REPORT ARC a ALA'5KA INC. Øl JUH ge 2K-10 JUMPing ParaMeter Recorder PAK ø2-a~-ø255 IIM~ AN If( SLU~ 101 ~¡.(O-J ¡ 01 rr¿IC 8H r¿DAl SIG PRES PRES RATE SLUR CON PROP PRES PRES IN6 SLUR HH:MM:SS CPS I) CP S I) CBPM) (BaL) CPPA) (LB) CPSI) CPSI) CPPG) (BEL) 12:~2:02 3044 42Sl 24.8 802.0 0.1 1824 12/6 ~/48 8.S ,j ~~ :: . ~~ 12:52:13 3051 4248 24.8 806.6 0.1 1840 1268 5747 8.S .:' "~ :-:1 . -: 12:52:24 3008 4244 24.9 811.1 0.1 1850 1267 5753 8.~ 12:52:35 2996 4239 25.0 815.7 0.1 1861 1275 5731 ~ -I -= . :- 12:52:46 2996 4257 25.13 820.3 13.13 1869 1271 ~ -,.- ..., - ,.i(r:JJ - - 12:~2:~8 3002 4244 2~.0 82~.3 '3. 1 1884 12(6 574; 12:53:139 313132 4248 25.0 829.8 0.1 1899 1276 5744 -' . 12:53:19 3008 4244 25.0 834.8 0.1 1915 1275 5745 :3 . -, 12:53:31 3014 4248 25.13 839.13 o . 1 1928 1275 57413 :3 .r:::i - - - 12:53:41 3014 4244 25.1 843.2 0.1 1940 1289 5726 ::¡- 3 ~ 3 . .:.' ~ . 'r::: 12::,3::,1 3020 4239 24.8 84/.3 0.1 19:>1 1289 ~/26 8.6 :347.3 12:54:03 3826 4248 25.0 852.3 8.8 1969 1276 5748 8.6 852.3 12:54:13 3026 4248 24.8 856.5 0.0 1979 1276 5748 8.6 a56.S' 12:54:23 3832 4225 25.2 868.7 0.1 1989 1269 5750 8.6 8613.7 12:54:34 31338 4234 25.8 865.2 13.8 1997 1282 5714 8.S 355.2 12::,4:44 3038 4230 24.8 869.4 0.0 2000 12/4 S'(' 32 3.'; ;;3.::: 12:54:56 3838 4239 24.8 874.4 -13.0 2006 1274 5732 g.6 '374.4 12:55:09 3844 4234 24.8 879.7 0.1 2014 1268 5737 8.S 873.7 ·12:55:21 3014 4244 25.0 884.7 0.1 2840 1268' 5751 8.7 884.7 112:55:33 . 3002. 425-= 25.1 889.7 8.0 2052. 1275 57"~':4 ; -' ? . -:: -12 : :, ~ : 4 j 3008 -, 2~.~ 1:f\j3.tj ~116J ~(4~---g:b .j -; j -.-::' 4~4t: 11.1 1~(~ 12:55:53 3008 4244 25.4 898.1 0.1 2072 1281 5734 8.6 ':' :. ,=' ,. 12:56:06 3008 4248 25.4 983.5 0.1 2082 1281 5724 ':¡ c: '- . :1 12:56:19 31314 4253 25.2 909.13 ø.e 2094 1283 5741 ,""¡ :.... ':' .. 12:56:31 31320 4253 25.1 914.1 0.1 2104 1289 5730 : - ~2:36:.:13 I 31328 4244 2').a 3::1.1 a.a 2113 1'''' '1 ~ ~ ~ ~1 ~-'j ~ ~ (' ~ ~ :2:35:53 ; 3222 4253 '7- 1 323.3 a . :.. 2: :3'2 ~ 2:3'~ S"7 3 .:11 :... ') . ~ 12:57:03 3002 4244 24.8 g27.5 0.0 2144 1281 5729 3 . ~ 12:57:13 30138 4248 25.1 931.6 0.1 2152 1281 5734 8.6 13.:J _ 12:57:24 3808 4253 25.1 936.2 0.1 2169 1274 5751 8.6 936.2 12::'/:34 3008 42~3 2:>.1 940.4 1:1.1 2194 1280 :'/49 8.7 '343.4 12:57:48 3014 4253 25.e 946.3 0.1 2211 1265 5717 8.7 946.3 12:57:58 3020 4244 25.13 950.4 0.0 2220 1277 5747 8.6 950.4 12:58:138 30213 4239 25.e 954.6 0.1 2230 1277 5733 8.6 954.6 12:58:18 3026 4244- 25.e 958.8 0.1 2258 1277 5733 8.6 958.8 12:~8:2t1 3032 4~34' 2~.~ \j6~.~ 1:1.~ 22,(~ 126lj ~/32' 8./ 962.9 12:58:40 3032 4248 25.2 968.0 13.0 2289 1284 5731 8.6 968.0 12:58:52 3026 4230 25.13 973.0 13.2 2308 1277 5724 8.7 973.a 12:59:04 2983 4230 25.0 978.0 13.1 2324 1284 5722 8.6 '378.0 12:59:16 2983 4234 25.0 983.0 0.0 2343 1284 5722 8.6 S83.ld 12:~9:28 2983 42j4 2:'.2" 9t18.0 0.1 23~j 12// S(¿4 8./ Ij :3 '3 .. ~=; 12:59:38 2983 4239 25.0 992.2 0.1 2371 1276 5730 8.S -, - - 12:59:48 2990 4230 24.9 996.4 13.13 2391 1277 5724 ,:] - . - '_I . -:'1 12:59:58 29913 4239 25.2 113013.5 13.1 2403 1277 5733 .""' - 13:00:138 2996 4234 25.13 11304.7 13 . 1 2415 1277 5733 - - - . 13:00:21 3002 422~ 2:'.2 1010.2 0. 1 2426 1284 :'/13 - - - 13:00:33 3002 4239 25.21 1015.2 8.1 2448 1284 5713 8 . ~ 13:00:45 31308 42313 24.9 1028.2 13.2 2477 1271 5726 8 . 71 - 13:130:55 3008 4230 25.2 1324.4 13.13 2491 1271 5735 i3 . 7 ~ ~~ '~ - . - 13:01:05 3014 4225 24.8 1028.5 0. 1 25133 1284 5718 8.7 1823.5 13:01:18 3014 4239 24.9 1034.0 0.1 2~¿9 1284 :,/1a" 8./ 1334.8 13:01:<8 3020' 4234- 24.9 1038.1 0.1 2546 1271 5740 8. 71 1038.1 13:01:38 3020 4239 25.0 1042.3 0.1 2569 1271 5740 8.6 1042.3 13:01:50 3025 4244 25.0 1047.3 0.1 2584 1271 574~^ 11 A 8.6 1047.3 .I... .. .. " '" r , " T Ilt1~1 I \. (] = ,-' .- -, : . -J 31..: 36.4 44.0 48. 1 52.7 57.3 61. S 55.7 69.? 7 4 . 1 78.~ 18544 L~ '3 . - '3 . t,: 9.5 9.7 9.7 9.7 ~.8 9.7 9.9 9.7 9.9 9.8 10.0 9.9 10.0 g. " '3 .3 10. Cl ':' - . '3 . ~ :3 , t·~- 8.~ 116~.4 8.6 1173.S 3 . 51 1 1 7? . ~ 3 . -Sl : ~ : ~ . = a . 6' 11 a 7 .=' 8.5 1192.0 8.6 1196.2 8.7 O.·~ 8 . -;--1 8 . 61 114 ~ . 8 . S, 11·32. '3, 8.õ 11S(.8 8.6 1164.8 1 1 1" -~ J. . _.., . la88. la93. la'3:3. 1~a3. 1 1 ~]:3 . :J·33.:: L.·~ BaL) la62.~ 1066.3 1070.S 1074.6 1378.3 :J - . - 8.7' ':J ~ t_i , ,] .1 IJ . ~ :J "'=' 'RDF11 IN6 (PPG) 8. I 8.7 8.7 8.S 8.5 a . ! 8.6 8.8 8.5 8.S 8.6 ~(46 5746 5765 5782 ~(9~ 5802 5792 5801 5749 ~t34 5753 5748 5758 5744 ~(:,1 5751 5738 5744 5738 ~l4~ 5753 ~t11:1 5701 5781 5713 ~(30 5732 5732 5750 1.~ 32¿1:I 1214 1.6 349Ø 1274 1.8 3766 1276 1.9 4071 1280 2.~ 44~~ 129~ 2.1 4787 1291 2.0 5119 1310 2.0 5507 1316 2.2 6123 1327 2.2 646~ 1319 2.1 6840 1317 2.1 7218 1338 2.2 7568 1329 2.3 7929 1347 2.3 8296 13~6 2.4 8673 1356 2.4 9058 1355 2.5 9443 1351 2.5 9832 1358 ¿.6 10¿3~ 13:,¿ 2.6 10644 1354 129:' HljL ìOI-j-I¡.¿dP 1280 1274 1274 1274 1¿(4 1282 1282 1238 I TIM ~ 'R N I ¡.¿ S L U R TO I 'j-I R 0 P 10 I PRES PRES RATE SLUR CON PROP I HH:MM:SS (PSI) (PSI) (BPM) (BBL) (PPA) (LB) 13:02:26 3038 4234 24.1 1062.~ 0.1 264~ 13:02:36 3038 4244 24.9 1066.3 0.0 2658 13:02:46 3038 4239 24.9 1070.5 0.1 2665 13:02:56 3044 42S2 25.0 1074.6 0.1 2680 13:03:06 3044 4239 24.3 1078.8 0.1 2694 13:a3:18 3a38 4239 2~.2 1083.8 0.0 2704 13:03:30 2983 4244 25.2 1088.8 0.1 2732 13:03:42 2983 4244 25.2 1093.9 0.1 2752 13:03:54 2983 4239 25.1 1098.9 0.1 2769 13:04:06 2983 4230 25.0 1103.9 0.0 2792 13:04:18 2990 4230 25.1 1108.9 0.1 281~ 13:04:30 2990 4239 25.1 1114.0 0.0 2826 13:04:42 2996 4230 25.3 1119.0 0.0 2840 13:04:52 2996 4234 25.3 1123.2 0.0 2850 13:05:02 3002 4221 25.1 1127.3 0.1 2864 13:0~:14 3002 4234 24.9 1132.4 0.0 2869 13:05:26 3008 4239 24.9 1137.3 0.0 2880 13:05:38 3008 4230 24.9 1142.3 0.0 2886 13:05:51 301~ 4225 25.1 1147.8 0.0 2899 13 : 06: 03 3 014 ~ 2'3 e. 24 . 9 11 S 2 . e . 0... 1 2913 13: 1d6: 1~ 302~, 4¿2~ 2~. ~. 115"(. 3l' --,J. '11 ¿:;~ 1 13:06:32 3020 4216 24.9 1164.8 0.0 2947 13:06:31: (9~)- SIA~' ~UMj-I G j-I~Oj-l ANI lj:06:43 31d¿6 4¿¿1 24.9 116:;.4 Id.\:;j 13:06:53 3026 4216 25.1 1173.6 0.0 ~3'~7'l- -~1~ 4~25 ~- 1 1177 Q ~ ~ .:. .(.) .-:..j I' j~...- - í..-:J.....:...... '::..1.(.) 1~:a7:15 2977 423g2S.~ 1182.,3 a.a 13:0t:2( 29;1 4239 2~.1 1181.8 0.1 13:07:37 2977 4234 25.1 1192.0 0.0 13:07:47 2977 4253 24.9 1196.2 0.0 13:07:57 2977 4239 24.9. 1200.3 0.0 ! 1 j n:H; : Id ~ : ( 1 ¿ b') - N I:. W S I A G l:. .:2 ... '13:08:11d ¿~~j 42~~ ¿4.~ 1¿1d~.( 13:08:20 299Ø 4257 24.9 1209.9 13:08:30' 2990 4262 24.9 1214.1 13:08:40 299Ø 4262 24.8 1218.2 ¡ 13:08:~2 2996 4¿j~ 2~.1 1¿¿3.~ 13:09:02 2996 4230 25.2 1227.4 13:09:12 3002 4221 25.5 1231.7 13,: 09: 24 3002 4166 25.3 1236. 7 13:09:42 3002 4065 25.0 1244.3 13:09:~2 3002 40:,1 2~.0 1¿4~.~ 13:10:03 3002 4056 25.0 1253.1 13:10:14 3002 4019 25.1 1257.7 13:10:24 3002 4006 25.2 1261.8 13:10:34 3002 3987 25.2 1266.0 13:10:44 3002 399~ 2~.3 12(0.2 13:10:54 2996 3974 25.3 1274.5 13:11:04 3002 3969 25.1 1278.7 13:11:14 3002 3964 25.1 1282.8 13:11:24 3002 3964 25.3 1287.0 13:11:j4 30\:;j2 3964 2:'.1 1291.~ ·13:11:44 3002 3955 25.1 1295.4 f('\I-I-IIITI1 1:5~,-¡ I4HI Inl-<;I U~ ¿~~j 2957 2962 2'367 29;/ 2986 2987 2993 ¡-~ICEH PRES PRES (PSI) (PSI) 126~ 5t4b 1263 5743 1271 5744 1271 5744 1269 5755 12(1 513'3 1284 5726 1285 5725 1272 5734 1285 5730 1282 ~(14 1287 5724 1286 5706 1279 5726 1279 5725 12(4 5732 1273 5733 1279 5722 1280 5717 1274 5728 12(4 ~tj¿ 1274 5714 - ARro ðL....I(··· ,.. ., :" rl ~ . '. ~ 1 ~·4:. I 2K-1a PAK Ø2-~~-~~:: - - TREATMENT REPORT 81 JUH ge ~ FracTEC* 'uHPing ParaMeter Recorder - - - - - - - - - - - - - - - - - - ( { - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - ~ FracTEC* ?uHPing ParaMeter Recorder TREATMENT REPORT 01 JUH 90 ARCO ALASKA INC. 2K-1Ø PAK 02-04-0255 rIM!:. HH:MM:SS 13:12:21 13:12:2':1: 13:12:34 13:12:45 13:12:56 13:13:06 13:13:18 13:13:29 13:13:40 13:13:50 13:14:02 13:14:12 13:14:22 13:14:33 13:14:43 13:14:53 13:1j:04 13:15:15 13:15:25 13:15:37 13:15:49 13:16:kjkj 13:16:10 13:16:213 13:1S:30 AN If.¿ SLU¡'¿ 101 '-Jf.¿0I-J 101 r~IC PRES PRES RATE SLUR CON PROP PRES (PSI) (PSI) (BPM) (EBL) (PPA) (LB) (PSI) 3g0~ 3960 2~.0 1311.! 2.8 12263 13~1 C 1 ¿ 6 ) - N t. W S I A G t:. 'f w' 3002 39~1 24.9 1316.3 3002 3960 25.2 1320.9 3002 3955 25.2 1325.5 3002 3951 25.1 1329.7 3002 39~1 24.8 1334.1 2996 3941 24.8 1339.3 2996 3955 25.3 1343.8 3002 3941 25.1 1348.0 2996 3900 25.5 1353.1 299~ 3868 2j.3 13~(.3 2996 3822 24.5 1361.5 2996 3850 24.6 1365.9 2995 3868 25.0 1370.1 2990 3873 25.1 1374.2 2930 39(( 2S.1 13(3.8 2990 3873 25.3 1383.4 2990 3868 25.13 1387.6 2990 3864 24.8 1392.5 2983 3818 24.6 1397.~ 29':10 3822 ¿4.8 1402.~ 2983 3836 24.8 1406.1 2983 3827 25.13 141ø.~ 2983 3822 25.0 1414.4 ~3:'~~:J'L ) '~3:lõ:31. : 13:17:03 13:17:15 13:17:27 13 : 1'( : 39 : Lj:ll:3'::j 13:17:513 13:18:02 ! 13:18:12 , 13:1Cj:2¿ 13:18:34 ,13:18:44 13:18:55 13:19:05 13:19:18 13:19:28 13:19:40 13:19:52 13:20:02 13:20:12 13:20:22 13:20:32 13:20:44 13:20:54 13:21:0~ 13:21:16 13: 21 : 2'6 ¡Ol-~LUIÓ ~3j3 J..... ... --. :::':::j': 2977 2977 2977 C12b)- 2991:1 3020 31326 30213 302~ 3020 3020 3014 3014 3014 3008 3008 3008 3002 3802 3002 3002 3002 3002 300¿ 2995 2995 14'8( .:: :: ") 'j 2 S .: 1 4 '1 :; . ~ .:.=:d ::::>.:/ 1423.~ 3836 25.1 1428.3 3832 25.1 1433.4 3827 25.1 1438.4 NI:.W 51 AGi:. f#" 3Cj41 ¿~.1 144j.8 3786 24.2 1447.9 3827 25.1 1452.9 3818 25.1 1457.1 3~kj~ ¿~.1 1461.¿ 3790 25.2 1466.3 3781 25.1 1470.5 3763 25.2 1475.1 3754 25.5 1479.3 3/0J 2~.1 14l:14.8 3694 25.2 1489.0 3671 24.7 1494.0 3644 24.9 1499.0 3639 24.9 1503.1 36~8 24.9 1:;0(.3 3644 24.7 1511.4 3662 24.9 1515.6 3676 25.1 1520.5 3662 25.1 1524.7 366Z 24.9 1~29.j 3658 24.9 1533.8 3649 25.3 1538.0 HI:IL 101 -SLUt< 3.0 2.9 3. 1 3.2 3.2 3.2 3.3 3.4 3.5 3.6 3.7 3.7 3.7 3.8 4.0 3.9 4.1 -1.2. 4.2 4.1 4.3 4.5 4.6 4.4 -4 . ? 4.7 4.8 4.9 12/94 13296 13808 14291 14884 15422 15977 16490 17129 1/666 18210 18811 19368 19929 2a~66 21211 21813 :~ ¿ 5 .'~ : 23276 23':161 24590 25227 25898 2651:3 2/23; 28126 28944 29789 ~H ~DA1 '5¡G PRES IN6 SLUR (PSI) CPPG) (BEL) ~ / / 6 10 . 1 ~J . ': 13:,9 1368 1369 1369 1360 1362 1371 1371 1399 1399 1394 1369 1372 1381 1392 1394 1397 ¡3:7 1390 139J 1404 1407 1424 1428 1447 1444 1440 1452 ~.1 jkjl1':1 144( 5.1 31439 1444 4.9 32281 1436 5.2 33027 1449 ~.J j3l(4 1461 5.3 34679 1485 5.4 35435 1495 5.5 36292 1483 5.4 37076 1486 ~.6 3CjkjCjg 1481 5.7 38889 1482 5.5 39840 1493 6.0 40794 1476 5.9 41614 1489 j.8 42416 1493 6.1 43239 1496 5.9 44041 1491 6.0 45037 1493 6.1 45871 1504 6.0 46(1j~ 1~¡j5 6.2 477213 1519 6.1 48567 1521 1:>jCj }jHL 101 -p¡.¿ð~ j/81 S7gS 578'j S73'~ S808 5815 5833 5833 5770 ~((0 5750 5742 5789 5821 S828 5834 5843 5837 5850 ~808 5819 5841 5830 -,'~ -" ..... -\. _ _T -: ,- - -"~ 58S9 5873 5871 '1 8 . ':1 ~.J . .:,1 ~~: . ~ 1':'1 l·J . ~ 18 . -:: 10.4 10.5 10.~ 10.6 10.5 la.S 10.5 12 . / 10.7 10.8 - 10.8 11.0 10. '3 11.~=t 10.:: 1 1 1 1 .'=' 11.2 11.2 j8~~ 11.3 5901 11.3 5903 11.5 5922 11.3 ~~¿¿ 11.:; 59133 11.5 5894 11.5 5887 11.4 5880 11.6 ~89¿ 11. S 5846 11.6 58 36 1 1 . ~: 5852 1L.- 5823 l~.- j842 1~. 5861 11. S 8 6 9 1 1 . :3' 5874 11.7 5886 11.'3 ~891 11.8 5873 11.3 5860 11.8 4tr~6l LB 3·:) . ' 41.7 46.0 50.1 54.6 sa.? ""? - 0_.::; ~; ~ ......J I .-" 72.1 76.2 81.2 q"- 1 _:J.. ... :L] . -.. ,::¡ : L:. 127 . "- 1./ 5.7 10.7 14.9 19.1 24. 1 28.3 33.0 37.2 d~.,:: , - ::- - .32 . ~r 8/.1 91. 7 95.9 - - - - . : 7.5 11.~ 3 . 3 1:;8.2' 152.4 157.4 13,:). 140.2 144.4 149.4 153.6 :32. .c: 85.6 90. 1 94.'3 '3'3. ~ 1.J:::.-' 7-'.= S 1. 5 56.1 60.2 64.4 68.b 73.~ .:::: ~ -'. ' g ,.:. - . - ,:! - - - . 141.:3 145.9 a.2 1 ... .. .... ~.... .. .. _ '...J t _ 59(2 13.0 5966 13.1 5994 13.0 5994 13.1 6 ~ ~ J 1 3 . ¿. 1 ~ I .:11 (' L~, 12.5 12.5 12.6 12.5 12.6 12.6 12.~ 1 ,:;---.....1 - . 12 '12. 1·.,:, 1...- 12. :3 12.7 12.8 12.5 12.9 12.9 12.9 12.9 12.9 12.31 12.··.:- 12.4 12.4 12.4 12.5 12.4 ~ 2.5, ::: . ~; ~.::. - ...., - 12.2 12.1 12.3 12.::: ":' - .:.. - . 1? .' ~ - . - 12. 1 12 . 1 12 . 1 5'317 5923 ~~:>4 5956 5956 5974 5976 :>982 5968 59613 5953 5967 ~96a 5968 5943 5951 5960 ~960 5964 5973 1 - :>942 5941 5919 S901 ~91~ 5931 5agS 5886 5905 ~~(¿ 5881 5894 5892 5875 ~ti~~ 5ga4 - ~..04 - -.,..... ' .... J..I ...._ 9.0 10Z(4~ 161~ 9.1 103876 1677 9.4 105031 1667 9.2 106179 1667 ~.2 10(311 16'(1 1t~3 ~~L 'ol-~~d~ 1:>:>2 1547 1558 . 1578 1~ (' 1 1559 1587 1572 1575 1:>(~ 1581 1576 1578 1590 l~~j 15'37 1:: a 1 1537 1609 1604 1616 1616 1602 1599 16¿¿ 1622- 1627 1640 1652 1646 1646 1651 1655 1659 1663 1667 1671 61:>10 62437 63366 64424 6~3(1 66418 67668 68721 69980 (~~4j 72004 73089 74078 75067 (6~~ö 77233 78234 79355 80375 ti13(~ 82394 83420 84443 85666 86~tjb 88176 89433 90496 91575 9Z(('ti 93845 94933 96260 97365 9ajaj' 99698 101049 AN III< SLU~ 10 I p¡.¿o~ PRES PRE~ RATE SLUR CON (PSI) (PSI) CBPM) (BEL) (PPA) 2990 366( 24.·~ 1~:>:>.:> 6.~ 2990 3639 25.1 1559.7 6.5 2990 3658 24.9 1564.3 6.5 2990 3644 24.9 1568.4 6.6 2990 3635 24.9 1573.4 6.6 2983 3626 2~.1 1518.4 6./ 3020 3653 25.2 1583.9 6.7 3032 3658 25.1 1588.1 6.8 3032 3667 25.1 1593.1 ß.8 (126) - ~H:oW SlAG!:. B ... 3032 3661 24.9 rS98. 6 3032 3653 25.2 1602.7 3026 3644 25.2 1606.9 3026 3635 25.5 1611.6 3026 360j 2~.2 161~.8 3020 3607 25.1 1620.4 3020 3594 25.3 1625.8 3020 3584 25.1 1630.4 3014 3566 25.1 1635.9 3~14 3b4~ 24.~ ~~4~.~ 3014 3562 24.~ iö~4.ö 3014 3571 24.9 1649.2 3008 3552 25.1 1653.4 3008 3562 25.1 1657.5 3008 3~~( 2~.1 1661.1 3882 3562 25.2 lS56.7 3882 ~S52 25.2 1578.3 3002 3552 25.1 1675.5 2996 3552 25.1 1679.7 2996 3~8Œ ~4.~ 16~~.8 2996 3584 25.1 1688.0 2995 3580 24.7 1692.2 2990 3575 24.9 1696.3 2990 3575 24.5 1701.2 ~~~~ 3~~4 ¿4.~ lt~6.~ 2990 3571 24.9 1711.~ 2983 3552 25.1 1716.1 2983 3557 25.1 1720.3 2983 3575 25.3 1724.5 2983 3:>62 2~.3 1(2~.1 2977 3534 25.1 1733.3 2977 3534 25.1 1737.5 2977 3543 25.1 1742.5 2971 3543 25.1 1746.7 2911 3~43 2~.1 1/jl.3 2965 3548 25.1 1755.5 2965 3543 24.9 1760.5 (126)- NtW S IAGt JD" 296~ 3:>48 24.9 1166.( 2990 3539 25.1 1770.9 3032 3552 24.9 1775.1 3032 3552 24.9 1779.2 j~¿6 3:>4¿ 24.~ 1t~~.4 1bt1 ~l;jL 101-SLU~ 6.8 6.9 7.1 7.1 1 . 1 7.2 7.1 7.2 7.2 I.l '1.3 7.5 7.4 7.4 I.~ 7.S 7.5 7.9 7.6 (. ¿ 7.9 7.9 7.9 8.0 ~.¿ 8.3 8.1 8.3 8.6 8.4 8.2 8.6 8.7 8.7 8.8 8.9 9.0 I 0 I 'I- ¡.¿ I C J::i H PROP PRES PRES (LB) (PSI) (PSI) :>2203 1~31 ~911 53096 1536 5891 54065 1528 5909 54946 1532 5911 56017 1525 5925 5(102 1~45 5893 58288 1553 5S91 59205 1556 5927 60311 1550 5948 ?LHl I t' 6 I (PPG) ,<~;jL 12.0 113.~ 12.0 117.5 12.1 122.1 12.1 125.3 12.2 131.2 ARC 0 A LAS K A It! C 2K-IØ P~K ~2 ...01 "¡O__ n f.) -~,-~.;:::, - ~' 13:26:55 13:27:05 13:2(:1~ 13:27:25 13:27:35 13:27:45 13:27:57 13:28:09· 13:28:21 13:28:33 13:28:43 13:28:53 13:29:04 13:29:14 13:29:24 13:29:36 13:29:46 13:29:~1 13:30:07 13:30:19 13:30:28: 13:30:34 13:30:44 13:30:54 13:31:~4 L:!:31:1.4 tor-I-LuILÍ HH:MM:SS 13:22:08 13:22:18 13:22:29 13:22:39 13:22:51 13:23:03 13:23:16 13:23:26 13:23:38 13:23:46: 13:23:~1 13:24:01 13:24:11 13:24:22 13:24:32 13:24:43 13:24:56 13:25:07 13:25:20 ..~.o -.._ ~ · .. _ ~ :::...: : ..J ~ 13 25:41 13 25:52 13 26:02 13 26:12 13 26:~~ 13 26:34 I :32S:441 IIMt:. TREAiMEHT REPORT 01 JUH 30 f7J::} Fr-acTEC+ PUMPing ParaMeter Recorder - / ij f7J:.1 FracTEC* JUMPing ParaMeter Recorder TIM!:. : HH:MM:SS '13:31::>11 13:32:013 13:32:11 13:32:21 : 13:32:33 : 13:32:43 ! 13:32:53 ¡ 13:33:03 : 13:33:14 113:33:25 '13:33:3j 13:33:48 13:33:58 13:34:08: 13:34:08 13:34:19 13:34:31 13:34:41 13:.::I4:j1 13:35:03 13:35:13 13:35:24 13:35:34 13:.::I~:44: 13:3~:44 I 13:3~:~~: TREATMENT REPORT 01 JUN 90 AN PRES CPS I) 3020 3020 3020 3014 3014 312114 3014 3008 3008 3008 31211218 3008 3008 (126)- 312102 3002 2996 2996 299121 29913 29913 2990 29913 (114)- 29901 (. 1 .:; ., \ _ ',- ... - - / I~ SLUR 101 f-IRO~ 101 PRES RATE SLUR CON PROP CPSI) CBPM) CBBL) CPPA) (LB) 3~/:, 2~.1 1/9S.j g.1 l11j~2 3575 24.9 18132.6 9.,8 112752 3603 24.9 18137.2 9.8 114056 3603 24.7 1811.3 10.0 115250 3625 24.7 1816.3 10.1 116703 3649 24.9 1820.4 10.0 11(901 3667 24.4 1824.5 10.2 119111 3671 24.5 1828.6 10.1 120315 3703 24.7 1833.1 10.2 121645 3763 24.7 1837.6 10.6 123005 3(86 24.4 1841.7 1121.3 124234 3887 25.0 1847.0 10.6 125850 3855 24.9 1851.2 10.7 127121 ~H:. W S ¡ A G I:. ) J- j:J. 3/40 23./ 18j~.l 1121.8 3676 23.4 1859.6 11.2 ~652 22.8 1864.2 11.3 3599 22.9 1868.0 11.3 3 6 4 9 2 1 . ~I 18 / 1 . / 121 . 8 ~: ,- ~' ? :;:. .~: 1 Q 76 . 1 -1 . 2 3699 2¿.8 1ª~9.~ -1.2 3726 22.6 1884.0 -1.2 3790 22.3 1887.7 -1.2 SIO~ ~UM~ING ~~O~~ANI 3 8 6 41 2 2 . 41 18 9 1 . 81 - 1 . ¿ 13 .::I 1 ~ 61 s: ~ ~ I C r '~ :.!j \j rJ L U M l ARca ALASKA INC 2K-10 PAK 02-04-0255 ~~IC BH~DAl 51G PRES PRES IN6 SLUR (PSI) (PSI) CPPG) CEBL) 169~ 6a21 13.2 3).1 1692 6039 13.4 33.2 171215 6071 13 3 4~': 1705 5071 13'~ '':':1 1705 5101 ... ·_1 l/g~ 6181 ~=. 1715 6135 __ 1716 6178 ._ 1 7 13 6 1 '3 6 i j . ~ 1 7 1 9 6 2 4 1 1 :: .s; 1'{34 6291 13.7 1721 6344 13.5 83.5 1761 6383 '13./ 87.8 128469 129701 131146 132344 133108 133156 133156 133156 133156 1 3 : ~ ) : S 3 i c: :J :; ~ ; ; 3 21 ,~ ~ . ~¡ 1 ,= ~; . ,j - : . 2 1 33 1:) õ' 13:36:08 13:36:20 13:36:31 13:36:43 1.::1::J6:~(: 13:36:j'{ 13:37:138 13:37:18 13:37:28 13:3/:38 13:37:48 13:38:04 13:38:14 13:38:25 13:38:3~ 13:38:45 13:38:55 13:39:06 13:39:17 13:39:2~ 13:39:39 13:39:50 13:40:01 13:40:12 13:40:¿J 13:40:34 101-~LUIÚ 2S30 2996 2996 2996 C1¿b)- 2990 2996 2990 2947 2941 2941 2935 2935 2922 2922 2915 2916 2910 2910 291214 2904 2898 2898 2892 2892 2886 1 /ì.J 4 3905 23.2 1900.6 3877 23.4 1905.3 3818 23.5 1909.6 3(22 23.2 1916.9 NI::.W SIAG~ 36/6 2¿.8 1:11:1.9 3658 22.9 1923.7 3571 22.5 1927.5 1730 3.2 19313.3 ¿1(~ 0.0 1:1;j~.j 2170 0.0 1930.3 2165 0.0 1930.3 2165 0.0 1930.3 2056 0.0 1930.3 1904 0.0 193~.3 1900 0.0 1930.3 1895 0.0 1930.3 1895 0.0 1930.3 1891 0.0 1930.3 1886 0.0 19.::1~.3 1886 0.0 1930.3 1882 0.0 1930.3 1886 0.0 1930.3 1891 0.0 1930.3 189~ 0.121 193~.3 1895 0.0 19313.3 8HL I 01 -SLU~ 1,(~9 1714 1683 1656 16// 1636 1644 1640 1563 63:'/ 62:37 6286 5325 6334 6365 6311 6253 6209- 13.:J 13.5 13 . ,:3 13.3 13.8 12.9 9.8 7.8 7 . 1 1 ~ 4 11 6 1 (' 21 ~ . ,.:,1 : 3 2 '.--11 -: r~ = -~I -1.2 133156 1488 -1.2 133156 1447 -1.2 133156 1425 -1.2 1331~6 1333 -1.¿ 1.::1.::11~6 1316 -1.2 133156 1316 -1.2 13315& 1321 -1.2 13315& 1324 -1.2' 1;j.::l1jb 1/4 -1.2 133156 0 -1.2 133156 0 -1.2 133156 0 -1.2 133156 0 -1.2 1331~6 0 -1.2 133156 0 0.0 133156 0 0.0 133156 0 0.0 133156 0 ~.0 1331~6 ~ 0.0 133156 0 0.0 133156 0 0.0 133156 0 0.0 133156 0 0.0 1J31~b 0 0.0 133156 13 19.::1k1 bHL 101 -~~d~ 338 11 5836 5661 ~30~ ~0(6 5076 4886 4629 40~6 4546 4542 4542 4464 4464 4281 4276 4272 4272 426/ 4263 4263 4258 4263 4¿6/ 4272 1:,jj1~6 - I . 7 . ~J 6.9 6.8 6.8 6.8 6.9 6.8 6.3 6.8 6.8 6.9 6.8 6.8 6 .8, - M - : ·~I '- . _ -JI 1:. . - S . '3 6. :3 6.8 6.8 6.8 LB =-, - I J_, . _ 2.2 ..... - ../ . J 10.:: 14.:: 18.3 22.4 26.2 30.3 :3 4 . ~. ,'7i .-, ..-, .. ~- 3.0 6.8 10.6 13.4 13.4 13.4 13.4 13.4 13.~ 1 3 . --:. ':1 '.. 1 , J. _ . 13 . ~ 13.4 13.4 ( f7:r.} FracTEC* PUMPing ParaMeter Recorder TREATMENT REPORT 01 JUN S0 iIM~ HH:MM:SS 13:41:0( 13:41:17 13:41:28 13:41:39 13:41:50 13:42:01 13:42:12 13:42:23 13:42 33 13:42 43 13:42 :,,:i 13:43 03 13:43 13 13:43 24 13:43 34 13:43 44 13:43 55 13:44 05 13:44 16 13:44 27 1.:i:44 44 13:44 54 13:45 04 13:45 14 13:45.25 13:4:,:?S ¡ 13:45:45 13:45:55 13:46:05 13:46:15 13:46:2:> 13:46:35 13:46:45 13:46:55 13:47:07 13:4(:1( 13:47:27 13:47:37 13:47:47 13:47:57 13:48:0/ 13:48:17 13:48:27 13:48:37 13:48:47 13:48::>l 13:49:07 13:49:17 13:49:27 13:49:37 13:49:4( 13:49:57 13:50:0.7 13:50:17 AN PRES (PSI) 2880 2880 2874 2874 2867 2861 2861 2861 2861 2855 28:,~ 2855 2849 2849 2843 2843 2837 2837 2837 2831 2831 2825 2825 2819 2819 ,~ -. ~ .... :::. j .;, :; 2312 2812 2806 2806 2!::06 2800 2800 2800 2794 2(,=,4 2788 2788 2788 2782 2/82 2782 2776 2776 2770 2'(( 0 2770 2764 2764 2764 2/~8 2758 2758 2751 'I ~ SLUIo( I 01 PRES RATE SLUR CPS I) CBPM) CBEL) 1904 0.~ 1930.3 1904 0.0 1930.3 1909 0.0 1930.3 1909 0.0 1930.3 1914 0.0 1930.3 1914 0.0 1930.3 1918 0.0 1930.3 1918 0.0 1930.3 1918 0.0 1930.3 1918 0.0 1930.3 1923 0.0 1930.3 1923 0.0 1930.3 1923 0.0 1930.3 1927 0.0 1930.3 1927 0.0 1930.3 1921 0.0 1930.3 1927 0.0 1930.3 1932 0.0 1930.3 1932 0.0 1930.3 1932 0.0 1930.3 19.:ib 0.~ 193~.j 1936 0.0 1930.3 1936 0.0 1930.3 1936 0.0 1930.3 1941 0.0 1930.3 :94: 2.2 133J.3 :341 a.a 1330.3 1936 a.a 1930.3 1936 0.0 1930.3 1932 0.0 1930.3 192/ 0.~ 193~.j 1923 0.0 1930.3 1918 0.0 1930.3 1918 0.0 1930.3 1914 0.0 1930.3 19~~ ~.Œ l,=,j~.j 1904 0.0 1930.3 1904 0.0 1930.3 1900 0.0 1930.3 1895 0.0 1930.3 1891 0.0 '193~.3 1886 0.0 1930.3 1886 0.0 1930.3 1882 0.0 1930.3 1877 0.0 1930.3 18 (I 0 . 0 1 9 30 . 3 1872 0.0 1930.3 1868 0.0 1930.3 1868 0.0 1930.3 1863 0.0 1930.3 18~9 0.0 19j0.3 1854 0.0 1930.3 1854 0.0 1930.3 1850 0.0 1930.3 ~¡..¿O~ 101 ~Io(IC CON PROP PRES CPPA) CLB) (PSI) 0.~ 1331~b 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331:'6 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331~6 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331~6 0.0 133156 0.0 133156 0.0 133156 0'.0 133156 ta.8 :~3i56 0.0 133156 0.0 133156 0.0 133156 0.0 133156 ,a . a 1 3 3 1 :, SI a . a 13 3 1 S S; 0.0 133156 0.0 133156 0.0 133156 0.~ 1331~6 0.0 133155 0.0 133156 0.0 133156 0.0 133156 0.~ 13.:il~b 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331:'6 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331~6 0.0 133156 0.0 133156 0.0 133156 0.0 133156 0.0 1331~6 0.0 133156 0.0 133156 0.13 133156 ( ARca ALASKA !~iC. 2K-la PAK ø2-a~-g25S 8H RS-1: PRES I ~f6 (PSI) (PPGj ~ 42/b 6.? o 4281 6.8 o 4281 6.9 o 4285 S.8 o 4285 5.'3 o 42'30 5.'3 o 4290 5.8 o 4295 6.8 o 4295 6.8 o 4295 6.9 o 429~ 6.8 o 4299 6.9 o 4299 6.8 o 4 30 4 5 . :3 o 4 3 0 4 S . ~I o 4304 o 4304 o 4304 o 4308 o 4308 . '-Ø-" '-431j o 4313 o 4313 o 4313 o 4318 a 4313 a 431'3 o 4318 o 4313 o 4313 o 430g 13 4304 o 4299 o 4295 o 4290 ~ 428:, o 4285 o 4281 o 4276 o 4272 o 42 '( 2 o 4267 o 4263 o 4263 o 4258 o 42~3 o 4249 o 4244 o 4244 o 4240 o 423~ 13 4235 o 4231 ø 4226 - . - . b . ;:;1 6.,'3 6.'9 6.8 6.9 6.8 5.9 -' . - .:, =i -' . - ,- ~ 1:1 . :; 6.8 6.8 6.8 6.9 6.8 6. '3 6 . '3 b . ';1 t, . ,- r:\ . s . ~ 6.81 6.3 6.8 6.9 6.9 6.8 6 . '3 6.8 6. '3 6.a 6.8 6.8 6.8 6.9 6. :3 .. . - . 13.4 13.4 13.4 13.~ 13 . ~ 13.4 13.4 13.4 13.4 13.4 13.4 13.-+ \ :' , - '1. 3 :.... 13.4 13.4 13.4 13.4 . '" . ... - . - - - . 'l31~ 13.4 13.4 13.4 13.4 1 j. _.J.' , :' ... -' 1 ~ . . 13.4 13.4 13.4 13.4 13 . 4 13.4 13.4 13.4 13 . 4 13..4 13 . 4 13 . ~ ~ :; f7J.} Frac: TEC* JUMPing ParaMeter Recorder IIMt:. HH:MM:SS 13:50:48 ,13:513:58 13:51:138 ,13:51:18 13:51:28 13:~1:38 13:51:48 ! 13:51:58 13:52:138 13:52:18 13:~2:31 13:52:41 13:52:51 13:53:01 13:53:11 I 13:~3:21 13:53:31 13:53:41 13:53:51 ¡--: ..,...- t:" t. I: '"I - TREATMENT REPORT 01 JUN 90 ARca ALASKA r NC. 2K-10 PAK Ø2-Ø~-Ø255 ~DA1 SrG IN6 SLUR CPPG) (BEL) 6.9 13.4 6.8 13.4 6.9 13.": S . '3 - IAN II-( SLUR TOI ~RES PRES RATE SLUR (PSI) (PSI) (EPM) (EEL) 2/45 2745 2745 2739 2739 2('39 2733 2733 2733 2727 2/2/ 2727 2721 2721 2721 2'(1~ 2715 2715 27139 -'-"i/1j4 pl-(OP 101. r~ICtjH CON PROP PRES PRES (PPA) (LE) (PSI) (PSI) 0.~ 1331~b 0 13.13 133156 13 13.13 133156 13 13.13 133156 13 0.0 133156 13 0.0 1331~6 0 13.13 133156 13 13.13 133156 13 0.13 133156 13 0.13 133156 13 0.0 1331~6 0 13.13 133156 13 13.13 133156 13 13.13 133156 13 13.13 133156 13 0.0 1331~6 0 13.13 133156 13 13.13 133156 a 13.13 133156 13 , 1 93~ '8Bl r 01 -j-I¡'¿~ 1~ _. -- r I '---- 184k1 1836 1831 1827 1827 1822 1817 1813 1813 -3689 -3689 -3689 1749 1795 17913 1/90 1785 1781 1776 B8L 0.0 1930.3 13.13 19313.3 13.13 19313.3 13.13 19313.3 13.13 19313.3 8.0 1930.3 13.13 19313.3 0.13 19313.3 0.13 19313.3 0.13 19313.3 0.0 1930.3 13.13 19313.3 13.13 19313.3 13.13 19313.3 13.13 19313.3 0.0 19313.3 13.13 19313.3 13.13 19313.3 13.13 19313.3 IOI-SLU~ PAGf=. ì , --l \ 421/ 4212 42138 42138 4203 4138 41'34 41'34 4189 4189 o 13 2912- 4171 4166 4166 4152 4157 4153 13.:11':16 ",:: - : ~ - . - . - r- ':J . :- Ô . '3 6.8 6.9 6.8 S.:J ,- ""' ::J . ':: 5. 'j S . :3 6.9 Llj 13.4 13.4 13.4 13..J 1 ..., .:. j . - 13.~ <:¡ . ..L._.~ 13.4 *Trademark and Service Mark of Dowell Schlumberger PROP-CON (PP A) 14. O~-_'__'_----------' - - ---- I , I 12.0----------------~----------·~----~---------------T---------------- 10.0----------------~---------------~---- ---------f---------------- 8 O----------------L---------------L- ---------~---------------- . , 'I 6.0----------------~------------- -----~---------+---------------- I I I I 4.0----------------r---------- ---T-----j---------T---------------~ 2 O----------------L------- -----r'----- ---------1---------------- . I . I O.OÒ.ô' .,.- ... 3ÔI.Õ-·- - - . - 60'.0 - J... .. 9A- 120 PUMP-TIME (MIN) TR-PRES (PSI) 8000 ---,- _,_~o, ...--.---. -0- . -_ . I I , I I I I 6000----------------~-----------~---~---------------~---------------- I , I I I I 4000 - .... - - - --'- - - - - L ~ - _·L f- ~ - -..?- - ..:; ....; . .. . _ - L_- _ - - - ... ~ _ - _ _ _ _ _ J. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ I . I I ,I , 2000----------------L-----------~---L-------~ I I I . I o .0---- -,0------- .- _--- __- 1_ SLUR-RA TE (SPM) 30 . 0 --~ ,----- -. - -. - · · I I I 25 . 0 ~ _ ¿ J - ~ . _ _ _ _ _ J - - - - ~ - . _..... - · _ ~ - - - - - - - ... - - - - - - - - - - - - - - - - 20.0----------------~---------------l-----~~r-------l---------------- I ,. I 15 O-------------~--L---------------L-------[I -______J.________________ 10·0----------------~-----------,----1--------------1---------------- 5·0----------------~-----------.----i-------l-------l~--------------- . I 1"1 0.0 ____--1.- -____ - .., 1__- - _. -.. ' r~--------------· I .~ -- ARCO ALASKA INC. 2K-10 PAK 02-04-0255 Pumping Parameter Recorder TREATMENT REPORT 01 JUN 90 Frac TEC If .:::: . .- - ..... "'- :" *Trademark and Service Mark of Dowell Sch1umberger PUMP-TIME (MIN) NET-PRESR (PSI) 1 OOOO:~ -:=-~-.: {~-~=-r~-=-~ - ~::.: t 1 ~ F==::':'~': - - -:- - F ~ - r ~-:-:-~ -'- -:. - -t - - - r ~ -:- -:- ~ - ~ + {] ------l---T--r-r~-r'l~---------~--'-l-r'-~r~-----'---r--~-r'-rT1J ------ï---~--ï-ï~-~~ï~---------~--1-ï-r~-~r~-----~---r--ï-ï~-r~~" - - - _ _ _.J _ _ _ J. _ _ L _ L -I_1..J. .J J _ _ _ _ _ _'.. _ _ -1_ _ .1 _ J _ L.J _L L _ _ _ _ _ _ J. _ _ _ 1. _ _L _L..J _ L .1. ..1. I I I I I I I I ¡ . I I I I I I I 'I I I I I I I - - - - - - -t - - - 1- - - t- - ~ -1- t- _t ; -t - - - - -....... - - ....- - _t - -; - ,.. -i-t_ t- - - - - - - _t - - - t- - -t_ - t- -t - ~ + _t . I I I I "1'1 ; I I I I I,ll I I I I I III ------~---+--~-~~-r~~1------t---~--~-~-r~-~~~-----~---r--~-~~-~+~~ , I 1 I I I I 1 1 I I 1 I 1 I I t I 'I 1 , I I I I I I I 1.111 I I I 1.111 I I I I III' ------'---T--r-r'-r~'-------r--'--~-'-r'-rr------~---r--r-r'-rT'~ I I 111111. ,.1 I I1II I I 111I11 I 'I "11'1 I I I~I III . II11111 ------J--._-l--L-L~-LJJ11------L--~--j-J- ~LLL_____J___l__L_LJ_L1J_ I I I I I I 1 I , I I I I ,I 1 I I' I , I I , I , · · '1 -, - , I \ I J i'" r r' - - - - I - ( ,,-, f" I ,'II. I I 1 I . I 1 I , , I I , I I , I , 1 I' I' I I I 1,1' I I I I , I I I I I I I I I'll I I I I I III I I , I I I II I , I , I III, " I I I'll, "I' 'I II 1000__,_____ __~_'-_-'~----~_~"-'~-~-~~j¡---:"--: :__~ _-:.-~ : : I. .,.: .: ~__~__~..~ ------;---~--r-~4-~~; ------r--4--~-;-~~-~r------~---r--r-~~-~~~· ------;---1---t--~~-t__t; ------t---....--~-;-,..-i-t_t_------_t---,..--t_-t_~-~+_t. ------~___~__L_L~_~~~J______~__~__~_~_L~_~~~_____~___L__~_L~_L~~_ I I I I I I I II I' I I I ',I'! 'I I I I I 1 I - - - - - - 1 - - - T - - r - r -. - r ~ 1 ì - - - - - ... r - - -, - - ì - 1 - r ì -1- r - - - - - - , - - - r - -1- -, Î - r T , - - - - - - _.J _ _ _ 1 _ _ L _ L _1_ L J. J ~ _ _ _ _ _ _l, _ _ .J_ _ .1 _ -.I _ L J ~L L i- _ _ _ _ _.1_ _ _ L _ _L _ L J _ L 1 .1 . I , I I I I I I 1 I I I I "I I L . I I I I I I I ------J---~__L_LJ_lJJ~------L--J--j-J-lJ-LL _____J___l__L_LJ_LIJ. I I I I I I I I I "I I I I I , I I I I I I I I I , I I I I I I , I' I I I I 1 , ., I I I I I I ------~---+--~-~~-~4~J------~--~--~-4-~~-A~L-----~---~--~-~~-~+4· I I I I I I , I -1 I' I ¡ I 1 PI , I I" I I I I I I I I I I I I I : "I I I , I I . I I I I I I I I I I I I I I I J I' I , I I , I . I , I I I I I ------'---T--ï-ï~-r~' ------~---1--Î-ï-r~-r~------~---~--r-ïï~~T~- I I I I I I I I I I' I I I I I I 'I I I I I I I I I I I I I I I I I' I I I I I I I I I I I I I I , I I I 'I I I I I I I I I I I 100_~L__1___1_' I I I 1 I I 1 10- I 1000 100 ARCO ALASKA INC. 2K-10 PAK 02-04-0255 Pumping Parameter Recorder TREATMENT REPORT 01 JUN 90 FracTEC* ( I \::? <::Y- o..> J '1 .J c.r I j ~ I .) ~-j DOWELL SCHLUMRrRGER Arlø A 1t<~Þ ~ <:.'~^ t" tJk FLUID QUALI 1 Y CLIENT: WELL: .).~-Io TREATMENT NO.: OJ -oc..- OJ.~ TANK WATER FLUID TANK VOLUME WATERFRAC FANN VISCOSITY HARSH FUNNEL NET GEL CROSSLINKING NO. pH TYPE BEFORE AFTER pH TEMP. 100 RPM 300 RPM TIME SIZE CONC. TIME TEMP. ì~5Ç 7'f J- t.t 0 ~y,ç (ø) ,[·3 loOC) rq ~~ ý-o=+l- : 0<) (006 ~ It" ì 1../ 0. - (¿, 7· ç '.J.- 7 1ïCJ '7 ~~ " ) 77° I~ '-~ ~ ì,~Ç Lfo..fÇ' fo7.Ç ì·3 c17° ,,)0 ~3 ( 77° V 7.Ço cj ¥';- 7~.Ç 91'° 7.~ J-o š3 ) 7~o ç 7.<; 'it./- <;' 7fo ,ç 07· ~ <jc.¡" ;)0 3<../ '7ý-D c,~ NOTES: l~ ).5 ~~\ vY\llø, ~ç y-\ 047J r s-ç"ç-ti" Kc:.\.. I I7Çcrt :r 3/-/7,..J.'ðC)1ft L 10, 1~7 'ý---\ ~~- I ~4"# ;Jj.rg "SS/FE SIGNATURE: fLùC~ **DATE: C:, - ( - qo - STATE Of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION (~ APPLICATION FOR SUNDRY APPROVALS Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing_ Variance _ Perforate _ Other 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK (approx) (approx) 1087' FEL, Sec. 1,T10N, R8E, UM (approx) 4. Location of well at surface 71' FNL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval 1220' FSL, 980' FWL, Sec. 1, T10N, R8E, UM At effective depth 1291' FSL, 1046' FEL, Sec. 1, T10N, R8E, UM At total depth 1334' FNL, 7651' feet Plugs (measured) 7306' feet None 6. Datum elevation (DF or KB) RKB 154' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-10 9. Permit number 89-59 10. APl number 50-103-20106 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured (approx) true vertical 6724' feet Junk (measured) 63 8 0' feet None Effective depth: measured (approx) true vertical Size Cemented 16" 9 5/8" 900 Sx AS III & 186 Sx Class G 7" 225 Sx Class G None Casing Length Structural 8 0' Conductor Surface 2 9 64' Intermediate Production 6 7 53' Liner Perforation depth: measured true vertical Measured depth True vertical depth 115' 115' 3000' 2932' (approx) 6789' 6445' (approx) EE' EIVED MAR -:1 990 Alaska Oil & Gas Con8. CommisSIolt Ancho~ge Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal _ Detailed operation program ;K BOP sketch _ 14. Estimated date for commencing operation March, 1990 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil X Gas __ Suspended Service Name of approver Date 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~ ~ ~ Title Area Drilling En~]ineer FOR COMMISSION USE ONLY JApproval No. I 5;~o -/2 ~. / Commissioner Date .,,,a,,. ,,.~ ._7~ SUBMIT IN TRIPLICATE Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test__ Location clearance__ Mechanical Integrity Test_ Subsequent form require ~.,~J~NAL 81GNED 8Y LONNIE C. SMITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 ARCO Oil and Gas Company Well History - Initial Report - Dally instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spuclded or workover operations are atarted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ARCO ALASKA INC. KUPARUK RIVER UNIT ICount, parish or borough NORTH SLOPE Lease or Unit ADL: 25588 Title DRILLING ALK: 2674 2K-10 IWell no. Auth. or W.O. no. AK3650 Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 12/12/89 (1) TD: 0'( 0 SUPV:SC IDete Hour 00:00 IARCO W.I, 55.8533 Prior atatus if a W,O. 12/13/89 (2) TD: 1549' ( 1549 SUPV:SC 12/14/89 (3) TD: 3020'( 1471 SUPV:SC 12/15/89 (4) TD: 3580'( 560 SUPV:CD 12/16/89 (5) TD: 6236' ( 2656 SUPV:CD 12/17/89 (6) TD: 6767' ( 53 SUPV:CD 12/18/89 (7) TD: 6798' ( 31 SUPV:CD 12/19/89 TD: 6798'( SUPV:CD Complete record for each day reposed DOYON 14 NU DIVERTER MW: 0.0 VIS: 0 MOVE FROM 2K20,NU DIVERTER, RIG ACCEPTED 0530 HOURS, 12/12/89. DAILY: $ 0 CUM: $ 0 ETD: $ 0 EFC: $1,294M DRLG 12.25" HOLE MW: 8.8 VIS: 93 NU DIVERTER, CUT DRILLING LINE, DRLG 12.25" HOLE F/l15 T/1549. DAILY:S111,732 CUM: $111,732 ETD:S111,732 EFC: $1,294M RUN 9-5/8 CSG MW: 9.1 DRLG F/1549 T/3020, CSG PT@3020, CIRC, SHORT POOH, LD BHA, RUN CSG. DAILY: $53,521 CUM: $165,253 ETD: $165,253 EFC: $1,' 294~ DRILLING MW: 8.5 VIS: 32 FINISH RUNNING CASING, CIRC, CMT W/900SX LEAD-186SX TAIL, ND DIVERTER, TOP JOB, NU BOPE, TEST-OK, MU BHA & RIH, TEST CSG TO 2000PSI, DRLG FLOAT EQUIPMENT, DISP W/ 8.5PPG MUD,TEST FORMATION TO 12.8 EMW, DRLG AHEAD. DAILY:S192,542 CUM:$357,795 ETD:S357,795 EFC:$1,294M POH FOR LOT MW: 9.2 VIS: 36 DRLG F/3580-6236, CIRC., POH FOR LOT AT 9-5/8" CASING SHOE DAILY:S78,457 CUM:$436,252 ETD:S436,252 EFC:$1,294M DRLG AT 6767 MW:10.6 VIS: 39 CONT. POH TO CSG SHOE, CIRC, PERFORM OH LOT TO 11.2 EMW, TIH, POH AND LD TURBINE, PU ROT. BHA, TIH, WASH & REAM LAST 37', DRLG F/6236-6767 DAILY:S91,449 CUM:$527,701 ETD:S527,701EFC:$1,294M WASH & REAM TO BTM MW:10.6 VIS: 37 DRLG F/6767-6798, CIRC., 15 STD SHORT TRIP, CIRC, POH, RU SWS, LOG W/ TRIPLE COMBO & SONIC, RD SWS, PU BHA, TIH, WASH AND REAM 60' TO BTM DAILY:S55,762 CUM:$583,463 ETD:S583,464 EFC:$1,294M DISPLACING CEMENT MW:10.6 VIS: 36 CONT. WASH & REAM TO BTM, CIRC., POH LD DP, PULL WB, RU & RUN 7" 29" L-80 CASING, SLI~S NOT MOLDING ON DOYON EQUIP, WAIT ON CASING CREW, CONT. RUN 7", CIRC. AT 3000', CONT. RUN 7" TO 6790', CIRC. W/ 30% RETURNS, PUMP 34 BBL SPACER 3000, 10 BBL CHEMICAL WASH, 225 SX CL G W/ ADDITIVES, DISPLACE WITH WATER DAILY:S103,952 CUM:$687,415 ETD:S687,415 EFC:$1,294M The 8b~ is correct For form prepar,~n ~.nd_ dis?ibu~l_on~ see Procedures~Ma~ual, Section 10, Drilling, Pages ~,4~nd 87. / '/ RECEIVED MAR -! ]990 Alaska 0il & Gas Cons. Anchorage Number all dally well history forms consecutively aa they are prepared for each will. ]Pl~e no, AR3B-459-1-D ~.RCO Oil and Gas Company Daily Well History--Interim structions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Jmber ail drill stem tests sequentially. Attach description of all cores, Work performed by Producing Section will be reported on "Interim" sheets until final )repletion. Report official or representative test on "Final" form. 1) Submit "lnteriln" sheets when filled out but not less frequently than every 30 days, or (2) Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. strict JCounty or Parish ISt~[~( ARCO ALASKA INC. I NORTH SLOPE eld JLease or Unit KUPARUK RIVER UNIT I ADL: 25588 ALK: 2674 2K-10 ate and depth ~ of 8:00 a.m. 12/20/89 ( TD: 6798'( SUPV:CD 12/21/89 ( 10 TD: 0'( SUPV:CD 12/22/89 ( 11 TD: 0'( SUPV:SC 12/23/89 ( 12 TD: 0'( SUPV:SC 12/24/89 ( 13 TD: 0'( SUPV:SC 12/25/89 ( 14 TD: 0'( SUPV:SC 12/26/89 ( 15 TD: 0'( SUPV:SC 12/27/89 TD: 0'( SUPV:SC Completerecordforeach{~ whiledrillingorworkoverinprogr~ss DOYON o) RR TO BP TAIL AFE MW:10.6 VIS: 37 CONTINUE DISPLACE CMT W/WTR. BUMP PLUG TO 3500 PSI FLOATS OK C.I.?. @ 0720 WELL FLOWING ON ANNULUS SIDE-MONITOR WELL. P/U BOP, SET 7" SLIP, ROUGH CUT CSG L/D LANDING JT-MAKE FINAL 7" CUT, N/D XO SPOOL, SET BACK BOP, INSTALL AND TEST ?ACKOFF. CHANGE OVER TO CONFIDENTIAL BP TAIL AFE @ 1330 12/19/89. DAILY:S168,257 CUM:$855,672 ETD:S687,415 EFC:$1,294M TIGHT HOLE. CONFIDENTIAL MW: 0.0 VIS: 0 DAILY:SO CUM:SO ETD:SO EFC:$0 TIGHT HOLE. CONFIDENTIAL. MW: 0.0 VIS: EXPLORATION TAIL BELOW KUPARUK - TIGHT HOLE DAILY:SO CUM:S0 EXPLORATORY TAIL FOR BP/UNOCAL. DAILY:SO CUM:SO EXPLORATORY TAIL FOR BP/UNOCAL. DAILY:SO CUM:SO EXPLORATORY TAIL FOR UNOCAL/BP. DAILY:SO CUM:SO ETD:SO EFC:$0 MW: 0.0 VIS: 0 TIGHT HOLE ETD:SO EFC:$0 MW: 0.0 VIS: 0 TIGHT HOLE ETD:SO EFC:$0 MW: 0.0 VIS: 0 TIGHT HOLE. ETD:S0 EFC:$0 MW: 0.0 VIS: 0 EXPLORATORY TAIL SECTION FOR UNOCAL/BP. TIGHT HOLE. DAILY:SO CUM:S0 ETD:S0 EFC:$0 MW: 0.0 VIS: 0 EXPLORATORY TAIL SECTION FOR UNOCAL/BP. DAILY:SO CUM:SO ETD:SO EFC:$0 '~e above is correct IWell no. RECEIVED MAR -1 ]990 Alaska Oil & Gas Cons. Comm%ssiot Anchorag~ ~ii1' g, g d 87 ' I~te / / R3B-459-2-B t~l'umber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. District County or Parish ARCO ALASKA INC. NORTH SLOPE Field ILease or Unit KUPARUK RIVER UNIT I ADL: 25588 Auth. or W.O. no. ITitle AK3650 I DRILLING ALK: 2674 IAccounting cost center code State AK 2K-10 no. Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 12/28/89 (17) TD: 0'( SUPV:SC Old TD A.R.Co. W.I. 55,8553 Date Complete record for each day reported DOYON 14 otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W.O, 00:00 I MW: 0.0 VIS: 0 EXPLORATORY TAIL SECTION FOR BP/UNOCAL. FINAL REPORT. TIGHT HOLE. RR @ 1700 12/27/89 DAILY:SO CUM:S0 ETD:SO EFC:$0 New TD RECEIVED Alaska Oil & Gas Cons, C0mmissi0 AnchOrage PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data ~ell no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P. C.P. Water % GOR Gravity Allowable Effective date corrected The above i1~ correct iiii~ dsed~ln. Da~//~/~ / / IT~ g~ .. Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively es they are prepared for each well. Page no. Dl~lllon of AtlantlcRIchfl~dCompany List Formations Miluveach Top Kingak of Geolooic Markers Depth 6600 7210 SS BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 18, 1990 Mr. Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Kuparuk 2K-10 Tail Operation Data Dear Commissioner Chatterton: Hand delivered herewith are copies of the well data listed on the attached "Exhibit A" for the Kuparuk 2K-10 tail operation. These data and information are marked "Confidential." We request confidentiality of these data and information under the provisions of 11 AAC 82.810. We note additionally that as we outlined in our letter dated December 15, 1989, a copy of which is also attached as "Exhibit B," ARCO, although operator of the 2K-10 well, was not a participant in the tail operation. Therefore only Unocal and BP Exploration should be given access to the commission files for this portion of the well while the data retains a confidential status. We thank you for your cooperation and assistance in this matter. ~./~,Yours very truly, ~,/~ . E. P. Zse~czky, Jr. / Land Manager- Alaska EPZ/slb cc: Mr. Robert Anderson Land Manager Unocal 909 W. Avenue Anchorage, Alaska 99519 RECEIVED FEB - 2 1990 Alaska Oil & Gas Cons. Commissio.~ Anchorage CONFIDENTIAL Exhibit A Kuparuk 2K-10 Tail Well Information BP Exploration/Unocal -- Mudlog '-T. DT/CNL/G R Sepia and Blueline · Sepia and Blueline /~,,~j'Sepia and Blueline 7 Sepia and Blueline Sepia and Blueline Sepia and Blueline List of Geologic Markers Washed and Dried Cuttings Well Log Data Tape with Verification Listings RECEIVED FEB - 2 1990 Alaska Oil & Gas Cons. Commissio[~ Anchorage BP EXPLORATION EXHIBIT B BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907) 561-5111 December 15, 1989 Mr. Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE' Notification of Commencement of Kuparuk 2K-10 Tail Operation Dear commissioner Chatterton: BP Exploration (Alaska) Inc. hereinafter "BP", wishes to advise of a change in report submissions to the AOGCC for the currently drilling Kuparuk 2K-10 well. We have discussed this previously with Commissioner Lonnie Smith, who advised that we should notify the Commission in this fashion, at this time. The Kuparuk 2K-10 well is currently being drilled by ARCO Alaska, Inc. as operator, on behalf of itself, BP and Unocal. Commencing shortly, a tail operation will be drilled by ARCO as operator for only the benefit of BP and Unocal, At this time we expect this operation to begin on Monday, December .18. The tail will commence at a depth of approximately 250 feet below the base of the Kuparuk formation and is projected to bottom at approximately 1000 feet deeper. BP is named as tract representative on behalf of participants BP and Unocal. Because ARCo has elected not to participate in the tail operation, and should therefore not be privy to ali well information, BP shall submit all required reports to the AOGCC. As per oUr discussion with CommiSsioner Smith, ARCO shall continue to be named as operator of the well, however. Upon completion of the operation, responsibility for filing the final well report shall be transferred back to ARCO. We appreciate the advice and cooperation of the Commission in this endeavor. Please call me should you have any questions. Yours very truly, E. P. ZsCreczky, Jr. ' ¢ Land Manager- Alaska EPZ/slb RECEIVED FEB - 2 1990 Alaska Oil & Gas Cons. Cot3¢SStu-~.~ Anchorage STATE OF ALASKA AL, ,,.,KA OIL AND GAS CONSERVATION COMMISSION U REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging X Perforate . Pull tubing Alter casing Repair well Other X A~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 71' FSL, 94' FEL Sec. 2, TION, R8E At top of productive interval N/A At effective depth N/A At total depth N/A 12. Present well condition summary Total depth: measured true vertical 5. Type of Well: Development Exploratory X Stratigraphic Service 8. Well number 2K-10 9. Permit number/approval number 89-59/9-905 10. APl number 50- 103-20106 11. Field/Pool ~ Kuparuk River Field/Oil Pool 7651' feet feet Plugs (measured) Class G Cement Plug @6724'-7651' Retainer @6770' Effective depth: measured true vertical 6724' feet Junk (measured) none feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length ,,,6750' Size Cemented Measured depth True vertical depth 7" 225 sx C/ass G 6789' measured N/A -- NOTE: WITNESSING OF PLUG SETTING AND TAGGING WAIVED BY AOGCC REPRESENTATIVE MIKE MINDER true vertical Tubing (size, grade, and measured depth) N/A Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) The exploratory tail from 6724'-7651' has been plugged and abandoned Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~//~ ~ ~ Title Lead Exploration Engineer Form 10-404 Rev 06/15/88 6. Datum elevation (DF or KB) RKB = 154' feet 7. Unit or Property name Kuparuk River Unit KUPARUK 2K- 10 AFTER ABANDONMENT OF THE TAIL 7" CASING IN 8 1/2" HOLE ,.,.,...,.,.,.,.,. ENT TOP 6724' ~ ......... SOUEEZE PACKER - 6770' CEMENT ~ ,I~,,,,,,,,%,,~,,,,,~ 7 CASING - 6789 ~ ~'~','~',',',','1 TD 7651' ATTACHMENT I ABANDONMENT PROCEDURE WELL KUPARUK 2K-10 Well status prior to abandonment of tail section: Arco, as Operator, drilled to 6798' and ran and cemented 7" production casing at 6789'. At the point the casing was cleaned out, BPX gained operational and financial responsibility and Arco acted as a third party subcontractor performing the drilling operations. After performing a formation integrity test at the 7" shoe to 12.5 ppg EMW, a 6" hole was drilled to 7651" TD. Wireline logs were then run, and the 6" tail section was prepared for abandonment. After the abandonment of the tail, Arco will complete the well through the 7" casing. Abandonment Procedure: . . . . , , 10. RIH with 28 jts of 2 7/8" tubing below 3 1/2" drill pipe to 7651'. POH to 7631' (20') and pump a balanced 15 bbl Class G cement plug. POH to 7180' and pump a balanced 15 bbl Class G cement plug. POH to 6730 and circulate. POH. RIH with bit and scraper to 6775' - found no cement. Circulate, POH. RIH with EZSV squeeze packer and set same at 6770'. Squeeze 5 bbls of Class G cement below packer, unsting and lay 5 bbls of cement above packer in the 7" casing. RIH with bit and scraper, wash to 6700', test casing to 3500 psi- OK. Found cement top at 6724' (46" above the packer, 65' above the 7" shoe). Displaced well to brine and POH (Arco to take over completion operations at this stage). BP EXPLOR.~'iON Daily Drilling Report -- Kuparuk December 19, 1989 at 0600 hrs Confidential Rig: DOYON 14 Well: 2K10 AFE # AFE Amount: Current Amount: 0600 Depth: Day: 24 - Hour Ftg: 6798' Current Operation: Run and cement 7" casing. Condition hole. Run 7" casing. Circulate lost partial returns. Cement 7" casing with 225 sx cement. Wells Shut-In for Drill-By: Mud Type: WT: 10.6 SURVEY MD ANGLE VIS: 36 PV: 13 YP: 7 FL: 4.0 Solids: 14 Temp: °F DIRECTION TVD SECTION COORDINATES DLS BP EXPLORATION Daily Drilling Report -- Kuparuk December 20, 1989 at 0600 hrs Confidential Rig: DOYON 14 Well: 2K10 AFE # 684633 AFE Amount: Current Amount: 0600 Depth: Day' 24- Hour Ftg: 6798' Current Operation: RIH with 3-1/2" drill pipe to drill out casing. Cemented 7" casing at 6789'. Made up BHA & RIH with 3-1/2" drillpipe (BHA includes 6" PDC bit and Neyrfor turbine). BPX/Unocal accepted rig operations on 12/19/89 at 1330 hrs. Wells Shut-In for Drill-By: Mud Type: WT: SURVEY MD. ANGLE VIS: PV: YP: FL: DIRECTION TVD SECTION Solids: Temp: ~F COORDINATES DLS BP EXPLOR~iON Daily Drilling Report -- Kuparuk December 21, 1989 at 0600 hrs Confidential Rig: DOYON 14 Well: 2K10 AFE # 684633 AFE Amount: Current Amount: 0600 Depth: 6925' Day: 24- HourFtg: 127' Current Operation: Drilling 6" hole. RIH with 3-1/2" drill pipe. Test casing 3000 psi. Drill out shoe and cement and 10' new hole to 6808'. Test formation to 12.5 EMW. Drill new 6" hole at 6925'. Wells Shut-In for Drill-By: Mud Type: NEW DRILL WT: 10.6 VIS:47 PV:25 SURVEY MD ANGLE DIRECTION TVD YP: 18 FL:4 Solids: 13 Temp' 83~ SECTION COORDINATES DLS BP EXPLOR~N Daily Drilling Report -- Kuparuk December 26, 1989 at 0600 hrs Confidential Rig: DOYON 14 Well: 2K10 AFE # 684633 AFE Amount: Current Amount: 0600 Depth: 7651' Day: 120- HourFtg: 0 Current Operation: Circulating to condition mud. Drill 6" hole to 7651' TD. Log with Schlumberger: DITE/ARRAY SONIC/NGT/AMS/SP/LTD/CNL/GR/EPT. Cut and recovered 18 Halliburton sidewall cores. Run Schlumberger SWS and RFT. RIH to 7651' with 3-1/2" drill pipe and 2-7/8" tubing stinger. Pump 15 bbls cement, POH to 7180'. Pump 15 bbl cement. POH to 6730', circulate and condition mud. Wells Shut-In for Drill-By: Mud Type: NEW DRILL WT: 10.6 SURVEY MD ANGLE VIS:44 PV: 18 YP: 19 FL:4.2 Solids: 16 Temp: 80°F DIRECTION TVD SECTION COORDINATES DLS BP EXPLORN'ION Daily Drilling Report -- Kuparuk December 27, 1989 at 0600 hrs Confidential Rig: DOYON 14 Well: 2K10 AFE # 684633 AFE Amount: Current Amount: 0600 Depth: 7651' Day: 24- Hour Ftg: 0 Current Operation: POH laying down 3-1/2" drill pipe. POH. RIH with bit and scraper to 6775', no cement. POH. RIH with EZ drill and set packer at 6770'. Squeezed 5 bbls cement below packer. Spotted 5 bbls cement above. POH. RIH wtih bit and scraper. Wash to 6700'; no cement. Test 7" casing to 3500 psi - OK. Found cement top at 6724' (65' inside 7" casing). Changed well to 10.6 ppg brine. POH. Wells Shut-In for Drill-By: Mud Type: NEW DRILL WT: 10.6 VIS'57 PV:22 SURVEY MD ANGLE DIRECTION TVD YP: 26 FL: 9.9 Solids: 16 Temp' 85 °F SECTION COORDINATES DLS. ARCO Alaska, Inc. Date' January 12, 1990 Transmittal #: 7648 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K- 1 0 CBT Log 12-30-89 4840-6716 Receipt Acknowledged' RECEIVED JAN [6 Date: Alaska Oil 8;. Gas Cons. Commtsstm~ Anchorage DISTRIBUTION: NSK Drilling St~f Alaska(+sepia) ARCO Alaska, Inc. Date- December 28, 1989 Transmittal #: 7638 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2 K - 1 0 OH Edit Tape and Listing I 2 - 1 7 - 8 9 # 7 3 6 0 0 Receipt Acknowledged' ............................. Date- DISTRIBUTION: Lynn Goettinger State of Alaska ..... _R_ECEIVED JAN J. 2 ]9~ Alaska 011 &' Gas Cons. Commissi~ Anchorage ARCO Alaska, Inc. Date: December 28, 1989 Transmittal #: 7634 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2K-1 0 2" Dual Induction- SFL 1 2-1 7-89 2997-6740 2K-1 0 5" Dual Induction- SFL 1 2-1 7-89 2997-6740 2K-10 2"Raw FDC 12-17-89 2997-6712 2K-10 5" Cyberlook 12-17-89 6390-6670 2K-10 2" Porosity FDC 12-17-89 2997-6712 Receipt Acknowledged: DISTRIBUTION: D&M Drilling ............................. Date' RECEIVED Franzen JAN 1 2 lggO Alaska Oil &' Gas Cons. CommlsSlOP Anchorage Vendor Package(Johnson) NSK State :of Alaska(+Sepia) MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smi~-:'~%/ DATE: Commissioner~ FILE NO: TELEPHONE NO: January 3, 1990 D.ADA.104 THRU: Michael T Minder '~'~' ~'~'~' SUBJEC~ Sr Petroleum Engineer BOP Test AAI KRU 2K-10 Permit No. 89-59 Kuparuk Rv Field FROM: Doug Amos ~ Petroleum Inspector Thursday, December 14, 1989: I traveled this date from BPX PBU to ~'KRU'~Wel'I "2K2-i'0' a'~'Doyon Rig No. 14 to witness the BOP test. The testing commenced at 5:30pm and was concluded at 7:30pm. There were no failures, and I filled out an AOGCC BOP inspection report which is attached. In summary, I witnessed the successful BOP test at AAI KRU 2K-10 well on Doyon Rig No. 14. Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOrE Inspection Report Inspector Operator Well ~t<- Location: Sec ~ Drlg contrctr -~O~JtJ:~J~ Location (general) General housekeeping Reserve pit ~ R ~)~ Rig # Well sign Rig MUD SYSTEMS: Trip tank Pit gauge Flow monitor Gas detectors Visual Audio BOPE STACK: Test Pressure Annular preventer / ~}C~ Pipe rams ~ ~ ~. U Blind rams ~ I !~ Choke line valves,/~l~ ~ ~ HCR valve ~' '1 ~ Kill line valves ~ ~ ~ ~ Check valve ~ ~ TEST RESULTS: Representative Permit # ~;[ ~/~ t~ Casing ACCUMULATOR SYSTEM: Full charge pressure Press after closure Pump incr clos press 200 psig Full charge press attained ft psig psig min .~ sec min -~c9 sec Controls: Master Remote KELLY AND FLOOR SAFETY VALVES: Upper Kelly j ~)~ Test pressure Lower Kelly j ~Y Test pressure Ball type I ~ Test pressure Inside BOP I ~ Test pressure Choke manifold I ~' Test pressure Number valves ~'~"-' Number flanges Adjustable chokes Hydraulically operated choke Failures J~CO~,J~____) Test time ~ :00 hrs Repair or replacement of failed equipment to be made within and Inspector/Commission office notified. days Remarks: Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 03/17/89) Inspector: BP EXPLORATION December 15, 1989 Mr. Chat Chatterton, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 RE: Notification of Commencement of Kuparuk 2K- 10 Tail Operation Dear Commissioner Chatterton' BP Exploration (Alaska) Inc. hereinafter "BP", wishes to advise of a change in report submissions to the AOGCC for the currently drilling Kuparuk 2K-10 well. We have discussed this previously with Commissioner Lonnie Smith, who advised that we should notify the Commission in this fashion, at this time. The Kuparuk 2K-10 well is currently being drilled by ARCO Alaska, Inc. as operator on behalf of itself, BP and Unocal. Commencing shortly, a tail operation will be drilled by ARCO as operator for only the benefit of BP and Unocal. At this time we expect this operation to begin on Monday, December 18. The tail will commence at a depth of approximately 250 feet below the base of the Kuparuk formation and is projected to bottom at approximately 1000 feet deeper. BP is named as tract representative on behalf of participants BP and Unocal. Because ARCO has elected not to participate in the tail operation, and should therefore not be privy to all well information, BP shall submit all required reports to the AOGCC. As per our discussion with Commissioner Smith, ARCO shall continue to be named as operator of the well, however. Upon completion of the operation, responsibility for filing the final well report shall be transferred back to ARCO. We appreciate the advice and cooperation of the Commission in this endeavor. Please call me should you have any questions. Yours very truly, Land Manager- Alaska EPZ/slb Alaska 0il & 8as Cons. Commlssio~'~,~ Anchorage OILAND GAS CONSERVATION COk ~'~ION 0 I1{ APPL, ;ATION FOR SUNDRY APPROVALS I1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X~ Operation Shutdown _ Re-enter suspended well_ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO Alaska, In(;;. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X.~ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 71' FSL, 94' FEL, Sec. 2, T10N, RSE, UM At top of productive interval (@ Target) 1220' FSL, 980' FWL, Sec. 1, T10N, RSE, UM At effective depth At total depth 1334' FSL, 1087' FWL~ Sec. 1~ T10N~ RSE~ UM 12. Present well condition summary Total Depth: measured true vertical feet Plugs (measured) feet 6. Datum elevation (DF or KB) RKB 154' GL 118' 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-10 9. Permit number 89-59 feet Effective depth: measured true vertical feet Junk (measured) feet None Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Size Cemented 10. APl number 50-1 03-201 06 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Change in directional program and drilling procedure to allow for an exploratory tail below the Kuparuk casing point. Detailed operation program BOP sketch 13. Attachments Description summary of proposal _ Change in drilling procedure and directional plan 14. Estimated date for commencing operation Spud estimated 10-21-89 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil ~ Gas __ Service Suspended Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~)~ ~ ~--.~~ Title Area Drilling Engineer FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No~) ~--?,,~ Plug integrity m BOP Test_ LocatiOn clearance ~ J Mechanical Integrity Test _ Subsequent form require 10- ~-c,~ ~ ,Yl-~:':.:''''':~, ",":' . . of Cutting Samples and a ?,Iud Log are required from the exploratory portion Approved by the order of the Commission JD~i~,,-'~'ll'c ¢,,.. c¢~,---,... Commissioner Date /<'. f,-";/'" ,::','"r,l i Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Addendum To Drilling Procedure Exploratory Tail Extension Kuparuk River Field Well 2K-10 . , , , o o , . . Well 2K-10 will be drilled per the normal Kuparuk Drilling Procedure to the 7" casing point just below the Kuparuk formation, then the following changes will be made. Run and cement 7", 29#, L-80 Casing. Test casing to 3500 psi. The higher weight casing will be run to allow for casing wear while drilling the tail extension. Install and test BOPE to 3000 psi. Pickup 6" bit and 4-3/4" bottomhole assembly. Drill out cement, float equipment, and 10' of new hole. Perform leakoff test to 12.5 ppg EMW. Drill 6" hole to logging point according to attached directional plan. Run open hole logs from TD to 7" casing point. Plug open hole with necessary cement plugs. All hydrocarbon zones will have a balance cement plug placed from 50' below the zone to 100' above the zone. The 7" casing shoe will have a cement plug placed from 100' below the casing to 100' inside the casing. · . Pressure test 7" casing to 3500 psi to ensure bottom cement plug is holding. Continue with completion activities per normal Kuparuk Drilling Procedure. ARCO ALASKA, I,~'__ Ped 2K. Well N' , 10 Kuperuk Field. .orth Revised Proposel SI ope, Al eeke 0 - RKB ELEVAT[ON~ 154' m rll rrl ! 000 _ 2000 _ 3000 _ 4000 _ 5000 _ 6000 _ ?'000 _ 8000. B/ PERHAFROST TVD=!424 T/ UGNU SNDS TVD--1544 KOP TVD=2007 THD=2007 DEP=O 3 T/ W SAK SNDS TVD=2163 THD=2]63 DEP=6 g BUILD 3 DEO 15 PER 100 FT 21 B/ W SAK SNDS TVD=2734 THD=2753 DEP=144 27 EOC / 9 5/8" CSG PT TVD=2934 THD=2975 DEP=240 K-lO TVD=3182 THD=3259 DEP-378 MAXIHUH ANGLE 29 DEG 2 HI N VERTICAL 27 24 21 18 15 12 9 6 BEGIN ANGLE DROP TVD=4467 THD=4728 DEP=1091 K-5 TVD=4570 THD=4845 DEP=1146 DROP 1.5 DEO PER 100 FT END ANGLE DROP TVD=5988 THD=6331 DEP=1557 T/ ZONE C TVD=6088 THD=6431 DEP=1566 T/ ZONE A TVD=6128 THD=6471 DEPTM1 569 TARGET CNTR TVD"61T1 THD=6514 DEP=lST3 B/ KUP SNDS TVD=6254 THD=6598 DEP-I580 ?" CSG PT TVD=6453 THD=6798 DEP=I59T TARGET #2 TVD=6754 T~D=TIO0 DEP=1624 TD TVD=T2T9 THD=T627 DEP--! 670 I 1 000 SECTION I 2000 TARGET ANGLE 5 DEG HOR I ZONT" ' PROJECT I ON SCALE I IN. " 1000 FEET ARCO ALASKA. [no. Pad 2K, Well No' 10 Revised Proposal Kuparuk Field, North Slope, Alaska z c3 I 3000 2000 1000 1000 WEST-EAST 1 000 0 1000 2000 I I I _ SURFACE 3000 TAROET m2 TVD-6?$4 Tt'ID-?IO0 DEP-1624 NORTH 1186 EAST 1109 SURFACE LOCATION, 71' FSL, 94' FEL SEC. 2. TION. RSE TD LOCATION' 1291' FSL. I0~' FWL SEC. 1. TION. RBE TAROET ,e2 LOCATION, 1257' FSL. 101'3' FWL SEC. I. TI ON. RSE TARGET CENTER TVD-6171 THD-6514 OEP-tS?3 NORTH 1149 EAST 1074 TAROET CENTER LOCATION, 1220' FSL. 980' FWL SEC. I. TION, RBE N 43 DEO 4 HI N E 1573' (TO TARGET) 2OO 150 100 50 50 100 150 I 400 100 50 0 50 1200 I 150 )0 22O0 / / 800 / 2400 t 2200 °1000 / ~'2600 I 100 0 1000 0 .i,,~1 000 400,'~ I 5O 0 5O 100 I / / ./ 2800 150 200 I 25O I ,00 6OO I 100 i 150 I 200 I 250 200 150 100 50 _0 ~ 50 _ 100 AL ,A OIL AND GAS CONSERVATION COMI~ APPLICATION FOR SUNDRY APPI-IOVALS ORIGI A 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program X Operation Shutdown _ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other X 2. Name of Operator ARCO Alaska. In~, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 71' FSL, 94' FEL, Sec. 2, T10N, R8E, UM At top of productive interval (@ Target) 1220' FSL, 980' FWL, Sec. 1, T10N, R8E, UM At effective depth At total depth 1334' FSL~ 1087' FWLr Sec. 1~ T10Nr R8E~ UM 12. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 154' GL 118' 7. Unit or Property name Kuparuk River Unit feet 8. Well number 2K-10 9. Permit number 89-59 10. APl number ~0-103-201 06 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Effective depth: measured true vertical feet Junk (measured) feet None Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Size Cemented Measured depth True vertical depth true vertical Tubing (size, grade, and measured depth Packers and SSSV (type and measured depth) Change in original permit due to the cored well being moved from 2K-10 to 2K-11. 13. Attachments Description summary of proposal Change in drilling procedure and directional plan Detailed operation program X BOP sketch 14. Estimated date for commencing operation Spud estimated 9-17-89 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas m Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,~~ ~ ~ Title Area Drilling Engineer / FOR COMMISSION USE ONLY Date ~7/~ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test_ Subsequent form require Approved by the order of the Commission Original Sig~ed Ely David W. Johnston 10- Commissioner IIAppr°val No.~ ~/~ Approved Copy Returned Date ~" I';L~' ~I Form 10-403 Rev 08/15/88 SUBMIT IN TRIPLICATE GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casin!). Pressure test to 3500 psig. 11) Downsqueeze Arctic pack~ and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13} Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17} Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 19) Change over to diesel. 20} Flow well to tanks. Shut in. 21} Secure well and release rig. 22) Fracture stimulate. III MUD CLEANER SHALE SHAKERS STIF gTIR STIR MUD CLEANER CENTRIFUGE TYPICAL MUD SYSTEM SCHEMATIC ARCO ALASKA, !n~ Pad 2K, Wei I No~ 10 Rev~eed Propoeal Kuperuk Field, North Slope, Alaeke 0 . RKB ELEVAT[OH ~ ! 54' I-- I'll "0 1 000 _ 2000 _ 3000 40OO. 5000 _ 6000 _ 7000., B/ PERMAFROST TVD=1424 T/ UGNU SNDS TVD=I 544 T/ W SAK SNDS TVD=2163 B/ W SAK SNDS TVD=2Z34 9 5/8" CSG PT TVD=2934 KOP- TVD=3084 TMD=3084 DEP=O 3 K-10 TVD=3182 TMD=3182 DEP=~ g 15 BUILD 3 DEG ~ 21 PER 100 FT r EOC TVD=4088 TMD=~141 DEP-285 K-5 TVD=4570 TMD 4708 DEP=583 AVERAGE ANGLE 31 DEG 43 MIN T/ ZONE C TVD=6088 TMD=6492 DEP=1521 \ ~ "l/ ZONE A TVD=6128 TMD=6539 DEP=1546 ~ TARGET CNTR TVD=6171 TMD=6590 DEP=157~ B/ KUP SNDS TVD=6254 TMD=6688 DEP=I624 TD (LOG PT) TVD=6424 TMD=6888 DEP=1729 I I 1 000 2000 VERTICAL SECTION HOR~-=IONTAL PROJECT I ON ~, ~JALE 1 IN. '- !000 FEET ARCO ALASKA, !ne, Pad 2K, We I I N,o, 10 Rev I aed Propose I Kuperuk Field North Slope, Alae~a 3000 2000 _ c~ 1000 _ 0 1000 _ WEST-EAST 1 000 0 1 000 2000 I I I / 3000 I TO LOCAT l ON ' 1334' FSL. 1087' FWL SEC. I. TI ON. R8E TARGET CENTER TVD=6171 THD=6590 DEP=I57'3 NORTH 1149 EAST 1074 TARGET LOCATIONt 1220' FSL. 980' FWL SEC. 1. TION. RSE SURFACE: LI:X~ATION, 71' FSL. 94' ~ SEC. 2. TION. R~ N 4.:3 DEG 4 MI N E !57'J' (TO TARGET) 25O I 25O 200 100 _ I I I I 0 . I I I I 1oo _ I I 200 / / / / / / / 1 50 1 O0 5,., I I I 14 / !~ I15 I O0 1 1 O0 '~ oo ~..~oo soo 150 =~~ I ~' 2900~- '~ 5 -* f~oo lO · 500 1 900 '"3500 / 50(~ / 3300 · 500 / / / 3700 )0 200 / / / / / ," 2700 · 500 / 7 2300 // '~00 ~,21 O0 2500 ~"~?oo · 500 30O ~'?~00 5O I i I 150 500 , , __ ! 100 50 0 I 250 200 150 100 5O 5O 100 150 June 5, i989 Te!ecopy.. (907) 276-7542 Patrick J. Archey Area Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 2K-t0 ARCO Alaska, Inc. Permit No. 89-59 Sur. Loc. 71'FSL, 94'FEL, Sec. 2, T10N, RSE, U~f. Btmhole Loc. 1233'FSL, 992'FWL, Sec. 1, T10N, RSE, UM. Dear Mr. Archey~ Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, aad does not authorize conducting drilling operations until all other required pe~itting determinations are made. To aid us in scheduling field work, plebe notify this office 24 hours prior to commencing installation ~f the blowout prevention equipment so that a representative of the ~ommission may be present to witness t~sting of the eq~ipm~t before tl~e surface casing shoe is drilled, ir_~ere a diverte~system is required, please also notify this office 24 hours ~rior to comme~cing equipment installation so that the Commission may witness testing before drillzng below the shoe of the conductor pipe V~ry truiz ~yours, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF ~E COb~MISSION dlf Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA L,,L AND GAS CONSERVATION CC,,,MISSION PERMIT TO DRILL 20 AAC 25.005 I la. Type of work Drill Re-Entry [] Deepen[]1 Service [] Developement Gas [] Single Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska~ Inc. RKB154'~Pad118'GL feet Kuparuk River Field 3. Address 6. Prop(~ :_y_ [:)rt esiAL~ nati26_~ n P.O. Box 100360, Anchorage, AK 99510 ADL 25588 Kuparuk River Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20AAC 25.025) 71' FSL, 94' FEL, Sec. 2, TION, R8E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well nu .tuber Number 2K-10 U630610 1220' FSL, 980' FWL, Sec. 1, T10N, R8E, UM At total depth 9. Approximate spud date Amount 1233' FSL, 992' FWL, Sec. 1, T10N, R8E, UN 6/10/89 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposeddepth (MD and TVD) property line 2K-7 Conductor, 671 6'MD 4047' at TD feet 25' at surface feet 2560 6383' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth 2091 feet Maximum hole angle26 0 Maximum surface 1700 psig At total depth (TVD)2934' psig 18. Casing program Setting Depth size Specifications Top Bottom Ouantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80 35 35 ' 115 115 ' +200# Cf 12~" 9-5/8 36.0# J-55 BTC 2929 35 35 ' 2964 2934 ' 600sx AS111 HF-ERW 400sx Class G 8½" 7" 26.0# J-55 BTC 6682 34 34' 6716 6383' 200sx Class G tail HF-ERW Top of G 500' 19. To be completed for Redrill, Re-entry, and Deepen Operations. above Kuparuk Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural ConductorRECEIVED Surface Intermediate ProductionMAY J i 198.9 Liner Alaska 0il & Gas Cons. Commission Perforation depth: measured Anchorage true vertical 20. Attachments Filing fee Drilling fluid program 21. I hereby cert,.j,fy that the foregoing is true and correct to the best of my knowledge Signed F~,-~f¢,.~ ~---~ ~_,~%~.,,_ -'~,"/ Title Areal)rillingEncjineer Date ~Commission Use Only PD1/3 (JTP/TWM) Permit Number I APlnumber IApprovaldate I See cover letter ~j,¢ .~-~ 50-- /0,3,.- ~.c-J/.,O,_.~2 06/0.5 / 8o2 for other requirements Conditions of approval Samples requir, ed [] Yes I~ No Mud Icg required [] Yes J~ No Hydrogen sulfide measures [] Yes '~ No Directional survey required ]~ Yes [] No Required working pj:.essure, for BOPE E32M; ,~3M; [] 5M; [] 10M; [] 15M Other: ~'~~~.~ - by order of Approved b Commissioner the commission Date Form 10-401 Submit if triplicate GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMEN~ WELLS WITH SURFACE HOLE LOGS AND KUPARUK COKES 1. MIRU. 2. Install FMC diverter system. 3. Drill 12¼" hole to 9-5/8" surface casing point according to directional plan. 4. Run open hole logs through surface hole (West Sak) per well plan. 5. Run add cement 9-5/8" casing. 6. Install and test BOPE. Test casing to 2000 psig. 7. Drill out cement and 10' new hole. Perform leakoff test. 8. Drill 8½" hole to core point according to directional plan. ~'9. Core Kuparuk sands as specified in well plan. 10. With coring complete, continue drilling 8½" hole to logging point total depth. Leave 100' between PBTD and base of Kuparuk Sands. 11. Run open hole logs per well plan. 12. Run and cement 7" casing. Pressure test to 3500 psig. 13. Downsqueeze arctic pack and cement in 7" x 9-5/8" annulus. 14. ND BOPE and install temporary Xmas tree. 15. Secure well and release rig. 16. Run cased hole logs. 17. Move in workover rig, Nil BOPE. 18. PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 19, Perforate and run completion assembly, set and test packer. 20. ND BOPE and install Xmas tree. 21. Change over to diesel. 22. Flow well to tanks. Shut in. 23. Secure well and release rig. 24. Fracture stimulate. RECEIVED OEGA$$ER MAY ~ 1 1989 Alaska Oil & Gas Cons. Commissio~ Anchorage MUD CLEANEFI 8HALE 81HAKEFI$ STI 8TlR 8TlR TYPICAL MUD SYSTEM SCHEMATIC DRILLING FLUID PROGRAM Spud to 9 5/8" Drill out to Ourface casing Weight up Density 9.6-9.8 8.7-9.2 PV 15-30 5-15 YP 20-40 8-12 Viscosity 50- 100 35-40 Initial Gel 5-15 2-4 10 minute Gel 15-30 4-8 Filtrate API 2 0 10- 20 pH 9-10 9.5-10.5 % solids 10 + 4- 7 Weight up to TD 10.0 11-16 8-12 35-50 3-5 5-12 6 9.0-10.5 12-15 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators RECEIVED MAY 3 1 1~8~ Alaska Oil & Gas Oons. Com,'nissioa Anchorage 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 13.0 ppg EMW and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. There are no wellbores within 200' of this proposed well since It is the fourth well to be drilled on the pad. The first three wells are at least 175' away at the surface, which would be the closest point. Excess non-hazardous fluids ~leveloped 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 shutdown in pumping operations. The annulus will be sealed with 175 ax of cement followed by arctic pack upon completion of the fluid pumping. KUPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I 6 DESCRIPTION 1. 16' CONDUCTOR 2. FMC SLIP~:DN WELD STARTING HEAD 3. FMC OlVERTER ASSEMBLY WITH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL W/10' OUTLETS 5. 10" HCR BALL VALVES W/10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY ~ TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2(X)0 PSI ANNULAR PREVENTER ARCO ALASKA, INC.. REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 3 UPON INmAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PFIOPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES RECEIV[D Alaska Oil & Gas Cobs. Cornmissb[i Anchorage JG 4/26/88 7 6 D~~ el 5030 I~]: ~ BI~ ~I'AC~ ACX:LM.LATC~ CAPACITY I. CI-ECI( ~ FILL ACCUM. LATCR RESERVOIR TO LEVEL RZTH ~IC FLUID, 2. A~JRE THAT ACC:LM.LATCR ~ I~ ~ I~JI I~:10 PSI DI:~I~TREAM ~ TI,~ I~GLLATCR. 3. ~ Tlt~.. TI,,EN ~ aLL., I,JNZ'I~ SZM.LTN~' AFO REC:Cla) 11,,E TII~: N~O ~ REM~INIM:; AFTER 4. I~~ ~ ~ RE]:K~q'. TI~ ~.IIBLE: LCI~ER LIM.I' ]~ 45 ~~ G. Cl6]~ T]I~ N~) 1200 I:"1] 5 RECEIVED- Anchorage 4 3 2 1~/8' BOP STACK TEST I. FILL ~ 5'1'AC3( ~ CHiI<E IdlM~FI:I.O W~TH ARCTIC DIESEL. 2. 0,~ TIMT ,eLL. LOCK ~ ~ IN ~ FLLLY I~'TRACrE~ SEAT TE~T PLUG IN I~ELU,F..aD W/TH la.t~IIk~ JT ~ ~ IN kOa<DI31~ ~ LIllE V,~L. VF.S ABJA(/NT TO BI~ ~l'/Ot,. ,M,L. 4. I::~ESSU~ UP TO 2~0 ReJZ MD I,O.D Fl:IR I0 CREA~ ~Lrggj~ TO ICXX) PgZ N~) I.IX.D I~1~ I0 I~1~ BLEED PllEggI. RE TO 0 IXJZ. LII~: W~.VES. CLCSE TCP PlI=E RM~ ~ Ha~ V~vF..S CN KILL ~ O4al<E 6. TE:ST T0 ~ PSI /It4) 3:1:10 1="31 /t~ IN STEP 4. ?. CO~I~ TE:STIkG ALL V,e&.VE3. LII~E~, JIN) WiTH a 250~I LC3W AI~ 301:X) ~I HIGH,, 8. a=EN TCP PIl:~ ~ MI} ct.agE BOTT(IM PIPE: RAM~ TEST BOTTCI4 PIPE: ~ TO 2~0 I~! MI) ~ l:~I. g,. ~ BOTTCM PlI~ ~ BAa( 01JT ~ J'l' AM:) I0. CLCI~ 81.]1~ ~ AM:) TEST TO 2~ I~! AN:) 30eX:) FLUID. SET ALL VaLVEII IN CRZLLZNG PC~]TICI~ 12. TEST b"T~]~ VALVE:~ KILLY. KELLY CO0~ PI:I:~SA~'ETY W~LVE. AI~ Zl~Zl:1: BlIP TO :2:80 PS! tOO0 PS]. FARM, SIGN. ~ ~ TO CRILL. II~ I~:.EIG.Y ~ FLN~ICNALLY ~TE ~ ARCO ALASKA. !no. Pad 2K. Well Not 10 Propo,ed Kuparuk Field. North Slope. 0 . RI(B ELEYAT[ON~ 154' 1 000 _ 2000. m 3000 m 4000 B/ PERHAFROST TVD=1424 T/ UGNU SNDS TVD'1544 KOP TVD-2Ogl TMD=2Ogl DEP-O 3 T/ 14SAK SNDS TVD-2163 THD-2163 DEP-! 9 BUILD 3 PER I00 FT B/ 14 SAK SNDS TVD=2734 THD=2747 DEP-112 I EOC TVD=2933 THD=2963 DEP=I96 g 5/8' CSG PT TVD-2934 THD-2964 DEP-lg6 K-lO TVD--3182 THD-3240 DEP-318 MAXIMUM AN GLE , , .... ,!!?Fb 26 DEO 9 MI N Alaska Oil & (~; C'orr~ Oommi~io[l Anchorage K-5 TVD-4570 TMD-4?8? DEP-tO00 5000 6000 7000 24 21 18 I$ · , I 1000 BEGIN ANGLE DROP TVD=5031 TMD=5301 DEP=1226 DROP 1.5 DEO PER 1 O0 FT END ANGLE DROP TVD=Sg21 TMD=6245 DEP=1534 T/ ZONE C TVD=6021 TMD=6347 DEP=IS$5 T/ ZONE A TVD-6061 TMD=6388 DEP-1564 TARGET CNTR TVD-6104 THD-6432 DEP-1573 B/ KUP SNDS TVD-6187 THD-6516 DEP-1590 TD (LOG PT) TVD-6383 THD-6716 DEP-1632 , TARGET ANGLE 2000 12 DEO VERTICAL SECTION HO'~' ZONTAL PROJECT I ON'~-~ SCALE ! IN. = 1000 FEET ARCO ALASKA. !.o. P.d 2K. Well No~ 10 Peopome~l Kupeeuk Field. No~th Slope. Almeke z 3000 2000 . 1 000 1000 _ WEST-EAST 1 000 0 1000 2000 I I I 3000 I TD LOCAT [ ON' 12.,33' FSL. g92' FWL SEC- I. T 1 ON. RSE TAROT ~NTER TVD-6104 TH0-6432 OEP- 1573 NORTH 1 149 EAST 107'4 TAROET LOCAT [ ON t 1220' FSL. g80' FIlL SEC. I. TION. RSE SURF'~ LOCAT [ ON t TI' F91... 94' FEL gee. 2. TI ON. RSE N 43 DEI~ 4 MI N E 1573' (TO TARGET) 250 200 1 50 1 O0 50 0 50 450 - 400 350 300 . 250 _ 200 _ 150. 100 50 . ",1, 300 % \ \ \ "'*'4 300 \ \ \ \ \ ~,1100 \ ~,~oo~ /too I '~joo ~ //soo I \ "',~oo \ soo '~ kl O0 %7'00 ' 500 500 · = 2900 / / / -- ~' 1 500 --"i'3oo ~ /"2700 ! ! 2500 ! / .,,. / 2300 ° 500 I I i i i ' i 250 200 150 1 O0 50 0 i 45C 40C 35C 30C _ 250 .20C _ 15C _ 10C _ 50 ARCO Alaska, Inc. Post Office Box ~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 12, 1988 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- Conductor As-Built Location Plat- 2K Pad (Wells I - 24) Dear Mr. Chatteron' Enclosed is an as-built location plat for the subject wells. any questions, please call me at 263-4618. Sincerely, If you have D. Martin Engineering Aide DM-hf Enclosure RECEIVED DEC 1 ]988 Alaska 0il & Gas Cons. C0mmissim~ Anchorage GRU13/010 ft~ ldC'~m ,in ARCO Alaska, Inc. is ¢ Subsidiary of AtlanlicRich ' , ~ . p, y N.T.S. SECTION 2 . 'IECTION I I %-.,'"- ' e~ ~e· ~? 16:~9 WELLS 1'12 ARE LOCATED IN SECTION 2, T I0 N., R. 8 E., UMIAT MERIDIAN. WELLS 13-24 ARE LOCATED IN SECTION II,T. ION., R. 8 E., UMIAT MERIDIAN. SECTION I PROTRACTED Notes: SECTION CORNER 3~' 36 ~THIS ~URVEY VI MAP T ION ~ I. COORDINATES ARE A.S.P. ZONE 4. SECTION 12 2. ALL DISTANCES SHOWN ARE TRUE. $. ELEVATIONS ARE B.P.M.S.L. RECEIVED DEC 1 ~ 1988 4. O.G. ELEVATIONS FROM CED-RIXX-3$11, rev. 4. 5. HORIZONTAL POSITION BASED ON 2-K CONTROL MONUMENTS PER LOUNSBURY & ASSOCIATES. 6. REFERENCE FIELD BOOK: L 88-40, pgs. 55,56, 58,59, 65 I~ 66. .1 ' , , ASP's , , Alasi,,a Uil & C:~..~s Fgu,,:.-,. [JO[i' m;3'3:g:: Dist. Dist. O.G. Pad · Y X L~dD~ LONGITUDE F.S.L. F.E.L. Elev. Elev. I 5,958,G00. 18 498,$10.17 70° 14'`5G .519" 150o00'49.1`5:5'' 296' 94' !14.0 118.5 2 5,9.58,575.14 498,`510.28 70° 14' `56.27`5" 150°00'49.150'' 271' I 1`5.9 `5 5,9`58,550.`50 498,`510.`55 70° 14-' `5G.029" 150°00'49.128'' 246' I 1`5.8 4 5,g58,525.4G 49 8,`510.0G 70°14' `55.784" 150°00'49.1`56'' 2:>::>' 11`5.8 5 5,9`58,500.19 498,`510.12 70°14' 35.536" 150°00'49.1`54'' 19G' 11`5.8 6 5,938,475.14 498,310.33 70014'35.289'' 150°00' 49.12:8" I?1' 113.8 7 5,9`58,450.36 498,310.36 70°14'35.046" 150°00'49.127" 146' I 1`5.8 8 5,9`58,425.30 498,`510.18 70014'`54.799'. 150°00'49.132:'' 121' 11`5.8 9 5,9`58,400.30 i 498,309.98 70014. `54.553" 150°00'49.137" 96' 113.8 I0 5,958,375.19 498,510.14 70014'34.306'' 150°00'49.133'' 71' I 11`5.9 I I 5,938,350.22 498,310.14 70°14'`54.061 " 150o00'49.1`53" 46' ,r 11`5.9 12 5,938,$25.20 498,310.17 70°14'`5`5.815" 150 °00' 49.131" 21' 94' 11`5.9 118.5 FN.L. 1`5 5,9`58,2`55.`51 498,`510.37 70°14'`52.930" 150°00'49.125" 69' 94' 11`5.7 118.5 15 5,938,185.1Z 498,310.16 70Ol4'32.437" 150°00'49.151'' 119' tl3.8 16 5,938,160.11 I. 498,`510.20 70°14'32.191'' 150°00'49.1`50'' ~44' 11`5.8 17 5,938, 1`55.21 498,`510.18 70°14'`51.946" 150°00'49.130" 169' 115.9 18 5,9`58, 110.19 ! 498,310.29 70°14'31.700" 150°00'49.127" 194' 114.0 19 5,938,085.~0 ! 498,310.27 70014' 31.454" 150°00'49.127" 219' 114.0 j II I ' 20 5,9~8,060.14 498,`510 .Z2 70°14' $1.207,, 150000 49. '28" 244' i 114.1 21 5,938,055.16 498,310.16 70Ol4'$0.962 150°00'49.1`50'' 269' 't 114.0 22 5,938,010.40 498 `510 19 70°14'30.718'' 150°00'49.129" , · 294' 94' 114.0 2`5 5,9`57,985.3z 498,`510.13 70014' $0.47t" 150000'49. 130" 319' 95' 114.0 24 51937,960. Z9 498,310.08 70 °14' 30.225'' 150° 00'49. 132'' 344' 95' I 115.9 118.5 I HEREBY CERTIFY THAT I AM ARCO Abska, Mc. BY ME OR UNDER MY DIRECT SUPER- VISION AND THAT ALL DIMENSIONS PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS .... ........... ....:..., PL-AT REPRESENTS A SURVEY MADE ~_ ,_,..~~ d '~ · C.,e~ALD 'f~'~:.". IS- 6299 .." .~,_~' ,, AND OTHER DETAILS ARE CORRECT AS OF NOVEMBER ZO~ 1988. DRILL SITE 2.K CONDUCTOR AS-BUILTS Or. ~y.' M.O'D CA. &),. ;,~'G /¢/ SA/'. I cC I Oefe.'ll/2i/88 ] Ote'g. No. NSK 6.21 I. d 4 CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee '' (2) Loc (2 thru 8) (8) (3) Admin ,~ ¢/,,~ (9 thru 1 3)' .,,Izz.~.,r-z-<. /., - i (10 and 13) (4) Casg (14 t~ru 22) (2.3 thru 28) Company Lease & Well No. YES NO A, Rco 1. 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 ...................... . 10. 11. 12. 13. Does operator have a bond in force .................................. Is a conservation order needed ...................................... l~- Is administrative approval needed ................................... ., Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 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 ~Od)C; psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. REMARKS (6) OTHER ~fV r_..l'~ (29 thru' 31) (6) Add: Geology: RPC Eng%rkeerin~ :/ 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 ............................................. Additional RemarkS': INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE ,,./,/o/00 ~,v .- t o;~2 ~?o t//c o ow' Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX.. No special'effort has been made to chronologically organize this category of information. ALASKA CO~iPUTING CENTER ****************************** ****************************** COMPANY NA~E : ARC(~ ALASKA, INC, WELL LAME : 2K - 10 FIELD ~.AME ~ KUPARUK BOROUGH : NORTH SLOPE STATE : ALASKA API NUMSER : 50'~03'20106-00 REFERENCE N(3 : 7]600 TaPe Yerlfication Listing 2!-DEC-1989 13:52 DATE ~ 89/12/2!. ORIGIN : FLIC REEL NA~E : 73600 CONTINUATION # PREVIOUS REEL COMMENT : ARCO ALASKA, !NC,,KUPARUK,2K - !0,50-I03-20!06-00 **** TAPE HEADER **** SERVE IC.~ NAME : EDIT DATE : 89112/21 ORIGIN : FLIC TAPE NAME : 73600 CONTINUATION # : PREVIOUS TAPE : =CO~MENT : ARCO AL.ASK.A, INC,,KUPARUK,2~ - I0,50'~03-20!06~00 **** FILE HEADER **** FILE NA~E ~ EDIT ,001 SERVICE : FLIC VERSION : O01A04 DATE : 89/12/21 MAX RFC SIZE : 1096 FILE TYPE : bO LAST FtbE : ** ~* ** SCHLUMBERGER WELL SERVICES ** ******************************************************************************* COMPANY NA~E: ARCO ALASKA, INC, WELLg 2K - 10 FIELD~ KUP~RIJK 80ROUGM~ NORTH SLOPE STATE: ALASKA API NUMBER: 50-103-20106-00 LOCATION: 71' FSb & 94' FEL SECTION: 2 TOWNSHIP: iON ~ANGE: 8F~ PER~ANENT DATUM: MSL ELEVATION: 0 LOG ~EASURED FROM RKO !54 ABOVE PERMANENT OATU~ Tape Verlficati, onA Listing :hlumberger !ask:a ComPuting Center 21,-DEC-!989 PAGE~ ELEYATIONS DATE bOGG~D: RUN NUMBER: TD DRILLER: TD bUGGER: CASING KB1 154 DF: 153 !13 679~ 6746 9 5/8" LB ~ DRILLER DEPTH Of~ -- TO 3000 AND LOGGER DEPTH OF -- TO 2997 BIT SIZE 1: 8 112" TYPE FLUID IN HOLE: LSND POLYMER DENSITY: 10.6 VISCOSITY: ~9 PM: 9 FLBID LOSS: 3,6 MUD RESISTIVITY: FILTRATE RESISTIVITY: MUD CAKE RESISTIVITY: 2,92 ~ 65 ,96 M 66 ,24 ~ 6~ TI, ME CIRCULATION ENDED: 11:00 DECEMBER 17 TI~E LOGGER ON BOTTOM: 17:49 DECEMBER !7 MAXIMUM TE~P RECORDED: 142 LOGGING DISTRICT: LOGGING ENGINEER: WITNESS: PRUDHOE BAY TOOL NUMBERS: IE~-BD 1347 SGC-OC 2626 PGC-jA 1041 DIS-~iC 1457 NLM-LC !329 CNC-A 2122 PGS-HB 50B DIC-OA 1308 FIELD RE~ARKS: 1-1/2" STANDOFF ANO BASKET BOTTO~ ~OSE USED ON DIT, ~ATRIX DENSITY = ~65 G/CC FLUID DENSITY = 1.©~G/CC NEUTRON MATRIX MAXIMUM DEVIATIO~ : .4 DEGREES ~ 3589 , 80WSPRING USED ON CNL, PAD ELEVATION : 118' HIGH RESOLUTION PASS'LOGGED BU~ NOT PRESENTED TO FILMS, HIGH RESOLDTIOM USED FOR THE REPEAT PASS. DATE JOB STARTED: 21-DEC-89 JOB REFERENCE NO: 73600 L~P/ANA: SINES ****************************************************************************** * * FILE ' EDIT,O01 * * ARCO At, ASKA, INC. TaPe Verification Listtnq 2blumberger Alaska ComP~ltin~ Center 21-D5C-1989 !3:52 , , KUPARUK 2K - 50-103-20106-00 MAIN PASS LOG DATA AND GAMMA RAY IN CASING DA~A SAMPLED EVER¥'-,50oo FEET DATA INCLUDED - TOOL EXTENSION TOOL TYPE USED NAME DIT-D ,DIL FDC .FDC CNT-A/D/M ~CNL DUAL INDUCTION SFL FOR~ATI:ON DENSITY' COMPENSATED NEUTRON GA~A RAY TABLE TYPE : CONS TUNI VA[,U DEFI Company Name CN ARCO ALASKA, INC, Flelo Name FN AFIN FL SECT TO~ R~.NG COUN STAT NAT! L~TI LONG ~ITN SON PDAT EPD APD EKB EDF EGL TDD TCS TLAB FT FT FT FT FT FT FT KIIPARUK 2K "' 10 50'103'20!06'00 71' FSL & 94' FEb 2 10~ 8E NO~TH SLtlPE DIXO~/LOWEN/UCGIMSEY 549102 MS[, O, 154. 154, 153, t740, 970 111(~0 [)ECE~,~IaER 17 17:49 DECEMBER 17 Well Name AP! Serial Number Field hocation Section Township Range County State or Province Nation Latitude Longitude Witness' Name Service Order Number Permanent datum Log Heasured FTO~ Bottom Log Interval Top Loo Interval Time Circulation Stopped Time Logger At Bottom Tape Verification Listir~g ~lumberger Alaska Computing Center 21-D~C-19~9 !3:52 TUNI VALU DEFI STE~ DEGF -999.25 TABLE TYPE : CURV DEF! DEPT Depth Channel Name ISD Dee~ Induction Standard processeO ~esistiv~t¥ IL~ ~ed t~.~ InduCtS. On ,Standard Processed ~esJ~sti SFLU SF5 Resistivity (u~avera~ed) SP S Ontaneous Potential GR G~mma ~av T~NS ~ens~on DPHI' Density Porosit~ RHOB BuI.~ Density DRHO Delta RHO FFDC Far FDC Count Rate NFDC Near FDC Count:, Rate CAL! Caliper GR Gamma Ray TENS Tension NPH! Neutron Porosity NP, TDer. mal Neutron'Porosit¥ NRA Calibrated Thermal Neutron Ratio NPOR Neutron Porositv Output From an Application Program RCNT' RCNT RCFT RCFT CNTC CNTC CFTC CFTC GR Gam~a Ray CAL! Caliper TENS Tension GR Gamma Ray TENS Tension DATA FORMAT SPECIFICATION RECORD ** SET TYP~ - 64EB ** TYPE REPR COD~ VALUE 1 66 0 2 66 0 3 73 112 4 66 5 66 6 73 Tape Yerification 51stin~ .-I~Xumberger AlasKa Come, ut, lng Center 21-DEC-t989 !3:52 TYPE REPR CODE VALUE 7 65 ~ 68 0{5 9 65 F. 1! 66 9 12 68 1.3 66 0 14 65 FT 15 66 68 16 66 ! 0 66 0 SET TYPE - CHAN ** NAMF SERV UNIT SERVICE API API AP1 AP1 FILE NUMB NUmB SIZE REPR PROCESS ' ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELEM ' CODE (HEX) DEPT FT 549102 O0 000 O0 0 i 1 I 4 68 0000000000 XLD OIL Og~ 549102 07 120 46 0 ! i i 4 68 0000000000 X~M DX5 0~ 549102 07 120 44 o 1 1 1 4 68 0000000000 8FLU OIL OHMM 549102 07 220 Ol 0 1 1 I 4 68 0000000000 sP DX5 ~v 5~9i02 07 OlO 01 0 t X X ~ 6~ 0000000000 GR OIL GAPI 549~02 ~7 3~0 O1 0 I I I 4 68 0000000000 ~ENS OIL LB 549~02 ~7 635 21 0 1 ! I 4 68 0000000000 OP~! FDC PU 549102 07 635 21 0 ! 1 1 4 6. 0000000000 ~o~ ~'oc ~/c] s4~lo~ o7 ~so 02 o ! 1 i 4 60 oooooooooo DRMO FDC G/C3 549102 07 356 Ol 0 i i 1 4 68 0000000000 FFDC FDC CPS 549102 07 354 02 0 i 1 1 4 68 0000000000 NFDC FDC CPS 549102 07 354 01 0 1 1 I 4 68 0000000000 CAL! FDC IN 549102 07 280 Ol 0 1 ~ ~ 4 68 0000000000 GR FDC GAPI 5~9102 07 310 O1 0 1 I 1 4 68 0000000000 TENS FDC LB 549102 07 635 2i 0 I ! 1 4 68 0000000000 NP~I CNL PU 549102 07 890 O0 0 1 1 1 4 68 0000000000 TNPN CNL pu 549102 07 890 OD 0 1 1 1 4 68 0000000000 TNRI C~L 549102 O? 420 O1 0 1. 1 1 4 68 0000000000 NPOR CNb PU 549102 07 890 O0 0 1 1 1 4 68 0000000000 RCNT CN~ CPS 549102 07 420 O1 0 1 ! 1 4 68 0000000000 RCFT CNL CPS 549102 07 420 O1 0 I 1 I 4 68 0000000000 CNTC CNL CPS 549102 07 420 O1 0 1 1 I 4 68 0000000000 CFTC CNL CPS 549102 (37 420 O1 0 1 1 I 4 68 0000000000 GR CN5 G4PI 549102 07 310 O! 0 I I 1 4 68 0000000000 C~LI CNL I~ 549102 07 280 O1 0 1 1 ! 4 68 0000000000 TENS C~L LB 549102 07 ~35 21 O 1 1 1 4 68 0000000000 GR CSG GAPI 549102 07 316 01 0 I 1 I 4 68 0000000000 TFNS CSG LB 549102 07 635 21 0 I 1 1 4 68 00000~0000 DATA IS TaPe Verification [,lstlng we chlumberger AlasKa Computing C..nter DEPT, 6760,000 SP,DIL '52,000 RHOB,FDC 2,499 C LI. FDC 8,158 TNPH.CNL 38;197 RCF~'CN5 532.687 !LO,DIb DRHO.FDC GR FDC T.NRA CNL CNTC CN5 TENS CNL DEPT SP ~CFT CAL! OIL FDC FDC CNL 6700'00 '30,00 2,40 8 49 4] 35 497 47 8 49 ILD,DIb GR,DI~ DRHO,FDC GR.F[C TNRA,CNL CNL hTC,,,~ ~ENS.C.tL DEPT, s., C!,LI, RCFT, CATi~ DIL FOC FDC CNL 6600, 2' O0 5O 47 55 97 91 55 Ga CNTC ,DIIL FoC ,CNL 'CNb DEPT, R~OB;FOC CAbl;FDC TNP~;C~L RCFT,CNL 6500.000 '42,000 2.444 8 500 ~9 318 917 620 8 500 I I,:,D · DRH FDC GR,FDC TN~ ' CNL ~NTC'CNL ~ENS, CN L DFPT, SP,DIL RHOB.FDC CALI,FOC TNPH'CNL RCFT,CNL C~LI.CNb 64o0.00 -42,50 2,36 ~,50 44,4! 454.57 8.50 ILD,DIL DRHO.FDC G~.FDC TNR~.CNL CNTC.CNL TENS.CNL DEPT, SP,Dlb RHOB,FDC CALl FDC TNPH:CNL RCFT CNL CALI:CNL 6300.00 -46.50 2.38 8.56 44,63 485.52 8.56 ILD,DIL GR.DIL DRHO.FDC GR.FDC TNRA CNL CNTCiCNL TENS.CNL DEPT. SP.DIL RHOB.FDC CALI,FDC TNPH.CNL RCFT.C~L CALI,CNL 6200 -47 2 44 536 ,000 ,000 .391 ,672 3~3 ~057 .672 ILO DIL GRiDIL DRHO FDC GR.FDC TNR.A CNL CNTCiCNL TENS,CNL 21-OEC-1989 13152 2,0~1 IOB,875 0 5 3 273 !920 854 27B40CiO 2,164 115,500 0,013 115.500 3,655 i944,575 4280,000 2 834 !1.7 375 0 048 117 375 3 305 2 42 571 4 $8. ooo 6.508 82,625 0.006 ~2 625 279~ 723 77~ 41~4 000 1,582 121,500 0,006 121,500 3,687 1798.957 2.460 156.500 0.013 156.500 3 ~31 1877~670 3990.000 1,479 226,625 0 04! 226i625 3 472 2067713 3930.000 lbS,lOlL TENS'DIL FFDC~FDC T NS F C NPOR,CNL c c,cm GR,CSG Ib~,DIL TENS,DIL FFDC,FOC TEN$,FDC NPOR.CNb CFTC,CNb GR,CSG iL~., DIL TEN$,DIL FFDC, FDC TENS.FDC NPO~, CFTC, CN L GR,CSG IL~,DtL TENS,DIL FFDC,FDC TENS,FDC NPOR,CNb CFTC,C~L GR,CSG ILM.DIb TENS,DIL FFDC,FDC TENS.FDC ~POR,CNb CFTC,CNL G~,CSG IL~.DIL TENS.DIL FFDC,FDC TENS.FOC NPOR,CNL CFTC,CNL GR,CSG , 2784' 473, 2784~ 38. 597, -999' 2, 4280, 528, 280, 442 54g' 2 4188 489 4!88 41 64 , -99 , 6 4184 472 105~ -999 4!84' 575. 4184. 43 499i -999 2. 3990 555 3990 45 -999 1 3930! 586 3930. 44, 573. =999. 251 000 250 000 1.97 611 250 309 000 OOO .000 301 8O8 25O 779 000 25O 000 415 71~ 2:50 877 000 750 000 566 126 250 685 000 500 000 951 263 250 557 000 000 000 676 857 25O 510 000 500 000 402 813 250 SFLU,DtL DP~:I.FDC NFDC,FDC ~P~I,CNL RCNT,CNL GR;CNL TENS,CSG SFLU,DIL DPM~ FDC NFD~ FDC NP~{I CN~ RCNT CNL GR CN5 TENS CSG 5FLU.DIb DPHI FDC NFDC FDC NPHI CNL GR CN~ TE~'S CSG SFL[J,DIL DPHI.FDC ~iFDC,FDC NPH!*CNL RCNT,CML :TFNS'CSG SFLU,DIL DPHI..FDC NFDC.FDC NPHI CNL RCNT:CNL GR CNL NS:CSG SFLU DIL DPHI:FDC NFDC,FDC NPHI,CNL RCNT,CNL GR CNL TEN$:CSG SFLU.DIL DPHI,FDC NFDC.FDC NPHI CNL RCNT:CNL GR,CNL TENS.CSG PAGEI 2,623 9 156 620 000 39 507 1894 278 108 875 -999 250 3 478 4 054 188~ 125 O0 "9 9 lO, 4 615,000 39,~ 2048, ~i 8,190 12'492 569;500 29.'7~0 274.1.,~7 l 82,625 -999,250 2,175 6~ 7'98 2'500 46,61! !790'9~ 121,50~ '999,250 500 49 177 1813 8t2 156 500 -999 250 2,353 15,726 642,000 42.443 035.461 2226,625 '999,250 Tape verification Listing .~hlUmberger AlasKa Computing Center DEPT, SD DIG R H 0 B F D C TNPH CNG CALI CN'5 DEPT RHOB FDC CAhl FDC TNPH CNG RCFT CNG CAI~I DEPT. SP,Dib RHOB,FDC .CALI.FDC TNPH,CNb RCFT.CN6 DEPT, SP,DIL RHOB FDC CASI:FDC TNPH RCFT~CNL CALI.CNL DEPT Sp' ,DIL RHOB,FDC C~I,FDC ~NPH,CNL RCFT.CNL CALI.CNL DEPT. RHOB,FDC CALI.FDC TNPH, NL ~CFT,CN5 6100 000 -58 500 2 457 9 148 4! 152 504 444 9 1.48 6000,000 -62.500 2 456 8 555 37 44] 624 8,555 5900,000 '60,000 2,331 8,398 47,713 456.855 8.398 5800 000 ~63,500 2,441 8,656 32,419 897,024 8,656 5700,000 "76.750 2 488 9 266 38 234 582 626 9,266 SilO0 000 -80~750 2,412 8,797 31,037 925.682 8,797 5~00,00o 85,000 2,383 8 977 728.996 IGD.DIb GR DIG DRHO FDC GR FDC TNRA CNG CNTC CNG TENS CN5 ILD,DI~ GR,D DRHO,FDC GR'FDc TNRA,CNL C~TC;C~ !LD,DIL DRHO'FDC CNTC.CMb TENS,CNb .ILD.DIL GR,DIL DRHO f[C GR:FDC TNRA.CNL CNTC.CNb TENS.CNh [bD.DIb GR.DIb DRHO.FDC GR.FDC TNRA.CNb CNTC.CNb TENS.CNG IbO.OIb GR DIL DRHO:FDC GR.FDC T~R~.CNb C~TCiC~L TENS CNL IbD.DIb GR.DIL DRHO.FDC GR.FDC TNRA CNG CNTC:CNL 21-DEC-1989 I3:52 2,878 ILM,DIL 163,500 TENS~DIL 3,411 NPO~'CNL !997.832 CF~;C.CNL 3844,000 G~,CSG 3 88@ I1.9 3'75 0 0~9 !,i9 375 223~ 340 378 3894 000 .038 12 ,750 0,040 i868.~32 3770. O0 2¸ 5 0,~02 !04, ~8 2,891 2806'656 3690,000 2,822 126.875 0 070 126~875 3 179 2073:168 3524,000 4,379 92,313 0,024 92.313 2,822 28!2.066 3630.000 3.544 115.375 0,018 115.375 2.995 2493.844 IL~,DIb TENS,DIL FFDC,FDC TENS,FDC NPOR,CNL N CFTC'C~'.b GR.CSG 2 945 SFLU,DIL 3844 000 DPHI,FDC 5!5 500 NFDC'FDC 3844 000 N~HI'CNL 41 4:53 RcNT'CNL 582 722 GR~CNL -999 2:50 TENS,CSG 3 3894 509 3894 37 7O5 -999 . 'SZ 6FbO DIL *000 DPHi FDC ,750 NFDC FDC ~000 NPHI CNG ~916 RCNT CNG .985 GR CNG .250 "s . ~E~ CSG IL~.D!L 3,8~7 SFLU,DIL ~ N' 0 DPHI FDC ~E 8 DID 3770, FFDC FDC 678,000 NFDC,FDC TENS FOC 3770.000 NPHI.CNL NPOR,CNb 47'391 RCNT,CN~ CFTC,CNL 49~,076 GR'CNL GR.CSG -999.250 TENSiCSG ILM,~IL TENS. FFDC,FDC TEMS.FDC NPOR.CML CFTC;CNL GR'CSG TENS.DIG FFDC.FDC TENS,FDC CFTC,CNG GR,CSG ILM.DIL TENS.DIL FFDC FDC ?ENS:FDC NPOR.CNb CFTC,CNG GR.CSG IL",DIL TENS.DIG FFDC.FDC TENS.FDC NPOR.CNL CFTC,CNG 2 742 3690 000 470 250 3690 000 32 554 983 677 -999 250 SFLU,DIL DPHI'FDC NFDC~FDC NPHI'CNL RCNT.CNL GR,CNL TENS,CSG 2.891 SFLU.DIL 3524.000 DP~I.FDC vso 637,651 GR.CNL 999,250 TEN$,CSG 4 738 8FLU.DIL 3630:000 DPHI.FDC 534 000 NFDC FDC 3630 000 NPhI CNL 29 810 RCNT CNL 1014 921 GR CNL -999 250 TENS,CSG 3.734 SFLU.DIL 3544.000 DPHI.FDC 564.000 NFDC.FDC 3544,000 NPHI.CNL 35.105 RCNT.CNL 827,022 GR,CNL PAGEI 3 957 il 72' 629 50~ 40 602 !957, 64'i '63 -~9~ 500 25O 5 963 I1 765 ~ 199 1~9 . ~999 2BO 669 OOO 48 443 1854 094 .!21 750 · 999 250 ],975 ,654 t3, ~)00 512, 89 2.758.,~06 104, 88 999, 50 3 286 9!855 635'5O0 36 177 2006,521 126,875 '999,250 6,978 14,439 609,000 30.879 2863.869 92.313 '999,250 5 081 16 170 612 500 33 248 2436 665 115 375 Tape Verification Listing chlUmberger AlasKa CompUting' Center CALi,CN5 8.977 TENS.CNb DEPT, I RHOB,FDC C I.FDC TNPH'CNL CALt,CNb 5400 000 -83 500 2 406 9 836 35 350 770 7!~ 836 ILD OIL DRHO FDC GR FDC CNTC CNh SP,DI5 5300.000 2,454 35 75 9 92 ILD GR DIL DRHO FDC GR FDC TNRA CNL CNTC CNb TENS CML DE:PT, SP'DI5 RHOB;FDC CALI,FDC TNPH,CN5 hI,,CN5 5200 000 -94 250 2 4O3 10 80 39 ½23 572,243 !0,180 GR.DIL ORHO,FDC GR,FDC TNRA.CNL TEN RHOB RCFT CAS! FDC FDC CNL 5100 000 -86 313 2 358 9 852 41 678 523 245 9,852 ILD,DIh GR,DIb DRHO~FDC F GR., DC TNRA.CNL CNTC,CNL TENS.CNL DEPT, SP.DIL RMOB FDC CALl FDC TNPH RCFT CNL CRLI CNL 5000 000 -83:063 2,331 9,930 44,~83 467~71B 9,930 IL0 DII., DRHO.FDC GR,FDC TNRA.CNL CNTC CNL TENS:CNL DEPT SP RHOB FDC CALl FDC TNPH CNL RCFT CNL CALI.CNL 4900.000 -85'563 2.522 8,~52 28,529 1078,034 8.852 ILD.DIL GR.DIL DRHO FDC GRiFDC TNRA CNL CNTC CNL DEPT. SP DIL CILI.FDC TNP~.CNL 4800.000 -93 500 2:376 8.656 34,819 ILD.DIL GR.DIL DRHO.FDC GR.FDC TNRA,CNb 2!-DEC-1989 i3:52 3544.000 GR,CSG 10].$09 ILM,DIb '313 TENS,DIL 0,051 FFDC,FDC !03, 13 TE[S,FDC 3, 73 NPOR CNL ,000 $R CSG 3,623 ILM,DIh 129'500 TENS.DIb .0,034 FFDC.FDC 1,29'500 TENS,FDC 3'2!9 NPOR,CNL 2167'813 CFTC,CN5 3264,000 GR,CSG ~3.472 !b~,DIb 138'250 TENS,OIL 0,030 FFDC,FDC 138,250 TENS,FDC 3,346 NPOR,CNb 2046,331 CFTC,CNL 3234,000 GR,CSG 3,034 I. hM,OIL 158,000 TENS,DI5 O, 014 FFDC,FDC !58,000 ~EN$,FDC 3,588 NPOR,CNL 1948,~81 CFTC,CNL 3204.. O0 GR,CSG 1.486 ILM,DIb 125,813 TENS.DIL 0 052 FFDC,FDC 125~813 TENS,FDC 3,7~0 NPOR.CNL 1922.044 CFTC,CNL 3144.000 GR,CSG 4 232 I5~,OIb 49:688 IEN$,DIL 0 OB7 FFDC,FDC 49i688 TENS.FDC 2 343 NPOR.CNL 3407 143 CFTC,CNL 3100:000 GR.CSG 3,204 !LM.DIL i36.000 TENS.OIL 0.024 FFDC,FDC 136,000 TENS,FDC 3,083 NPOR,CNL -999,250 TENS.CSG 2.856 SFLU,DIL 3480'000 DPHI;FDC 578~500 NFDC,FDC 3480,000 NPHI,CNL 35,661 RCNT,CNL .784.622 GR,CN~ 999'250 TENS'CSG ,3 3264 494 3264 36 695 -999 .694 SFbU,DIL ,000 DPH!,FDC 500 NFDC,FDC 000 NPH!*CNL 153 RCNT.CNL 032 GR,CNL 250 TEN$,CSG 3 543 SFLU DIL 3234 000 DPEI FDC 553 500 NFDC FDC 3234 000 NPHI CNL 40 772 RCNT CNL 604 615 GR CN~ -999 250 IE CSG 000 DPHI;FOC 96.000 NFDC'FD¢ 3209'000 4o'172 RCNT.CNL 557,888 GR'CNL -999.250 TENS.CSG 1 513 SFLU,~L 3144 000 DPHI..C 699 000 NFDC*FDC 3~44 000 NPHI,CNL 45 138 RCNT,CNL 520 655 GR,CNL -999 250 TENS,CSG 4.526 SFLU DIL 3100.000 DPHI FDC 475 000 NFDC FDC 3100 000 NPHI CNL 27 444 RCNT CNL 1305 300 GR CNL -999 250 TENS CSG 3.183 SFLU.DIL 3014.000 DPEI,FDC 583,500 NFDC,FDC 3014.000 NPHI,CNL 35.167 RCNT.CNL '999,250 2 730 !4 78 648 00 35 25 2377 3it .03 - 99, 250 4,003' 1~.;903 605'000 36,571 1:28i966 i29'500 999,250 621~000 37, 8 .138, 0 999,~0 · 3 649 17 7~ 1984 O43 15~ 000 -999 250 I 443 687, 46 197 1885 820 125 813 -999 250 35 904 7 744 639 500 23 614 3462 485 49 688 -999 250 3,319 16.612 625.000 35,341 2205,581 I,S !ape Yerificatlon Listing ~hlUmberger AlasKa Computing Center RCFI,C~,.NL 661,241 CNTC,CNb .CALI'CNL 8,656 TENS,C~!L DEPT 4 00,000 ILD,DIL P:DI5 !93,250 GR.DIL -H~ DRk!O FDC g~ .B,FD¢ 2,386 , CALI,FDC 8,992 GR,FDC ,TNPH,CN.b 34,947 TNRA,CNL RCFT,CNF 759'358 CNTC,CNL C~5I;CNL 8,992 TEN$,CN'h DEP~, RHOB,FDC CALI;FD.C TNPH,CNb RCFT,CNL C~bI,CNb 4600 000 -96 000 2 355 9 00~ 35 896 752,514 9,008 IbD.DIL GR;D!L DRHO,FDC GR,FDC ~[aR~,CMb C~TC,CNb TEN$,CNL DEPT SP CAb! RCFT FDC FDC CNL 4500,000 -4~,250 ,312 9,.305 42,499 560'376 9,305 I~D,DIb DRHO;FDC TMRA, CNI~ CNTC, CNb TENS, CN b DEPT SP ALI TNPH RCFT CabI FDC FDC CNI~ CNL 4400,O00 -50,281 2,319 9,055 37,742 660,990 9,055 ILO OIL GR OIL DRHO FDC GR FDC TNRA CNL CNTC.CNL TENS'CNL DEPT, SP,DIL RHOB,FDC C~LI,FDC TNPM CMI, RCFTiC~b CALl C~L 4~00,000 54,281 2.294 9,000 36,601 694,98~ 9.000 ILO,OIL GR,DIL DRMO,FDC GR FDC NRA.CNh C~TC CNb DEPT, SP,DIL RHOB,FDC CALI,FDC TNP~,CNb ~CFT;C~L CALI,CNL 4200.000 -56'531 2,289 9,008 36,583 695,823 9'008 ILO,OIL GR,DIL DRHO,FDC GR,FDC TNRA,CNL CNTC,CML TENS,CNL DEPT, SP,DIL RHOB,FDC C~LI,FDC 4100.000 '58,000 2,279 9,031 ILO OIL GR:DIL DRHO,FDC GR,FDC 21-DEC-t989 !,3:52 ~34,149 CFTC,CNL ,000 GR,CSG 3,235 91,~00 o 69 91 5(>0 247~ 038 417 3030 3,106 1.00,375 0,003 100'375 3,160 2~91;732 224~,o00 ,7511, 25 0,010 115.!25 ,444 19,284 844,000 , 0,003 IO4,688 3,~54 2350, 94 2944,000 3.130 125 250 0!000 125 250 3,152 2407,542 2800,000 3.104 100,500 0,020 100,500 3.150 2381.138 2834,000 2,7~0 !10,750 0,007 110,750 IbM.OIL TENS,OIL FFDC,FDC TENS,FDC NPOR,CNb CFTC'CNL GR,CSG IL~,OIb TENS,OIL FFDC'FDC TEN$,FDC NPOR,CNL CFTC,CNL GR,CSG IbM,DIb TENS'DIb FFDC~FDC TENS~FDC NPOR,CNL CFTC'CNL GR,CSG IL~,DIb TE~!S,D!L FFDC,FDC TENS,FDC NPOR CNL GP,CSG IbM,OIL TENS,OIL FFDC FDC TENS:FDC NPOR,CNL CFIC,CNL GR,CSG IbM,OIL TFNS,DIL FFDC,FDC TENS,FDC NPOR.CNL CFTC,CNb GR,CSG ILM,DIL TENS,OIL FFDC.FDC Tf;NS,FOC 749,269 GR,~NL -999,250 TE.NS., SG 3,204 3030;000 DP'HI;FDC 549,500 NFDC'FDC 3030,000 NPHI.'CNL 3.4,886 RCNT'CNL 817'770 GR."CNL -999,250 T'ENS,CSO 3,169 SFbU 2924,000 DPH! FDC 583,500 NFDC FDC 2924,000 NPHI CNL 37'567 RCNT CN~ 805,942 GR CNL -999,250 TENS CSG 2,290 SFbU,DIL 2844.000 DPHI;FD~ 659*500 NFDC,FDC 2844,000 NPHt,~CNL 41,860 ~CN~,CN~ .622'444 G~'CNL ...LNS,CSG 999'250 T'~ 2 722 2944 000 638 000 2944 000 37 287 731 996 -999 250 DPHI, NFDC,FDC NPHI,CNL RCNT,CNL _ GR,C~L TENS,CSG 3 102 SFLD OIL 2800 000 DPHI FDC 672 000 NFDC FDC 2800 000 NPHI CNb 37 127 RCNT CNL 767 695 GR CNL -999,250 TEMS.CSG 3,032 SFLU DIE 2834,000 DPHIiFDC 715 000 NFDC FDC 2834:000 NPMI,CNL 35,702 RCNT.CNL 759,468 GR,CNL -999,250 TEN$,CSG 2,64i SFLU,DIL 2754,000 DPHI,FDC 710,000 NFDC,FDC 2754,000 NPHI,CNL PAGE: 136,000 "999,250 !6 598 500 34 008 2447 680 '9t 500 -999 250 3.~239 2;000 4'2!3 .9~0'3'75 9;2§0 2'464 20;464 632.5.00 40,982 .115'125 ~.999,250 2~ 706 O78 044 -999 250 3,138 21,573 622,500 36,094 125, -999'250 3,302 2t,862 659 000 36 050 2397 046 100 500 -999 250 2,720 22,480 643,000 44,409 ChlUbm: erger alaska ComPuting center TN~H,CNL 41,348 TNRA,C~L RCFT~CNL 542.884 CNTC CNb CALI':CNL 9,031 TE $.CNb D~PT,D 4000,000 ISD,D1L RHOB,FDC 2'297 CAbI,FDC 9,914 GR,FDC TNPM,CN5 42;075 TNRa,CNL RCFT.CNL 525~429 CNTC'CNb C~LI'CNL 9,91.4 TENS,CN~ 3900,000 !b.D,DI5 DEPT'DIL~P,- -6,3,250 GH,DIL RHOB.FDC 2.269 DRHO'FDC CALI,FDC 9,063 GR.FDC TNPM'CNL 40,652 TNRA'CMb RCFT~CML 557,588 CNTC,CNL C~LI~CN[~ 9,063 TENS.CNL DEPT. 380 SP.D!.L -6 RMOB'FDC CALI,FDC T~PH,~L 4 RCFT.iNL 55 C LI,CN 0.000 5 000 2 257 9 078 ! 491 7 588 9 078 ILD, G.R, DRMO. GR TNRA CNTC TENS OIL D I L FDC FDC CNL CNL DEPT, 370 ,DIL ,. TN ,CNL 4 RCFT,CNL 46 CALI,C~.5 1 0 000 9 750 2 251 0 344 3 111 4 173 0 344 ILD,DIL GR.DIL DRHO,~DC GR, DC TNRA,CNL CNTC,CNb TENS.CNL D~PT. SP,DIL RHOB FDC CAb) FDC TNPH CNL RCFT CNL CAb! CWb 4 46 0 2. 9. 4, 4, 9, 000 56] 224 195 8O8 173 195 ILO DJL , GR.DIL DRMO.FDC GR.FDC 'rNRA.CNL CNTC.CNL TENS.CNL DEPT, SP,DIL RHO~ FDC T~PH,CNL RCFT.CNL CALI,CNL 3500. '74, 2. 9. 40. 586. 9. 000 000 243 414 768 643 414 ILD DRHO. TNRA. CNTC. TENS. DIL D ! L FDC FDC CN L CNL CNL 21-D[:C-1989 13:52 3,609 NPOR, 2 "..,ooo ,82210 ,188 0,006 107.188 3,550 2 4, 0 2 885 105 000 0 0!2 !05 000 3 409 2144 921 2580 000 2,840 93,500 0.002 93,500 3'41! 21.09'503 2564'000 10~ 844 o .. 21 lO6 188 3 722 1946 448 2530 000 2 877 113:000 0009 113:000 3,782 2026.230 2410,000 4.033 I01,688 0,014 101,688 3,523 2063.109 2374.000 'ILS,DIL TEN$,DIL FFDC FDC TENS FDC NPOR CNL CFTC CNL · OR CSG ILM,D!L TENS~DiL FFDC,FDC TENS FDC NPOR CNb CFTC CNL GR CSG TENS'DIL FFDC,FDC '~ S FDC ~EN~., CF~C,C~L GN,CSG TENS,DIL FFOC,FDC TENS,FDC NPOR,CNL CF~iC,CNL GR,CSG IL~.DIL TENS.DIb FFDC,FDC TENS.FOC NPOR,CNL CFTC.CNL Gk.CSG !L~,DIL TENS.DIb FFDC.FDC TEN$.FDC NPOR,CNL CF~'C.CNL GR,CSG 4,3,,645 642'464 -999;250 2,754 2644,000 679,000 2644;000 35~,863 609,016 -999'250 2,85i 25802000 737'500 2580.000 40~959 632.083 '999~250 2,790 2564,000 7412000 2564.000 41'4~6 612,074 -999'250 2,733 25~.000 7 ,500 2530,000 43,639 540.697 -999,250 2 784 2410 000 816 500 2410 000 44 423 554 180 -999 250 3.754 2374000 8 2ooo 2374 000 41i458 603 900 -999 250 RCNT.CNL GR tnb TEN$'CSG SFLU,pIL DP~I.,iFDC NFDC,FDC NPai CNL RCNT,CNL G 'C L TEN$'CSG SFLU,DIL DPH!.FDC NFDC~FDC RCNT,CNL . GR*CNL ~ENS.CSG SFLU,,DI~ DPHI,FDC NFDC'FD~ RCNT.CN~ TENS;CSG SFLU DIL DPHI FDC NFDC FDC NPH! CNL RCNT CNL OR CNL TENS CSG SFLU,DIL DPHI,FDC NFDC,FDC NPHI CNL RCNT:CNL GR CNL TENS:CS6 SFLU DIL DPHIiFDC NFDC FDC NPHI.CNL RCNT,CN~ GR.CNL TENS,CSG AGE { ! 0 :2074'983 '1:10; 750 ' 999' 250 2,83 42. 63 5.00 42;003 2215,857 107,188 "999'2:50 2 9O8 23 122 656 000 40 704 2101 367 .lO9 ooo 999 250 644 500 40 708 -999 250 99 180 000 44;510 1898,85~ '106,18B 999,250 2.7~5 25,8 7 61~,500 2013'6 6 113,000 "999,250 3 772 24 664 671 500 42 252 2004 842 lOt 688 "999 250 [$ Tape verification L.isting DEPT,D 3400 RHOB,'FDC 2 TNPH,CNL 4 RCFT;CNL 52~ C~LI;CN[,i 9 .000 ILD,DIL 750 GR,DIL !30 DRHO.FDC 227 GR~FDC 928 TNRA~CNL 96o c~c~c~ 227 TEN$iCNL DEPT 3300 RHOB,FDC 2 CALI~FDc 9 TNPH,CNL 45 RCFT,CNL 457 CA. DI.'CNL 9 000 ILD,DIL 000 GR,DIL 233 DRHO.FDC 813 GR,FDC 019 TNRA,CNL ,623 CNTC.CNL ,813 TENS,CML DEPT 3200,000 RHOB~FDC 2,239 ~c~T;CNb 39.221 ,CML 538 ILD GR TNRA CML CNTC CNh TENS CML DEpT SP RHOB CALI TNPH RC~T CALl 3100 DIG FDC 2 FDC i0 CNL CNG 460 CNL 10 ,000 75O 252 422 693 974 422 ILD,DIL GR,DIL DRHO,FDC GR,FDC TN~A,CNL CNTC,CNL TENS'CML DEPT. SP.DIL RHOB.FDC CALI.FDC TNPH.CNL RCFT CML 3O0O 12 41 415 12 .000 ,o00 ,194 .430 ,357 ,053 ,430 tLD DID GR DIL GR FDC TNRA CNL CNTC CML TENS.CML DEPT. SP DIL RHOB:FDC CtbI FDC TNPH:CNL RCFT CML CALI:CNL 2900 -84 1 8 5! 314 8 ,000 .750 .891 :945 925 ,382 .945 ILD.DIL GR.DIb DRHO.FDC GR.FDC TNBA,CNL CNTC.CNL TENS.CML DEPT. SP.DIL RHOB,FDC CALY.FDC TNPH.CNL RCFT.CNL CALI,CNL 99 -999 -999 -999 -999 -999 ,000 ,250 .250 .250 ,250 ,250 .250 ILD.DIIJ GR.DII~ DRHO.FDC GR.FDC TNRA.CNL CNTC CNL TEN$:CNI.. 21-DEC-1989 13:52 9 I0 0 106 3 1. 921 2164 5,252 _ILM,DIL DIL TENS. 1 0~3 o o.o 1 063 TENS,FDC 3,6~2 NPO~,CMb 5, 6 CFTC,CL O, 0 GR,CSG 3 O39 6 8}3 03 ,08.1 , 3 ,000 5 1!2 0 2150 4 104 0 104 1983 2084 1 80 0 80 3 1694 2154 29 50 3 1392 2124 -999 -999 -999 -999 -999 -999 -999 , 5 020 375 278 294 000 395 .8.75 009 875 644 394 000 ,957 ,625 .013 625 852 O28 .000 .683 563 430 563 .994 .~4~ .000 250 i25o 25O 25O .250 .250 ,250 I bM, O ! b T E N o. D I b FFDC'FDC TENS FDC NPOR CNL CFTC CNL GR CSG ! L M, [)IL TENS, D!b FFDC*FDC TENS ' FDC NPOR'CNb CFT[ CNL ILM,OIL TENS FFDC FDC TENS FDC CFIC CML GR CSG TENS D!L TENS.FDC CFTC.CML GR.CSG IL~.DIL TENS.DIL FFDC.FDC TENS FDC NPOR:CNb CFTC.CML G~.CSG TENS,F)IL FFDC,FDC TENS.FDC NPOR,CNL CFTC.CML GR,CSG 5 2590 !006 2590 42 577 -999 2 2164 807 2!64 44 519 -999 5 2150 808 2150 36 580 -999 , :2084' 763, 2084; 44. 545. I02, 887' 2154, 41' 474. 85. 2000 2124 629 2124 52 341 48 -999 -999 -999 -999 -999 -999 54 2 000 000 496 250 810 000 500 000 218 908 250 408 000 500 000 585 596 25O 232 000 000 000 4OO 136 000 811 000 5O0 000 650 187 875 000 000 50O 000 868 830 625 250 250 250 25O 25O 25O 531 SFLU,DIL DPHI,FDC NFDC'F[)C NPHI'CNL GR,CNL TENS,CSG NFDC 'DC RC~T:.NL GR [NE I SG SFLU,DIL DPHI,FDC NFDC.FDC NPH! CML RCNT CNL GR TENS CS SFLU,D!L DPMI'FDC NFDC,FDC NPHI~CNL RCNT'CNL GR,CNL TE.NS'CSG SFLU.DIL NFDC DC NPHI,CNL GR NL TENS SG SFLU.DIL DPHI FDC NFDC:FDC NPHX,CNL RCNT,CNL GR.CNL TENS.CSG SFLU.DIL DPHI FDC NFDC:FDC RCNT:CNL GR.CNL TENS,CSG 44, 674~500 47,295 1925'255 5,317 24,90 35'949 2048,688 4.201 .24.125 659 000 42 959 1928 093 I04 2050 000 4,311 45,536 1660,256 80.625 2114.000 2000,000 46.008 259,500 51,585 1350.510 50,56~ 2045.000 -999,250 -999,250 -999.250 -999,250 -999,250 ~999 250 070~000 Tape Verification Listing chlumberger Alaska ComPUting~ Center DEPT, ~700,000 SP'DIL 999,250 RMOB'FDC -999'250 CALI~FDC -999 250 T~PD'~ML -999 256 RCFT,CN5 -999'250 CALI;CNL -999,250 DEPT, 2600,000 SP:~I.b -999.~50 ~HOB DC 999,250 CAL! Nb -999,250 DEPT, ~OB,FDC C LI.FDC FT,CNL DEP~, R~O.FDC CALI.;FDC CAL~,CNL DEPT, RMOB,FDC C~LI,FDC NPH,CN5 CFT,CN[, C~L!,C~L DEPT, SP,DIL RMOR FDC CALIiFDC TNP~ CNL RCFT,C~L CALI,CNL DEPT. SP,DIL RHOB.FDC CALI,FDC TNPH.CNL RCFT.CNL 2600 000 -999 250 -999 ~50 -999 150 -999 250 -999 250 -999 250 2400.000 -999.250 -999,250 -999,250 -999,250 :999,250 .999.250 2300,000 -999'250 -999,250 -999,250 -999,250 -999,250 -999.~50 2~00.000 -999,250 -999,250 -999.250 -999.~50 -999.250 -999.~50 2100,000 -999,250 -999.250 -999,250 =999 250 -999:250 GR'DIh DRHO FDC GR FDC TNRA CNL CNTC CNL TENS CNL !LD DIL GR DRHO FDC GR FDC TNRA CNL CN.rC, ILD D]L GR DRMG FDC GRFDC CNTC C~L TENS CNL ILD,DIL GR,DIL DRHO,FDC GR,(~DC TNRA. NL CNTC.CNL TENS,CNL IbD,DIL G~.DIL DRHO FDC GR.FDC TNRA, CN L CNTC.CNL TENS,CN5 ILD,DIL GR.D!L DRHO.FDC GR,f'DC TNRA.CN~ CNTC,CNI~ TENS.CNL ILD,DIb GR.DIL DRHO FDC GR!FDC T~,{RA CNL CNTC.CNL 21-DEC-1989 13:52 -999,250 -999'250 -999, 50 999'250 '999.250 ~999,250 -999'250 -999;250 -999'250 -999,250 -999'250 I999,250 ,999,250 .999'250 ~999,250 -999'250 -999 ~50 -999 50 ~99 250 99~ 25:0 -999 250 ~999 250 '999 250 -999,250 -999,250 -999.250 -999,250 -999.250 -999 250 '999:250 '999.250 '999.250 '999 250 '999]250 -999.250 '999.250 '999,250 -999.250 -999,250 -999.250 -999.250 -999 250 -999:250 TENS'DIL FFDC' FDC TENS, FDC CFTC;CNL GR,CSG FFO ~,, DC TENS,FDC NPOR,CNb CFTC,CNL GR'CSG Ib~ TENS DIL FFDC FDC TENS FDC NPOR'CNL CFTC,CNb GR,CSG TENS,DIL F ~ FDC . fDC, TENS,FDC CN b NPOR, 'N CFTC,C GR, CSG ILM,OIb IENS, FFDC,FDC TENS,FDC NPOR,CNL CFTC,CNL GR.CSG ILM,DIL TENS,DIL FFDC.FDC I~ENS, FDC N PO R, CN L CFTC,CNb G~.CSG Ib~'., I)IL TENS,DiL FFDC,FDC TENS,FDC NPOR, Cab CFTC,CNL -999,250 ~999,250 ~999'~50 ~999~250 ~999,250 999~250 52,156 ~999,250 999~250 -999,250 -999'250 -999,250 -999'250 46,750 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 48 844 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 50 156 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 53 125 -999 250 '999i250 -999 250 -999 250 -999 250 -999~250 41,125 999,250 -999 250 -999:250 -999,250 -999,250 SFbU,DIL DPH~,~DC ~FDC,FD¢ .PH1.CNL GR.CNL TEN$;CSG SFLU,Di~ DPB!.FDC NFDC'FDC RC~T,CN~ GR,CNb TENS~CSG SFL, U,DIL DP~I'FDC MFDC;FDC ~P~I,C~ RC~T'CN~ TE~S,CSG SFLU,DIL DPH!'FDC NFDC,.FDC NP~.I'CNL RCNT'CNL GR~CNL TEN$~CSG SFLU DIL DPHI FDC NFDC FDC NPHI CNL RCNT CNL GR CNL TENS CSG SFLU,DIL DP~IiFDC NFDC.FDC NPHI,CNL RCNT'CNL GR,CNL TENS.CSG SFLU DIL DPHI:FDC NFDC.FDC NPHI.CNL RCNT CNL GR:CNL -999'250 -999,250 -999~'250 '999;250 .-999.~250 .-999;.250 '999.,250. -999;250 '-999,250 :-999~250 -999,250 -999'250 1925;000 -999,250 -999'250 -999.250 :999'250 .999,250 -999;250 !905,000 -999,2~0 :-999,2 O '999,250 -999,250 -999.,250 -999,250 1845,000 -999 250 -999 250 -999 250 -999 250 -999 250 '-999 250 1785.000 -999.250 -999.250 -999.250 -999'250 -999.250 -999.250 1715.000 -999,250 -999.250 99~250 -999.250 -999.250 IS Tape Verification bisti, ng ~'hlumberger AlasKa Computing Center CALI,CNL -999,250 THiNS.C~L DEPT, 2000,000 II~O,DIL 'SP'OIL -999'250 GR,DIL RHOB~FDC -999,250 DRHO.FDC CALI,FDC -999,250 GR FDC TN'P~CN[, -999;350 TNRA:CNb RCFT,CML -999,~50 CNTC,CNL CAPI:;C~L -999,250 TENS,CNh O~PT, 1900.000 ILO ~MO :' DC -999,250 DRHO I'FD~ -999,~50 GR ,C~L -999'2§0 CNTC ~[ii,cNI: -999,250 TENS ,DIh ,DIL .FDC FDC DEPT, 1800.000 !LD SP~D!5 999.250 GR RMOB;FDC 2999'250 DRHO A . LI,FDC -999,250 GR · NPH.;CNL -999,250 TNRA ~CFT,cNL -999,250 CNTC CALI,C~L -999,250 TENS FDC FDC CNb CNL DEpT, ~70~,000 ILD P.DI5 99...,250 GR RM B'FDC 999.250 DRHO CALI,FDC 999'250 GR TNPH,C~L ~999.250 TNRA RCFT,CN5 -999,250 CNTC CAL],CN5 -999.250 TENS I I,~ IiL ,CNL ,ChL D~PT. 1600.000 SP.DIb -999'250 GR ~HOB.FD£ -999.250 DRHO CALI,FDC -999.250 GR TNPH.CNL -999,250 TNRA RCFT.CNL -999,250 CNTC CALX'CNb -999.250 TENS DIL DIL FDC FDC cnn ,CNL .C~L DEPT. 1500.000 ILD SP.DIL -999.250 GR RHOB.FDC -999.250 DRHO CALI.FDC -999.250 GR TNPH.CNL -999.250 TNRA RCFT CNL -999 250 CNTC CALI:C~5 '999:250 TENS .D!L .DIL .FDC .FDC .CNL .CNb .CNL DEPT. 1400.000 II.D SP.DIL -999.250 GR RHOB.FDC -999,250 DRHO CALl FDC -999.250 GR TNPH:CNL -999,250 TNRA ,DIL ,DIb .FDC ,CNL 2i-DgC-!989 1]:52 '999.250 GR.CSG "999 250 ~999 250 "99~ 250 "99. 250 -999 250 ~999 ~50 '999 50 -999.250 -999,250 -999,2~0 -999'2 -999'250 -999'250 -999'250 -999 250 -999 250 '999 250 "999 250 "999 250 -999'250 "999.250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 -999.250 -999 250 -9991250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999.250 -999 250 '9991250 -999 250 -99g 250 IL~,DIL TENS,DIL FFDC.FDC T~'~ FDC NPOR,CN5 CFTC.,C~I, GR'CSG IL~,DIL TENS DIL FFDC FDC TENS FDC NPOR CNL G~ CSG Ib~ TENS FFDC FDC TENS FDC NPOR CN5 CFTC'CNL GR,CSG ILM.OIL TENS,DIL FFDC.FDC TENS,FDC NPOR'CNL CFTC.CNL GR'CSG ILM,DIL TENS.DIL FFDC'FDC T~NS,FDC NPOR.CNL CFTC,CNL GR,CSG ILM.DIb TENS DIL FFDC:FDC TENS.FDC ~JPOR.CNb CFTC.CNL GR,CSG IL!4,D!L TENS.OIL FFDC,FDC TEN~,FDC NPOR,CNL 27,328 -999 250 -999 250 -999 2'50 -999 250 -999 250 -999 250 36 531 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 33 375 -999,250 -999 250 -999'~0 -999: 0 -999,250 -999,250 51,438 -999.250 -999,250 -999'250 -~99.250 -999 50 59 94 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 20 609 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 32 938 -999 250 -999i250 -999 250 -999 250 -999,250 TENS.CSG SFLU,DI.L DPHI,FDC NFDC'FDC NPHI,CNL GR;CNL TENS'CSG SFLU,DIL NFDC'FD¢ RC ,C L TENS.C~G 8FLU.DIL DPHI FDC NFDC FDC MPH! CNL RCNT CNL GR SFLU*DIL DPHI,FDC NFDC'FDC NPHI,CN~ RCNT.CNL G~'CNL TENS,CSG SFLU.DIL DPHI.FDC NFDC,FDC NPHI.CNL RCNT.CNL GR,CNL TENS,CSG SFLU DIL DPHI FDC NFDC FDC NPHX CNL RCNT CNL GR,CNL TENS,CSG SFLU,DIL DPHI,FDC ~EDC,FDC PHI.CNL ~CNT,CNL I630,000 '999'250 ~999, 0 '999'250 "999'250 !565'000 "9991.250 '999 2150 '999 250 -999 250 '999 250 "999250 1540 000 -999,250 .-999;2'50 -999'25 :'999,25~ .-999' 0 !1450;~0 ~-999'250 ~-999,250 ~'999;250 ~999,250 ~'999,250 '999'250 1420;000 '999,250 "999,250 "999.250 '999,250 "999.250 -999.250 1440.000 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 1370,000 -999 250 -999 250 -999 250 '999 250 '999 250 Tape Verification bist{ng ~hlumberger A!a$~a Computlnq Center 21-DEC-1989 !3:52 CALI,CNL -999.250 TENS'~NL ' ~99 ,250 GR,CSG IbD GR DRHO FDC GR FDC CNTC CNb TENS CNb DEPT 1300 000 SPiDIL -999250 R'HOF'FDC -999250 CALI,FDC -999 250 TNP~,CNL -999,250 RCFT,cN5 -999.250 CALl;CML .-999'250 GR GR TMR4 CNTC TENS ,OIL ~Dlb ;FUC ;FDC ,CNL DEPT 1200,000 SP' 'OIL '999'250 EHOB,FDC -999,250 CALI;FDC -999,250 TNP~,CNL .-999,~50 ~CFT;CN[, -999.250 CALI'CN.L -999,250 GR OIL DR~O FDC GR FDC CNTC CNh TENS,CNL DE~ 1100,000 :DIL .9~9'2§0 29 9. so C~LI.FDC -9~9,250 TNP~"C~L -9 9,250 ~CFT'CNL -9~9'250 CAL!,CNL -999,250 OI t, FDC FDC CNL CNL ~000000 999:250 -999250 -999250 -999 250 -999250 -999250 IbD.DIb GR,DIL DRHO,FDC GR"FDC TNRA'CNL C~TC.C~L TENS.CNL DEPT S~ R~OE C~hl TNPM ~CFT CAb! 968,500 '999.250 '999250 '999250 '999250 -999250 -999250 ILO,OiL GR.DIb DRH!!FDC G FDC T NR CN l, TEN CNL DEPT, SP.DIb R~OB FDC CALI:FDC TNPP.CN[, ~CFT,CNL C4LI,C~b ** EMD OF O~TA ** ~999 250 -999 250 -999 250 -999 250 -99 0 -999250 -999,250 -999.250 999,250 999.250 .:999,250 .999"250 -'999'250 -999 250 ~999 250 999 250 ~999 250 ~999 250 -999,250 '999,250 '999.250 '999,250 '999.250 '999,250 '999.250 '999.250 -999 250 -999 50 '999.250 '999,250 '999.250 '999.250 ,Ib~,DIb TE,~9,DIL FFuc'FDC TEN$,FDC NPOR,CNL CF~'C,CNb GR,CSG ILM,D!L TENS'OIL TENS DC NPOR:~NL CFTC NL G~,CSG IL~,O!b TENS,OIL FFDC,FDC TENM,FDC NPOR ~NL CFTC: Nb GR,CSG ILM,DI5 TENS.OIL FFDC,FDC TENS,FDC NPOR,CNL CFTC.CNL GR,CSG IL~.OIL TENS,OIL FFDC,FDC TENS,FDC NPOR,CNL CFTC,CNL GR.CSG -999.250 GR.CNL 43.875 TE~$,CSG -999 -999 -999 -999 -999 -999 32 50 DPM! DC 250 NPMI NL 563 TENS Sg -999,250 -999,250 -999'250 NFDC .999,250 -999,250 RC~T -9995250 27,1.72 TENS FDC CNL CNL tnb -999,250 SFLU.DIL -~99,250 DPHI,FDC - 99;250 NFDC,FDC -999'250 NPHI;CNL -999~250 RCNT~CNL -999~250 GR'CNL 26.500 TEN$,CSG -999250 SFLO.DIL -999 250 DPHI'FD¢ -999 250 NFDC2F~C -999 250 NPHI,CNL -999 250 RCNT,CNL -999250 G[~'CNL 53813 TENS.CSG -999 250 8FbU.DIL -999 250 DPHI.FDC -999 250 NFDC.FDC -999250 NPMI,CNL -999250 RCNT.CNL -999250 GR.C~L 29 044 TEN$,CSG PAGE: 14 -999 250 ooo '999,250 '999.250 '999 250 '999250 '"999 250 t310 000 -999,250 -999.250 ' ,20 ' ,250 '999,250 ~999,~50 1260,.00 '999,250 "99 '250 "999;250 '999'250 '999,250 1225'000 "999,250 '999,250 '999 250 '999250 '999250 '999250 1185,000 '999.250 '999.250 '999,250 "999.250 '999,2~0 '999,2.0 1170,000 !$ Tape verification Ltstlnq :hlumberger AlasKa Computing Center 2!'DEC-1989 13152 15 **** FISE TRAILER **** iFILE NANE : EDIT ,001 SERVICE : FLIC VERSION : 00lA04 DATE : 89/12/~1 MAX BEC SIZE : 1096 FILE TYPE : LO .F!SE NAME : EDIT ,002 VERSION : O01A04 DATE : 89/12/~. MAX REC SIZE : 1096 FILE TYPE : LO LAST FILE : ****************************************************************************** FILE.- ED!T,O02 ARCO ALASKA, !NC. KUPARUK 2K- !0 50-103-20106'00 HIGH RESOLUTION PASS DATA SAMPLED EVERY -,I000 FEET DATA INCLUDEP - TOOL EXTENSION TOOL * TYPE USED NAME , * FDC ~DH FORMATION DENSI. T¥ * CNT-A/D/M :CNH CONPENSATED {~EUTkON , ****************************************************************************** Tape Verification Listing ~hlumverger Alaska Computing Center TAB£E TYPE : CONS TUNI VALU DEFI CN ARCO A~,,ASKA, I~C, Compan~ Name FN KUPARU~ ' Field-.,i!ame WN 2K- I0 Well Name FL 7'~ ~o i ~ & 94' FEb Field. bocation $~CT 2 Section TO~N ION TownShip RANG 8E Range COU~ NORTH SLOPE Cousty STAT ~bASKA State or Province NATI USA Nation ATI ~atltude ONG bongitu~e WITN DIXON/LOWEN/~CGIMSEY Witfiess Name SON 549!.02 Service Order NUmber PDAT MSL Permanent datum EPD FT 0, L~F BKB ~og ~easured From APD FT }54 EKB FT 54' EDF FT 153' E¢~ FT . 13i TDD FT 679 $~E~ DEGF 99 ,25 TABLE TYPE : CURV DEPT DPH! RHOB DRHO FFDC NFDC CALl GR TENS NPH! TNPM TNRA NPOR RCNT RCFT CNTC CFTC GR CAL! TENS Depth Channe,1 Name Density Porosity BulW Density Oelta RHO Far FDC Count Rate Near FDC Count Rate Caliper Gamma Ray Tension Neutron Porosity TDermal ~eutron Porosity CallDrated Thermal Neutron Patio Neutron Porosity Output From an APplication Program RCNT RCFT CNTC CFTC Gamma Ray Caliper Tenslon lS Tape Verification List:lng Cblum.'ergerb Alaska Computino Center 21-DEC-!989 13:52 ** DATA FORMAT SPECIFICATION RECORD ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 8O 4 66 5 66 6 7 65 8 68 0 1 !! 66 i3 12 68 1] 66 0 14 65 15 66 68 16 66 1 0 66 ** SET TYPE - CHAN ** NASal SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SA~P ELE~ CODE (HEX) DFPT FT 549102 O0 DPHX FDH PU 549102 07 RHOB FDH G/C3 549102 07 DRHO FDH G/C3 549102 07 FFDC FDH CPS 549102 07 NFDC FDH CPS 549102 07 C~I,! FDH IN 549102 07 g~ FDH GAPI 549102 07 TENS FDH LB 549102 07 NPHI CNH PU 549102 07 TNPM CNH PU 549102 07 TNRA CNH 549102 07 NPOR CNH PU 549102 07 RCNT CNH CPS 549]02 07 RCFT CNH CPS 549102 07 CNTC CNH CPS 549102 07 CFTC C~H CPS 549102 07 GR CNH GAPI 549102 07 CALI CNH IN 549102 07 TENS CNN LB 549102 07 000 O0 0 2 1 1 4 68 0000000000 6]5 21 0 2 1 1 4 68 0000000000 350 02 0 2 1 I 4 68 0000000000 356 01 0 2 I 1 4 68 0000000000 354 02 0 2 1 1 4 68 0000000000 ]54 Ol 0 ~ 1 1 4 ~8 0000000000 280 Ol 0 2 1 1 4 68 0000000000 310 O1 0 2 1 1 4 68 0000000000 635 21 0 2 I I 4 68 0000000000 890 O0 0 2 1 I 4 68 0000000000 890 O0 0 2 ! ! 4 68 0000000000 420 01 0 2 1 1 4 68 0000000000 890 O0 0 2 I 1 4 68 0000000000 420 O1 0 2 1 1 4 68 0000000000 420 01 0 2 1 1 4 68 0000000000 420 O1 0 2 1 1 4 68 0000000000 420 O1 0 2 1 I q 68 0000000000 310 01 0 2 1 1 4 68 0000000000 280 O1 0 2 1 1 4 68 0000000000 635 21 0 2 1 1 4 68 0000000000 Tape Verification Listing ~hlUmberger Alaska Computing Center 2~-DEC-1989 !3~52 DEPT.. 6773,900 DPHI FDH FFDC,FD~H 462,000 NFDC FDM .TENS,FDH 2524,000 NPH! CNH NPOR,CNH ' 41,882 RCNT CNH CFTC,CNH 559.374 GR.CNM DEPT, 6700,000 DPHI,FDH FFDC,FDH 512,500 NFDC,FDH TENS'FDH 4200,000 NPHi,CNB NPO~,CN~ 45.0~3 RCNT.C~.H'~ CFTC~CN~ 552,856 GR,CNH DEPT, TENS DH 6600 UO0 467 500 4!08 000 44 073 629 816 DEPT, TE' ,FDH NPO~, C~H CFTC. CN H 6500,000 473.250 4180. 000 28.911 !.049'942 DEPT, FFDC.FDH TENS,FDH NPOR.CNH CFTC,CNH 6400 000 569 000 4124 000 42 638 498 327 DEPT, 6347 10! FF~C.~DH 530:500 TEN$.FD~ 3994,000 NPOR.CMH 44.863 CFTC,CNW 487,04R ** END OF DATA DPHI,rDH NFDC,FDH NPMI,CNH RCNT,CNH GR.CNH DPH I, FDH NFDC*FDH Np~ ! · CNH nCNT~ CNH GR.CNH DPHI.FDH NFDC.FDM NPHI,CNH RCNT.CNH GR.CNH 10 00 582 ~55 1900 5!2 124 500 13 270 04 000 46 1986 463 1.13 875 10,339 597 ' 500 42'344 2029'1%9 !09.438 t 160 5g~ oOo 28 283 ~33 ~o 8~ 31;3 !6,860 605,500 47.173 1879.906 128.500 15 521 861000 550 944 1718 855 119 688 RHOB,FDM 2.469 DRMO CA. LI~FDM 8'227 " GR TNP~,CN~ 41.882 TNRA RCFT'CNM 498~604 :CNTC CALI,CNM 8,227 TENS RHOB,FDH CALI.FDH TNPN,CNH RCFT.CNH A[.t.CNH CAL!.FDM TNPB.CNH RCFT,CNh CALI.CNM RMOB.FDN CAL!.FOH TNP~,CNH RCFT,CNH CALl,CNN ~HOB,FDH CALI.FDH TNPH.CNH RCFT.CNR CALI.CNH RHOB,FDH CADI,FOH TNPH CNH RCFT~CNH CALI.CNH FDH FDH 2 431 DRHO.FDH 8 469 GR,FDM 43 297 TNRA.CNM 497 ~57 CNTC,CNM 8 469 TEN$.CNH 2 480 DRMO,FDH 8 531 GR ~ FDM 41 393 TNRA.CNH 614 494 CNTC,CNM 8 531 TEN$'CNB ,466 DRMO.FDN ~8,508 GR~FD~ ,318 TNRA'CNH 8.508 TENS,CNH 2 8 43 372 8 72 DRHO 952 TNRA.CNh 508 TENS 2 394 DRHO.FDN 8 641 GR FDH 44 932 TNRAiCNH 391 101 CNTC CN~ 8 641 TENS.C~H :3;506 1927,175 2524,000 0,027 11~,875: 1953,668 4200,333 ,000 0.037 2151;6 3 4!08'0 0 0 029 81 2777 522 4180 000 0,010 128,500 3,718 1781,212 4124,000 0 003 11.9:688 3.934 ~773.054 3994.000 **** FILE TRAILER **** FILE NAME : EDIT .O02 SERVICE : FL!C VERSION : O01A04 DATE : 89/12/21 MAX REC SIZE ~ 1096 FILE TYPE : LO bAST FILE : TaPe Verification Listing hlU~berger AlasKa Computing Center 21-DEC-198~ !3:52 !:9 **** TAPE TRAILER **** ~SERVICE NAME : EDIT DATE : 89/12/2t ORIGIN : FLIC TAPE NAME : 73600 CONTINtATION~ ' ~] ~ .....:1, ..... · PREVIOUS TAPE COMMENT : ARCO ALASKA, INC,,KUPARUK,2K - !0,50-103-20106-00 **** REEh TRAILER **** SERVICE NAME : EDIT DATE : 89/12121 ORIGIN : FL.IC REEL NA~E : 73600 CONTINUATION # PREVIOUS REEL COMMENT : ARCO ALASKA, !NC,,KUPARUK,2K - 10,50-!03-20106-00 -) E X × ~ ~ N NN OO O i 4, N 0 O i 4. VV VV EEEEEEEEEE RRRRRRRR I I I I I t FFFFFFFFFF YY Y¥ VV VV EE RR RR I I FF YY YY v'v ~ VV VV EEEEEEEE RRRRRRRR I I FFFFFFFF YY VV VV EE RR RR i ~ FF YY 27 VV EEEEEEEEEE RR RR I I I I I I FF YY l... ........ 43i .... , ~ ::i .... TT AA AAPP EEEEEEEEEE ;~ :~ .... TT AA AA PP EEEEEEEEEE ;; 111111 54 551 56! 57i i59 .3 .) ~-: File _~45DUA281' [EXAN014. TAPE]VER!FY. TAPE~ 1 (8:;?0,5,3>, last we¥ised ~n i7-JAN-i?~.O 15-a..~, is a 38 block :,: lJI~C.'-[H42ilI, EXANOi-435-- The recowds awe variable length ~,i't'h sequential ~ile o~oed bg ?eco~tJ is 86-b-'.~,es. (~05) queued to LP_RM!228_A on I7-UAN-1990 16:02 by user EXANO14, UIC on prln et~--~AKVXO~$IXD~' on l¥-dAN-i990--1-6:O~ ~ [H42111,EXANOi4], undm'r account H41ill at ~iovi~y 65 -0 -. -.~ -: -_ 77777777777-777777-7i/7771---U~~ Equipmen~ Corpora-~:~''=--'VA×-~~-~ersi~n %~.~ CzTC;~,~~-- 7777777~77777777777~77777777777777777~77777777777777777777777777777777777~777777.777777777777777777777777 ORIGIN · REEL NAME TAPE HEADER CONTINUATION W ' PREVIOUS TAPE · THIS TAPE CONTAINS DATA WRITTEN IN LIS FOP. MAT BY PETROS ROUTINE STATE ' ALASKA COUNTRY: ~SA TOWNSHIP: ION RANGE : 8E ~ APi NUMbeR' 50103~0i0800 NEUTRON POROSITY IS IN SANDSTONE POROSITY UNITS FILE NAME : LISW~T. 001 SERVICE NAME : VERSION ~.' DATE ' ~0/0!/!7 MAXIMUM LENGTH ' i0~4 COMMENTS FIEL WELL ENTRY ~LocK~ DESCRIPTION UP/DOWN FLAO =~qS:-.. 4. I.. 66. DATUM SPECIFICATION BLOCKS or LDT 2 AP i O. O. O. O. 1. 4. O. 1. 68. PEF LDT 3 B/E O. O. O. O. 1. 4. O. 1. 68. R i LM D I l 12 OHMM O, O, O, O, 1, 4, O, 1, 68, R!LD OIL 13 OHMM O, O, O, O, !.. 4~ O, 1, 68, '4. O; URAN NOT 43 PPM O. O. O. O. i, 4. O. 1. 68. THOR NET 44 PPM O. O. O. O. I. 4. O. 1. 68. ********** DATA ***'~****** RILM -9999. 000 RILD -9999, 000 NPHi 35, 644 SOIl 101, 385 COR 85, 033 POTA O. 024 URAN i. 984 THOR I0, 218 2~4'50 RILM 2.000 RILD 1,937 NPHi 41,031 SQR 122,414 COR 99.625 POTA 0.028 URAN 2.765 THOR i2. i52 DEPT 6900.000 CALl 6. DRHO -0.007 RHOB 2. RILM 2.256 RiLD 2. 186 CQR 94.269 POTA 0.026 -~ 53-4-4T-000---~ 4572.000 DEPT 6950.000 CALl 6.500 ~HO 0.140 RHOB 2.431 RILM 1.743 RiLD 1.698 COR 105.201 POTA 0.025 ~ 0444.000 TEN8 4620.000 DEPT 7000.000 CALl --DRFtO 07097 RHOB RILM 1.716 RILD CQR 101.539 POTA DEPT 7050~:i000 CALI -DRHO -0.010 RHOB RiLM 2.383 RiLD C~R 91.446 POTA 066 OR i09.750 PEF 3.238 484 DT 101.400 RSFL 3.004 NPHI 38.828 S~R 121. 121 URAN 3.258 THOR 11.765 '< QR 108.875 PEF 6. 836 i ( DT 103 i-o~ ~7.~I5 NPH I 4 i. 062 SOR i 22. 752 ~ ir URAN 2. 12~ THOR 14. 448 6. 344 OR 108. 188~ PEF 5. 336 =:. 4,,,.. DT 106..500' R~FL ~--rT. O~l I. 664 NPHi 40. a?a SOR i 18. 454 O. OaS URAN ~. 05~ THOR la. 734 ~ 1 ~.000 .................................................... i06;:250;i'PEF 3.44'3 ~.4~ D~' iO~.~O0 N~FL 37-01~ 2.334 N?H! 3~.203 S~R 117.084 0.024 URAN 3. i10 THOR 11.67i 5 '6 118(" RILM 1.778 RILD COR 103.744 POTA ~, 476 DT ~9. DO0 1.736 NPHI 34.669 SQR 122,267 0.031 URAN 2,247 THOR 12,046 O. OiD NMU~ ,! RILM I. e23 RILD 1.819 NPHi 44.875 SQR i29. i73 COR 100.695 POTA 0.032 URAN 3.455 THOR 10.897 RILM 4. 066 RILD 3. 949 NPHI 23. 800 COR 69. 618 POTA O. 018 URAN 2, 475 THOR 5 ) FRAME SPACING UNITS ~N~ VALUE lIN 9. 4. 65. -9,.v. 00 I 4. 68 iD ORDER ~ LOG TYPE CLASS MOD NO. LEVEL CODE DEPT FT O, O, O. O, 2~ 4, O. 1, 68, DEPT 3050. 000 DT 118 063 GR 81 688 TENS I ;6~, 000 3x~ TENS iR ~ DEPT 3200.000 DT !!7. 188 QR i13. -5 ~Ou. O00 !34 DEPT 3350.000 DT i11.875 GR 107.438 TENS I895.000 ..) , DEPT ) .:.~ DEPT 3550. 000 DT ..,.;--DEFf, 3600. OOO --DP-- 3500.000 DT 106.438 GR 87,500 TENS 2030.000 1121813 GR ii4'.'3i3 GR I04.500 :TENS 2040.000 96. i88' TENS _,~ DEPT 3650. 000 DT 117. 625 GR I00. ~38 TENS 2030. 000 .~:: DEPT 3700. 000 DT 117. 87.5 GR 86,. 438 TENS 2084. 000 .,-'DEP"f 3¢;5~. 000 D] i i 3 438----t'~.. ......... -"2=084.000 :~ DEPT 3800. 000 DT 1 i0. 188 GR 94. !25. TENS _,..,.,,=..,...~" ~o OOn_ 5~ } ~ DEPT 3850, 000 DT , - DEPT 3900. 000 D7 112.500 GR ~5.500 TENS 1-I'~~ 2130.000 ) DEPT 3.~50. 000 DT 113. .e38 GR 106, 750 TENS 2164. 000 RILM i6 C~gR ~1 RILM C~R 0.0~5 RHOB 1.792 RILD 98.47i POTA 1.956 RiLD 92.078 POTA -0.007 RHOB RILM 2.275 RILD COR 93.012 POTA 1,719 NPHI 0.029 32. t03 SQR 0°44= RILM 1.825 RILD C~R 93.009 POTA 2'i"'5'~2 ....... DT i, 898 NPHI O. 028 URAN 323 THO~ ~3 DT 287 NPHI 025 URAN 26.466 1. ~ ~ ~6~ SQR THOR ;2. 400 NP H I O. 02,5 UR AN SQR THOR / 124 4.~_ i 16. 04.~ 10. 255 107 -.~o I1. 756 I07,533 11.755 FILE NAME 'LISWRT. O01 SERVICE NAME ' PREVIOUS FILE · ~', ~ UPHOLE BOREHOLE COMPENSATED SONIC DATA FILE NAME LISWRT.~~ SERVICE NAME ' ~ ~., DATE ' 90/01/17 ~.. MAXIMUM LENQTH · ~: FILE TYPE ' LO ~ ~? PREVIOUS FILE ' 1024 LISWRT. OO1 ~ COMMENTS ~ ?i~.~ F I EL D WELL DEPT 4700.000 DT 96.500 OR 88.375 TENS 2650.000 41~00. 000 DT 3oI DEPT 34h33 4850.000 DT 110. 125 OR 103. 125 TENS 4~DO. OOO DT I 11~. 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' 10~4 -'FI'~E~": L 0 PREVIOUS FILE ' ,: ** TAPE TRAILER ;._ SERVICE NAME 'LISWRT ~ OR 10IN ' -~ TAPE NAME · --- CONTiNUATiON ~ ' PREVIOUS TAPE ' COMMENTS - McCORD-LEWIS ENERQY SERVICES - PETROS WELL LOQ ANALYSIS SYSTEM i ~SL 4~ EEEEE X E X EEEEE X X AAA N N 000 1 4 4 X A A N N 0 0 1t 4 4 X A A N N 000 i i i 4 V V EEEE RRRR I V V E RR I t FFFF Y T A A PPPP EEEE ~ 1 F Y T AAAAA P E ~ t ,42 43~F- :s Oualit=iers: /NOFEED /FLAQ /fORM=DEFAULT /LENQTH=66 /LIBRARY=SYSSLIBRARY: SYSDEVCTL. TLB /MAROiN=(BOTTOM=6) /TRAILER /TRUNCATE File _$45DUA281-[EXANOI4. TAPE]VERiFY. TAPE; 1 (8990,5,3), last. revised on 17-dAN-!990 t5:49, is a 38 block sequential ~ile owned IIIC--[~~Ii, EXAN0i4]. - The records are varia dob VERIFY (205) queued to LP_~M1228_A on 17-dAN-1990 16'02 bu. user EXANO14, UIC [H42111,EXANO14], under account H41111 at prioritg print--~---_?KVXO~TXDS: 'on i7-dAN-ig. 90 i6:02 .~rom queue--L-P~,-RMl~?7 7777777777~77777777 DtB~-~l~fu~i-p-m-~-~~p~-r~-i~w~~7~S--V'~-si-~n VS.i -?~77777'7777777~/7777-777-,77z 77777777777777777777777777777777777777777777777777777777777777777777777777777777777777777777777777777777 -'-'~.. comp i eteo ~ T > ~iliI!iili ~ ~,, iiliiilili iiliiili!i F!~i-i-I-I-Fi-t-T ........... iiliiiii!i