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198-081
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Brooks, Phoebe L (OGC) To:NSK DHD Field Supv Cc:Regg, James B (OGC) Subject:RE: 10-426 form for 3K-pad SI non-witnessed MIT-IA"s 5-8-25 Date:Wednesday, June 18, 2025 2:28:23 PM Attachments:image001.png Matt/Bruce, I made a minor revision, changing the report date to 05/08/25. Please update your copy. Thank you, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: NSK DHD Field Supv <n2238@conocophillips.com> Sent: Thursday, May 8, 2025 6:41 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: NSK Wells Integrity Eng CPF1 & CPF3 <n1617@conocophillips.com> Subject: 10-426 form for 3K-pad SI non-witnessed MIT-IA's 5-8-25 Morning, Please see the attached 10-426 form from the 3K-pad SI non-witnessed MIT-IA’s that was performed on 5-8-25. If you have any questions, please let me know. Thanks, Matt Miller/ Bruce Richwine DHD Field Supervisor .58. 37' KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com Submit to: OOPERATOR: FIELDD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861020 Type Inj N Tubing 1275 1275 1275 1275 Type Test P Packer TVD 6420 BBL Pump 1.2 IA 450 2030 1975 1950 Interval 4 Test psi 1605 BBL Return 1.2 OA 25 30 25 25 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861040 Type Inj N Tubing 1450 1450 1450 1450 Type Test P Packer TVD 6431 BBL Pump 2.0 IA 700 2010 1930 1910 Interval 4 Test psi 1608 BBL Return 2.0 OA 150 150 160 160 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861250 Type Inj N Tubing 1350 1360 1360 1360 Type Test P Packer TVD 6564 BBL Pump 1.6 IA 300 2030 2010 2000 Interval 4 Test psi 1641 BBL Return 1.6 OA 10 10 10 10 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1861510 Type Inj N Tubing 1200 1250 1250 1250 Type Test P Packer TVD 6606 BBL Pump 1.2 IA 140 1900 1880 1880 Interval 4 Test psi 1652 BBL Return 1.2 OA 10 10 11 11 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980810 Type Inj N Tubing 1340 1350 1350 1340 Type Test P Packer TVD 6548 BBL Pump 1.0 IA 700 2040 2030 2030 Interval 4 Test psi 1637 BBL Return 1.0 OA 320 480 480 480 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1970770 Type Inj N Tubing 1080 1210 1100 1090 Type Test P Packer TVD 6621 BBL Pump 1.2 IA 220 1940 1915 1910 Interval 4 Test psi 1655 BBL Return 1.2 OA 540 620 580 580 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980820 Type Inj N Tubing 1340 1475 1425 1400 Type Test P Packer TVD 6117 BBL Pump 1.0 IA 100 2110 2080 2070 Interval 4 Test psi1529BBL Return1.0OA25252525 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1980770 Type Inj N Tubing 820 840 840 840 Type Test P Packer TVD 6275 BBL Pump 1.3 IA 200 1800 1790 1790 Interval 4 Test psi 1569 BBL Return 1.1 OA 25 40 40 40 Result P TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting 3K-31 3K-34 Notes: 3K-25 3K-26 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanicall Integrityy Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: 3K-07 Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3K Pad Gschwind/Sheets 05/08/28 Notes: Notes: Notes: Notes: 3K-02 3K-04 3K-18 Form 10-426 (Revised 01/2017)2025-0508_MIT_KRU_3K-25 9 9 9 9 9 999 99 99 9 -5HJJ 3K-25 MEMORANDUM TO: Jim Re gg � ID It g/�( P.I. Supervisor ��C� FROM: Austin McLeod Petroleum Inspector Well Name KUPARUK EIV UNIT 3K-25 Insp Num: mitSAM210506073129 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 13, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3K-25 KUPARUK RIV UNIT 3K-25 Sre: Inspector Reviewed By.::..�--9pp P.I. Supry 15 Comm API Well Number 50-029-22881-00-00 Inspector Name: Austin McLeod Permit Number: 198-081-0 Inspection Date: 5/5/2021 Thursday, May 13, 2021 Page I of I Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-25 Type In' w TVD GSSz Tubin 3120 �- 3120 I 3120 - 3120 -- P'fI) 1980810 Type Test SPT Test psi .� 1638 IA 730 2010 1980 , 1980 - BBL Pumped: o.a - BBL Returned: _. os - --- OA - 33s-_� a90 aao_ �so- _ Interval 4vRTST 'P/F P Notes: MITIA - Thursday, May 13, 2021 Page I of I r Ifrb e f�c�1P - N Obi- Cl e- 0 (Q far 0 t1 0 t ill V -0 > N m Clop v 0 >_ +_, ti o-w ai OD - m o +, J a Y O C U O a) E > QQ' O 'C e- r0 aN, 0 v a1 Mg O .> V d 0. 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N t() Q UU an W 111 -• '—y m v „. z m £ v > w Y O w cc ` c ala U 0 Q IO 2 _ i0 0 d t7 ~ v Qi 'i Q t00 coNco 'n •v 0 O T .+ +� Vl F- a, E z N t)4 Hl z e- e- O '- N N O 0 0 _ QJ A = E In 2 r� J 6 Y Y Y LL 2 m a% a a O d Q O N J M M M M N Z OJ CO • f� ' r-I .0 w C C ra vi r v � 4-1 C Q ` .c 0) CO O CA a 3 Q F- a a Q • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Tuesday,May 16,2017 P.I.Supervisor ��,�f y (7 SUBJECT: Mechanical Integrity Tests (( CONOCOPHILLIPS ALASKA INC 3K-25 FROM: Chuck Scheve KUPARUK RIV UNIT 3K-25 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry JpC NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3K-25 API Well Number 50-029-22881-00-00 Inspector Name: Chuck Scheve Permit Number: 198-081-0 Inspection Date: 5/9/2017 Insp Num: mitCS170511120955 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3K-25 Type Inj W 'TVD 6552 - Tubing 2900 2900 - 2900, 2900- PTD 1980810 Type Test SPT Test psi 1638 IA 670 1990 ° 1960 , 1960 , BBL Pumped: 0.8 JBBL Returned: 0.9 - OA 300 480 - 460 - 460 Interval 4YRTST 1P/F P Notes: SCANNED JUl,, 1 12017 Tuesday,May 16,2017 Page 1 of 1 41) ConocoPhillips Alaska P.O. BOX 100360 RECEIVED ANCHORAGE,ALASKA 99510-0360 JUL01 2015 June 29, 2016 AOGCC Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501S AME® a 9 2.016 Commissioner Cathy Foerster: Enclosed are the spreadsheets with a list of wells from the Alpine field(CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheets serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name,top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincere 1 j Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Alpine Field Date 6/29/2016 3H&3K Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal _ 3H-31 50103202050000 1940190 12" NA 12" NA 3 6/22/2016 �3K-25 _ 50029228810000 1980810 10" NA 10" NA 5 6/22/2016 3K-26 50029227640000 1970770 14" NA 14" NA 12 6/22/2016 STATE OF ALASKA Alt OIL AND GAS CONSERVATION COIV SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extension 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-0810 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service 50-029-22881-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025519 KRU 3K-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/ Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10170 feet Plugs(measured) None true vertical 6868 feet Junk(measured) None Effective Depth measured 10104 feet Packer(measured) 9650 true vertical 6827 feet (true vertical) 6548 Casing Length Size MD TVD Burst Collapse CONDUCTOR 84' 16 122' 122' SURFACE 5523' 7 5/8 5560' 4151' Production 9604' 51/2 9640' 6542' Liner 530' 41/2 10170' 6868' RECEIVED Perforation depth: Measured depth: 9754-9778, 9792-9862 1 �� � True Vertical Depth: 6611-6625, 6634-6677 ti JUN 2 3 2016 AOGC Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 9650 MD,6548 TVD Packers&SSSV(type,MD,and ND) NIPPLE=CAMCO DS NIPPLE w/2.813"NO GO PROFILE @ 527 MD and 527 TVD SEAL ASSY=BAKER GBH-22 SEAL ASSEMBLY @ 9650 MD and 6548 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Bectronic Fracture Stimulation Data r GSTOR r WINJ WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-296 Contact MJ Loveland Email: n1878(C7conocophiIIIps.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature /2! ignature �J Phone:659-7043 Date /6, 7 Z>../t›- --/- -t----------- vrL q/2//L RBDMS tAV JUN 2 3 2016 Form 10-404 Revised 5/2015 Submit Original Only • • Ipv ConocoPhillips RECEIVED Alaska J U N 2 3 2010 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC June 20, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 3K-25, PTD 198-081 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 0 3K-25 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/19/16 Welded 10" conductor extension to stablize well head • OF T� • • \� Iy7, .s. THE STATE Alaska Oil and Gas 9 �►._, �a Conservation CommissionFr M __ ALAS f 333 West Seventh Avenue — GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS� Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor SCANNED SEP 2, 8 2016 Conoco Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3K-25 Permit to Drill Number: 198-081 Sundry Number: 316-296 Dear Ms. Loveland: 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, Ltigy i°4CAAILE— Cathy . Foerster Chair DATED this 2- day of June, 2016. RBDMS 0 6 2016 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 3 1 201 APPLICATION FOR SUNDRY APPROVALS ors 6 12-1 I b 20 AAC 25.280 OGCC 1.Type of Request: Abandon r Plug Perforations r Fracture Stimulate E Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing`'r. Other: Conductor Extension P. 2.Operator Name: 4.Current Well Class: Y'+' 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development r 198-0810 ' 3.Address: Stratigraphic r Service rr 6.API Number: P. 0. Box 100360, Anchorage, Alaska 99510 50-029-22881-00 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA 1 Will planned perforations require spacing exception? Yes r No P / KRU 3K-25 " 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0025519 Kuparuk River Field/ Kuparuk River Oil Pool ' ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10170 ' 6868 10104' 6827' ` 3400 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 83' 16 121' 121' SURFACE 5523' 7 5/8 5560' 4151' Production 9604' 51/2 9640' 6542' Liner 530' 4 1/2 10170' 6868' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9754-9778, 9792-9862 ' 6611-6625,6634-6677 3 1/2 L-80 9650 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE=CAMCO DS NIPPLE w/2.813"NO GO PROFILE , MD=527 TVD=527 SEAL ASSY=BAKER GBH-22 SEAL ASSEMBLY • ` MD=9650 TVD=6548 12.Attachments: Proposal Summary F. WellBore Schematic ,p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r 14.Estimated Date for 15. Well Status after proposed work: 06/16/16 OIL r WINJ r . WDSPL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878conocophillips.com Title: NSK Well Integrity Project Supervisor Signature '7i l e-_ Date: _ __ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 t c — act cc Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance E Other: RBDMS L,l. JLI062016 / Post Initial Injection MIT Req'd? Yes r No I" Spacing Exception Required? Yes r No ,r7 Subsequent Form Required: /Q - 4 b 4, APPROVED BY Approved by: 8 / 1/t/ _ COMMISSIONER THE COMMISSION Date: 6_2_/6 64/,,,,:b, Submit Form and Form 10-403 Revised 11/2015 QrRvIGPIic ,4nAvll for 12 months from the ate of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska MAY 3 1 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC May 27, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3K-25, PTD 198-081 conductor extension. / Please contact me at 659-7043 if you have any questions. Sincerely, Xfj-1 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska, Inc. Kuparuk Well 3K-25 (PTD 198-081) SUNDRY NOTICE 10-403 APPROVAL REQUEST 05-27-16 This application for Sundry approval for Kuparuk well 3K-25 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 10". With approval, the conductor extension will require the following general steps: 1. Examine surface casing for any corrosion damage if it is exposed. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP INJ • 3K-25 a ConocoMillips iti Well Attributes Max Angle&MD TD ska Inc. Wellbore API/UWI Held Name Wellbore Status ncl(') MD(ftKB) Act She(ftKB) Ccr,ocoPNBpc 500292288100 KUPARUK RIVER UNIT INJ 57.14. 6,493.31 10,170.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3K-25,9/23/201512:50:15 PM SSSV:NIPPLE Last WO: 41.02 5/26/1998 V@NGel schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 10,004.0 9/22/2015 Rev Reason:PULL GAUGES pproven 9/23/2015 'Casing Strings I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread CONDUCTOR 16 15.062 38.0 121.0 121 0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER;36.4 . SURFACE 75/8 6.875 37.0 5,560.0 4,151.0 29.70 L-80 ABM-BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.950 38.0 10,170.0 6,867.5 15.50 L-80 LTC-MOD 5.5"x4.5"@ 9640' Tubing Strings . , . , ) ,, way Tubing Description String Ma...ID/n) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection ll TUBING 31/2 2.992 36.4 9,652.0 ....6,546.9 9.30 L-80 EUE8RDMOD Completion Details Nominal ID i Top(ftKB) Top(ND)(ftKB) Top Incl(1 Item Des Corn (in) 36.4 36.4 0.00 HANGER FMC GEN IV TUBING HANGER w/PUP 3.500 526.8 526.7 2.85 NIPPLE CAMCO DS NIPPLE w/2.813"NO GO PROFILE 2.813 CONDUCTOR;38.0-121.0 ' 9,605.4 6,520.9 53.55 NIPPLE CAMCO D NIPPLE w/2.75"NO GO PROFILE 2.750 I 9,650.0' 6,547.8 53.38 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY w/15'SEALS& 3.000 LOCATOR W/1'SPACEOUT Perforations&Slots NIPPLE;526.8 'V1 Shot a Dens Top(TVD) Btm(TVD) (shots/f lop(kKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,754.0 9,778.0 6,610.8 6,625.5 A-3,3K-25 5/24/1998 ' 4.0 (PERF 2 1/8"ENERJET,DP 9,792.0 9,862.0 6,634.0 6,676.9 A-2,3K-25 5/24/1998 4.0 IPERF 2 1/8"ENERJET,DP Mandrel Inserts St atl on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 9,545.6 6,485.1 BST AXT 1 GAS LIFT DV T-1 0.000 0.0 5/24/1998 Notes:General&Safety SURFACE;37.5-5,560.0 . End Date Annotation 5/24/1998 NOTE:7 5/85(5 1/2"ANNULUS HAS NOT BEEN ARCTIC PACKED.DO NOT BLEED OFF. 11/3/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9,545.6 -' 4 I NIPPLE;9,605. : i A IL III ILI 1 SEAL ASSY;9,650.0 . 1. 't (PERF;9,754.0-9,778.0 IPERF;9,792.0-9,862.0 PRODUCTION 5.5'x4.5'@ 9640';38.0-10,170.0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reggaalaska.aov; AOGCC.Inspectors(rDalaska.00v; phoebe.brooksaalaska.gov chris.wallace@alaska.pov OPERATOR: ConocoPhillips Alaska,Inc FIELD!UNIT/PAD: Kuparuk/KRU/3K Pad 'Z/J l 6.1,t( ' DATE: 05/28/13 c Q Q t] F OPERATOR REP: Hight/Phillips I °f v �5 AOGCC REP: K f Packer Depth _ Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. _ Well 3K-25 Type Inj. N TVD '6,765' Tubing 50 50 50 50 Interval 4 P.T.D. 1980810 Type test P '/ Test psi 1691.25 Casing 170 3,027 ' 2,975 -2,960 P/F P Notes: Non witnessed OA 320 680 ' 660 " 660 ' Well 3K-26 Type Inj. N TVD 6,637' Tubing 2,300 2,350 2,300 2,300 Interval 4 P.T.D. 1970770 Type test P Test psi 1659.25 Casing 770 3,025 2,981 2,975 P/F P Notes: Non witnessed OA 560 710 700 700 TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D=Drilling Waste M=Annulus Monitoring I=Initial Test G=Gas P=Standard Pressure Test 4=Four Year Cycle I=Industrial Wastewater R=Internal Radioactive Tracer Survey V=Required by Variance N=Not Injecting A=Temperature Anomaly Survey 0=Other(describe in notes) W=Water D=Differential Temperature Test scANNED FEB 2 0 2014 Form 10-426(Revised 11/2012) 201 3-0528 MIT KRU_3K-pad_2wells.xlsx MEMORANDUM TO: Jim Regg ~ ~~ ~'~l ~~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 20, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-25 KUPARUK RIV UNIT 3K-25 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprvJ~t-- Comm Well Name: KUPARUK RN UNIT 3K-25 Insp Num: mitCS090515164502 Rel Insp Num: API Well Number: 50-029-22881-00-00 Permit Number: 198-081-0 Inspector Name: Chuck Scheve Inspection Date: 5/15/2009 Packer Depth Pretest Initial IS Min. 30 Min. 45 Min. 60 Min. Well T 3K-25 Type Inj. N TVD 6765 IA 50 2320 2280 2280 P.T.D 1980810 TypeTest sPT Test psi 1691.25 OA 360 650 620 600 Interval axRTST p~F P -~ Tubing o 0 0 0 Notes: Pretest pressures observed and found stable . Well demonstrated good mechanical integrity. Wednesday, May 20, 2009 Page 1 of 1 . . ~ ConocoPhillips Alaska .JUl I) 3 2007 & Gas COris, P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2,2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 \ CA. <b ~ oC/) \ SCANNED JUL .0 5 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. ~~ M.J. Loveland ConocoPhillips Well Integrity Supervisor e------ . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft na Qal 1 C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 -'03-003 27" none 27" na 10 III .4/2007 Id/'////// 3K-12 186-165 6" none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 J.. y ....&:../.l ., ... "'-J ... '-L"'1J.. ., V U 1".1. .::naIe 01 AlaSKa Alaska Oil and Gas Conservation Comn. ")n TO: ) ~~ S~:~isor 'R eft 1,1 ¡ ~I ¡)Ç DATE: Wednesday, May 25,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3K-25 KUPARUK RIV UNIT 3K-25 FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3K-25 Insp Num: mitCS050521155626 ReI Insp Num: API Well Number: 50-029-22881-00-00 Permit Number: 198-081-0 Packer Well 3K-25 Type Inj. I N I TVD P.T. 1980810 TypeTest SPT Test psi Interval 4YRTST P/F P Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. \C\~/O~\ Reviewed By: P.I. Suprv :fS.Æ- Comm Inspector Name: Chuck Scheve Inspection Date: 5/21/2005 Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 6552 I IA I 0 2140 2120 2120 1638 lOA 300 600 600 600 Tubing 275 275 275 275 SCANNED JUL n '7 2005 Wednesday, May 25, 2005 Page 1 of 1 ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test f&y~~1 Email to: Tom_Maunder@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; and Jim_Regg@admin.state.ak.us \~.:,!' , 'll OPERATOR: ConocoPhillips Alaska Inc. SCANNED MAY ~: Et 2005 FIELD 1 UNIT 1 PAD: Kuparuk 1 KRU/3K DATE: 05/21/05 OPERATOR REP: Arend 1 Sauvageau - AES AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. well 3K-02 I Type Inj I S I T.V.D. 6421 I Tub~ng I 27501 27501 27501 2750 Interval I 4 P.T.D. 1861020 Type Test P Test psi 1605 Casing 1100 2000 1950 1950 P/F P Notes: OA: 500 I 550 1 550 I 550 well 3K-04 I Type Inj I S I T.V.Do 6431 I Tub~ng I 30001 30001 30001 3000 Interval I 4 PoT.D. 1861040 Type Test P Test psi 1608 Casing 1000 2100 2040 2040 P/F P Notes: OA: 250 I 350 I 350 I 350 Well\3K-05 I Type Inj I S I TV.D. 6341 I Tubing I 27501 27501 2750\ 2750\ Interval \ 4 PoT.D. 1861230 Type Test P Test psi 1585 Casing 1400 2100 2070 2070 P/F P Notes: OA: 880 I 940 I 940 I 940 well 3K-07 I Type Inj I S I T.V.D. 6565 I Tub~ng I 29501 29501 29501 2950 1 Interval f 4 P.T.D. 1861250 Type Test P Test psi 1641 Casing 450 2100 2040 2040 P/F P Notes: OA: 220 1 340 /340 I 340 we1l13K-12 I Type Inj I S I T.V.D. 6644 I Tubing I 28501 28501 28501 2850 I Interval I 0 PoT.D. 1861650 Type Test P Test psi 1661 Casing 400 2040 2000 1980 P/F P Notes: MIT IA done early to get on pad cycle OA: 200 1 480 I 480 1 480 Well\3K-13 I Type Inj I S I T.V.D. 6376 I Tubing I 28501 28501 28501 2850 Interval 4 P.T.D. 1861360 Type Test P Test psi 1594 Casing 550 2110 2050 2050 P/F P Notes: OA: 400 1 600 I 600 I 600 well 3K-15 1 Type Inj I S I T.V.D. 6448 I Tubing I 28501 28501 28501 28501 Interval 1 4 P.T.D. 1861380 Type Test P Test psi 1612 Casing 500 2070 2000 1980 P/F P Notes: OA: 300 1 450 / 450 1 450 Well\3K-18 I Type Inj I S I T.V.D.\ 6605 I Tubing I 22001 22001 22001 2200 I Interval I 4 P.T.D. 1861510 Type Test P Test psi 1651 Casing 100 2800 2750 2740 P/F P Notes: OA: 440 1 560 / 560 1 560 well 3K-19 I Type Inj I S I T.V.D. 6331 I Tubing I 27501 27501 27501 2750 1 Interval I 4 P .T.D. 2011080 Type Test P Test psi 1583 Casing 1000 2130 2130 2130 P/F P Notes: OA: 460 1 620 1620 1 620 Well\3K-25 l Type Inj I N I T.V.D.\ 6552 I Tubing I 27~1 275\ 275\ 2751 Interval I 4 P.T.D. 1980810 Type Test P T est psi 1638 Casing 2140 2120 2120 P/F P Notes: OA: 300 I 600 1 600 1 600 well 3K-26 I Type Inj I S I T.V.D. 6656 I Tubing I 27501 27501 27501 2750\lnterval 4 P.T.D. 1970770 Type Test P Test psi 1664 Casing 900 2180 2160 2160 P/F P Notes: OA: 720 I 780 1 780 1 780 well 3K-30 I Type Inj I S I T.V.D. 6580 I Tubing I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1971130 Type Test P Test psi 1645 Casing 250 2100 2070 2070 P/F P Notes: OA: 200 1 460 I 450 1 450 Well\3K-31 I Type Inj I S I T.V.D.\ 6117 I Tubing I 285~1 2850\ 28501 2850 \ Interval I 4 P.T.D. 1980820 Type Test P Test psi 1529 Casing 2140 2120 2120 P/F P Notes: OA: 300 1 600 1 600 1 600 well 3K-34 I Type Inj I S I T.V.D. 6285 I Tub~ng I 28501 28501 28501 2850 I Interval I 4 P.T.D. 1980770 Type Test P Test psi 1571 Casing 300 2140 2140 2140 P/F P Notes: OA: 400 1 650 1 650 1 650 Test Details: TYPE INJ codes TYPE TEST Codes INTERVAL Codes F = Fresh Water Inj M = Annulus Monitoring I = Initial Test G = Gas Inj P = standard Pressure Test 4 = Four Year Cycle S = Salt Water Inj R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey Test during WorKover D = Differential Temperature Test o = Other (describe in notes) MIT Report Form MIT KRU 3K 05-21-05.xls 5/24/2005 Revised: 05/19/02 • • Maunder, Thomas E (DOA) From: Jeff A Spencer [jspencer~ppco.com] Sent: Monday, January 07, 2002 10:18 AM To: Maunder, Thomas E (DOA) Subject: GKA Sundry Reports Tom, Just wanted to give you a quick heads up that we are sending in 8 Sundry Reports (one 403, seven 404's) for your review and approval. Also, just wanted to give a little more info on two of the we'?c ~e 2K-25:`( ,onversion Candidate) CBL was questionable (not run under pressure, but !~~ looks like a potential channel to me). Anyway, we submitted a Form 10-403 but plan on running a Water Flow Log to verify zonal isolation and will forward the results to you as soon as we get it. 2M-09A: (H20 to WAG Injector) In our ongoing efforts to reconcile AOGCC records with PAI's records we noticed that this well's Form 10-404 was missing and so submitted a new 10-404 showing initial gas injection commencing in March 2000. Hope you had a great Holiday Season! Jeffrey A. Spencer Production Engineering & Offtake Supervisor Phillips Alaska, Inc. 907-659-7226 Slope jspencer@ppco.com ~~ ~, ., _ ~ j ~ ~ - 1 Well Compliance Report File on Left side of folder MD 10!7_0___~ TVD 06868 (.~ompletionDate: 5/25/98 Completed Status: 1WINJ Current: T Name Interval Sent Received T/Cfi) D 8456 L CMT MAP SPERRY MPT/GR/EWR4 OH 7/8/98 7/8/98 4*IN'AAL 9652-10078 CH 5 8/3/98 8/6/98 L DGR/EWR4-MD .~INAL 5590-10170 L DGR/EWR4-TVD ~I>[NAL 4157-6868 L INJP-SPIN/TEM/ t. fdNAL PRES 9660-9930 R SRVY RPT ~qS!~,Y 0-10170. Daily Well Op, Was the well cored? yes ~_.~.~ OH 7/22/98 7/22/98 OH 7/22/98 7/22/98 CH 2 12/21/98 1/5/99 OH 6/26/98 7/1/98 Are Dry Ditch Samples Required? yes ~___~And Received:7--.y~--~m~ Analysis D es crip tion 41,~,'e~r~-3,~s--nn- Comments: Monday, May 01, 2000 Page 1 of 1 STATE OF ALASKA '- ,0 ..' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _ 41' RKE 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360 Stratagrapic__ Anchorage, AK99510-0360 Service .X Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1297' FSL, 317' FWL, Sec 35, T13N, RgE, UM 3K-25 At top of productive interval' 9. Permit number/aooroval number'._ At effective depth: 10. APl number: 2549' FNL, 913' FWL, Sec 26, T13N, RgE, UM 50-029-22881-00 At total depth: '11. Field/Pool: 2595' FNL, 938' FWL, Sec 26, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10170 feet Plugs (measured) None true vertical 6868 feet Effective Deptl measured 10104 feet Junk(measured) None true vertical 6827 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 3.5 Cu Yards 121' 121' Surface 5524' 7-5/8" 364 Sx DLW & 5560' 4151' 500 Sx Class G Production 9604' 5-1/2" 310 Sx Class G 9640' 6542' Liner 530' 4-1/2" (included above) 10170' 6542'-6868 Perforation Depth measured 9754'-9778';g792'-9862' true vertical 6611'-6625';6634'-6677' Tubing (size, grade, and measured depth)0 .JGiNAL 3.5", g.3 Ib/ft, L-80 @ g650' Packers and SSSV (type and measured depth) Packer: None; SSSV: None - Camco DS Nipple @ 527' 13. Stimulation or cement squeeze summary : ~-' ~ ;r ~!~' ~ : Perforate 'A' sands on 6/9/98 Intervals treated (measured) 9754'-9778 '; 9792 '-9862' Treatment description including volumes used and final pressure ., Perforated well w/2-1/8" EJ gun w/DP charges at 4 spt, fp was 50 psi. .,~i;~!!:-:-~:_~ i~il ~ ~i4:!i ;i. ,.:~'- :.. .... ::~' '~',.: ~',~ 14. Representitive Daily Average Production or Ini~tCfion' Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 0 0 0 0 50 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ZX Oil _ Gas _ Suspended _ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Production Engineering Supervisor Date Form 10-404 Re ~/~E(/' 5/88 SUBMIT IN DUPLICATE AR~CO Alaska, Inc. (UPARUK RIVER UNIT SERVICE REPORT 3K-25(4-1)) WELL JOB SCOPE JOB NUMBER 3K-25 PERFORATE, PERF SUPPORT 0,531980731.6 DATE O6/O9/98 DAY 3 FIELD ESTIMATE DAILY WORK PERFORATE A2 & A3 SANDS OPERATION COMPLETE ISUCCESSFUL O Yes ¢"~ No I (~ Yes O No AFC# ICC# I DAILY COST 999195 230DS36KL $22,182 InitiaITbg I FinalTbg I Initial IA 0 PSII 50 PSII 0 PSI I IKEY PERSON SWS-BARTZ ACCUM COST $63,600 FinallA IlnitialOA IFinalOA ITTLSize 0PSI 320PS1[ 320PSl 0.000 " UNIT NUMBER 2128 SUPERVISOR JONES Signed IMin ID I Depth 0.000" 0 FT DAILY SUMMARY SWS PERFORATED A3 FROM 9754' TO 9778' & A2 FROM 9792' TO 9862' IN 4 RUNS W/2 1/8" E J, 4 SPF, DP, 0 I I PHASED, 0 DEG ORIENT. TESTED BOP'S TO 4500#. [Pad] TIME LOG ENTRY 08:30 SWS (BARTZ & CREW) MIRU, HELD TGSM. RU BOP'S & TEST TO 4500#. (WAITED 30 MIN FOR TRIPLEX). 10:30 SECURED RADIO SILENCE. MU GUN & PT LUB TO 3000#. 11:45 MIH W/30' 2 1/8" E J, 4 SPF, DP, 0 PHASED & 0 DEG ORIENT. CORR TO SWS CMT LOG 6-6-98. PRESS TBG TO 300# & PERFED FROM 9832' TO 9862'. 14:15 POH & LD GUNS, ALL SHOTS FIRED. 15:30 MU GUN & PT LUB TO 3000#. 16:15 MIH W/24' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERF FROM 9754' TO 9778'. 17:15 POH & LD GUN, ALL SHOTS FIRED. 18:00 MU GUN & PT LUB TO 3000#. 19:00 MIH W/30' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 9802' TO 9832'. 20:30 POH & LD GUN, ALL SHOTS FIRED. 21:30 MU GUN & PT LUB TO 3000#. 22:15 MIH W/10' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 9792' TO 9802'. 23:30 POH & LD GUN, ALL SHOTS FIRED. RIGGED DOWN & RELEASED SWS @ 01:00AM. NOTE, DID NOT DO A STATIC BHP. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $350.00 $8,240.00 DOWELL $0.00 $9,663.00 HALLIBURTON $0.00 $0.00 LITTLE RED $0.00 $1,000.00 SCHLUMBERGER $21,832.50 $44,697.60 TOTAL FIELD ESTIMATE $22,182.50 $63,600.60 . STATE OF ALASKA ~_~,: ALASKA 'OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well_ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development _ 41' RKF 3. Address: Exploratory ~. 7. Unit or Property: P.O. Box 100360 Strafagrapic__ Anchorage, AK 99510-0360 Service .X Kuparuk River Unit 4. Location of well at surface: 8. Well number: 1297' FSL, 317' FWL, Sec 35, T13N, RgE, UM 3K-25 At top of productive interval: 9. Permit numb~r~,gpproval numb_er: 2248' FSL, 752' FWL, Sec 26, T13N, R9E, UM ~ ~r~' .-. O~-~I At effective depth: 10. APl number: 2549' FNL, 913' FWL, Sec 26, T13N, R9E, UM 50-029-22881-00 At total depth: 11. Field/Pool: 2595' FNL, 938' FWL, Sec 26, T13N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 10170 feet Plugs (measured) None true vertical 6868 feet Effective Deptt measured 10104feet Junk (measured) None true vertical 6827 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 3.5 Cu Yards 121' 121' Surface 5524' 7-5/8" 364 Sx DLW & 5560' 4151' 500 Sx Class G Production 9604' 5-1/2" 310 Sx Class G 9640' 6542' Liner 530' 4-1/2" (included above) 10170' 6542'-6868 Perforation Depth measured 9754'-9778';9792'-9862' true vertical 6611'-6625';6634'-6677' ; .. . Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/f~, L-80 @ 9650' · Packers and SSSV (type and measured depth) Packer: None; SSSV: None - Camco DS Nipple @ 527' _ 13. Stimulation or cement squeeze summary .. Fracture stimulate "A" sand on 6/14/98. 0 I INAL Intervals treated (measured) 9754'-9778 ';9792 '-9862' Treatment description including volumes used and final pressure Pumped 8,891 lbs of 20/40 ceramic proppant into formation, fp was 5012 psi, 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 380 Subsequent to operation 0 0 3088 100 1311 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations __X Oil _ Gas _ Suspended _ Service _X 17. I hereby_certify that the foregoing is true and correct to the best of my knowledge. Signed I~l~{~~ -- Title: Production Engineering Supervisor Date Form 10-404 Rev CI5~'151~ 8 SUBMIT IN DUPLICATE~ ARCO Alaska, Inc. (UPARUK RIVER UNIT SERVICE REPORT 3K-25(4-1)) WELL JOB SCOPE JOB NUMBER 3K-25 HPBD, HPBD SUPPORT 0531980729.5 UNIT NUMBER DATE 06/14/98 DAY 1 FIELD ESTIMATE DALLY WORK PUMP "A" SAND HPBD OPERATION COMPLETE SUCCESSFUL ~ Yes O No ¢"~ Yes O No AFC# ICC# I DAILY COST 999195 230DS36KL $40,812 IKEY PERSON ACCUM COST $40,812 380 PSI 1588PSlI 545 PSI 545 PSII 350 PSI 350PSII 0.000 " SUPERVISOR SCHWENDERMAN Signed Min ID [ Depth 0.000" 0 FI' DAILY SUMMARY I PUMPED ''A'' SAND HPBD MAXIMUM PRESSURE 8545 PSI' PUMPED TOTAL 8891 LBS OF 20/40 PROPPANT' 3780 LBS OF DIVERTER. FINAL TUBING PRESSURE 5012 PSI @ 40 BPM. [HPBD] TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT (YOAKUM / LRS / APC) TGSM HIGH PRESSURE LINES. SET TREE SAVER AND RIG UP SURFACE LINES AND EQUIPMENT. 10:00 PT BACKSIDE AND LINES TO 4000 PSI, OK. PTTO 10,800 PSI, OK. PRESSURE UP ANNULAS TO 3500 PSI. 10:16 PUMPED STAGE #1 BREAKDOWN WITH J-313 SW, 40 BPM TBG PRESSURE AT 8545 PSI. 1PPA PROPPANT AT 40 BPM/5433 PSI. FINAL 40 BPM/5182 PSI. SD OBTAIN ISIP OF 1355 PSI. 10:37 PUMPED STAGE #2 DIVERSION/HPBD/SCOUR, 2 PPG ROCK SALT& GELLED DIESEL/SPACERS@7 BPM & FLUS @ 3O BPM 10:45 FIRST AND SECOND SLUG ON PERFS NO INDICATIONS. FINAL FLUSH PRESSURE AT 40 BPM 4784 PSI. SD AND OBTAIN ISIP OF 1538 PSI. IA STABLE. 10:58 PUMPED STAGE #3 DIVERSION/HPBD/SCOUR, 2 PPG ROCK SALT & GELLED DIESEL/SPACERS @ 7 BPM. SW J313. IA STABLE AT 3495 PSI. 11:17 FIRST AND SECOND SLUG ON PERFS HAD PRESSURE INCREASE TO 5457 PSI. FLUSH PRESSURE AT 40 BPM 4797 PSI. SD OBTAIN ISIP OF 2444 PSI. 12:30 RDMO DS. NOTIFIED DSO WELL READY FOR INJECTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $1,500.00 $1,500.00 DOWELL $39,312.00 $39,312.00 TOTAL FIELD ESTIMATE $40,812.00 $40,812.00 SENT B'/' 1-18-.5~ · 2:87F~] ' AI%:o ALA~KA-~ OU/ :~/b /O~;z.'~ i/ z ARCO Alaska. Inc. .~:.. c~.,.~. 41-'4 _.(4~.~ } Loc. alion: ~OC~-cc-~ ,, Copies 3'0; ~ i Kuparuk Development P. o. BOX 700260 ANCHORAGE, AK 99510-0360 FAX # 907 265-6224 ATO-1279 FAX #: Phone Subject: CASING '[EST and FORMATION INTEGRITY TEST Well Name: 3K-25 Date: 111,2/99 Supervi~r: Don E, Bleeden Casing Size a~d Description: 7-5~", 29.7~.. L-.80, BTC Casing Setting Depth: 5560' T~D 4,152' 'i'VD Mud Weight: 6.8 p~g Hole Depth: 5,560' TMD 4.152' 1'VD EI~','V = Leak-off Press. + MW 0.052 x T'VD 1,4 '.. 0 psi + 6.8 ppg LOT = {0,052'/-152) = 13.3 ppg EMW @ 7-5/8" Csg Shoe Fluid Pumped = 10.0 bbl Pt~np eLrtput = 0.0580 bps ... ~r~l~: STROKES TURN TO MINUTES DURING 'SHUT IN TIME':see time line a~ove LEAK-OFF DATA MINUTES FOR FIT STROKES PRESSURE I SHUT IN TIME~ o stks 120 p~j I 10 slks -'-87.5__p_Esi--'__d_i 20 stks _~,_425, psi 30 stks 1,600 psi 40 stks 1,625 psi :.' so stk~ 60 stks 1_,.6D0 p.___~si__~ 70 stks 1,6D0 psi 90 stks 1,600 psi 1,r~o ~i 130 stks 1,625 psi 150 stks 1,625 160 stks 1,S25 psi 470 =t~_L_t,_ms ~si 18(} stks 1,625 psiI 190 stks 1,625 psi 2o0 ~ ~,s2s mi 220 slbs 1,625 psi_.j ~=0 stks --i,e25 psi! SHUT IN PRESSURE 100 stirs 110 stks 120 stks 0.0 rain 5.0 rain I0.0 min 15.0 rain 20.0 mi~ i 25.0 min i 30.0 rain I ~ 1,625psi [ i-- : 1,250 psi .= i ........... i 1,1"Opsi i ! i 1,15op_~l ! ' 1,~25 psi i 1,000 psi 975 ps[ -. t T .35.0 min 40,0 rain CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ! 0 slks ~____O.psi ! i I I : !. i SHLrT' IN TIME] · ! NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Ol 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 11D-110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 1 E-35 CEMENT MAPPING LOG 981203 1 1 1 E-35 'PRODUCTION LOG 981208 1 1 1 E-36 STATIC PRESS/TEMP 981123 1 1 1G-16 L~! Q.- MI INJECTION PROFILE 981202 1 1 1 Q-07 STATIC PRESS/TEMP 981119 i 1 1 Y- 15A CBL-SCMT 981109 1 1 2M-34 UL~---- MI INJECTION PROFILE 981110 1 1 2W-12 PRODUCTION PROFILE 981028 1 1 3F-04 UtC~ MI INJECTION PROFILE 981203 1 1 3F-12 ~tC. MI INJECTION PROFILE 981204 1 1 3F- 19 RST WFL & GLS 981103 1 1 3G-03 PROD PROFILE W/DEFT 981104 1 1 3K-25 ~,,I E ~, INJECTION PROFILE 981014 1 1 3K-26 ~ ~--_____ INJECTION PROFILE 981014 1 1 SIGNE ~"~'/c~' DATE: Please sign and ~.~e this transmittal to Sherrie at the above address. Thank you. · STATE OF ALASKA .... -~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Operation Shutdown m Re-enter suspended well_ Alter casing _ Repair well__ Plugging__ Time extension _ Stimulate_ Change approved program__ Pull tubing .. Variance_ Perforate_ Other X Annular Iniection 2. Name of Operator ARCO Alaska, Inc. 3. Address ~P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1297' FSL, 317' FWL, Sec. 35, T13N, R9E, UM At top of productive interval 2248' FSL, 752' FWL, Sec. 26, T13N, RgE, UM At effective depth At total depth 2595' FNL, 938' FWL, Sec. 26, T13N, R9E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service X 6. Datum elevation (DF or KB) 41' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3K-25 9. Permit number 98-81 10. APl number 50-029-22881 11. Field/Pool Kuparuk River feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical 10170' feet 6868' feet 10104' feet 6827' feet Casing Length Size Structural Conductor 80' 16" Surface 5519' 7.625" Intermediate 9599' 5.5" x 530' 4.5" Production Plugs (measured) None Junk (measured) Cemented Measured depth True vertical depth 3.5 CY High Early 121' 121' 364 sx DLW 5560' 4150' & 500 sx Class G 310 sx Class G 9640' 6546' tapered string 10170' 6868' Perforation depth: measured 9754'-9778', 9792'-9862' true vertical 6615'-6630', 6638'-6680' Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 9652' Packers and SSSV (type and measured depth) Baker GBH-22 Pkr @ 9650', No SSSV RECEIVED ORIGINAL r"l] JAN 05 1999 AlaSka 0il & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal__ Detailed operation program __ BOP sketch Contact Graham AIvord at 265-6120 with any questions_. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation Januarv 6, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas _ Suspended _ Service X 17. I hereby certify that the foregoing is true and correct to the best of myJ<nowlgdge. _, ~tr , ;/ ' ..- S~gned ~/ ~~~~ T~tle KuparukTeam Leader FOR COMMISSION USE ONLY Conditions of ~:?proval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mecllanical Integrity Test_ Subsequent form require 10-__ ~--I:;~,/.~dr__ ~, c~.~l~.,~.~'.#o ~e¢ a~'.~:7¢~'~:~¢"'~'~(o-~o Approved by the order of the Commission ORIGINAL SIGNEDBY Commissioner IApprova' No~¢~_ ~1 I Date Form 10-403 Rev 06/15/88 Approved CoPY Returr~ed Robert N. Chdstenson SUBMIT IN TRIPLICATE ARCO Alaska, Inc. Cementing Details Well Name: 3K-25 Report Date: 05/16/98 Report Number: 5 Rig Name: RIG # 245 AFC No.: AK9309 Field: Kuparuk Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: I LC Depth: I % washout: 7 5/8" 9 7/8" 55 5560I 5432 I Centralizers State type used, intervals covered and spacing Comments: 52 bow spring centralizers. One on 1st 12 its (1st 3 ran on stop collars in middle of it). After 12 centralizers, ran 1 on every 3rd jt to surface wi Iea on stop rings on each side of stage tool. Hud Weight: PV(prior cond): PV(after cond): J YP(prior cond): YP(after cond): Comments: 9.5 31 17J 40 12 Gels before: Gels after: Total Volume Circulated: 30~52 4/6 675 bbls Wash 0 Type: Volum e: Weight: Comments: Spacer 0 Type: Volume: Weight: Comments: FW 30~20 8.33 Stage 1&2 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: DLW 70 140/224 10.5 4.42 Additives: Class G + 50% D124 + 3.5% D44 + 0.4% D46 + 30% D53 + 1.5% Sl + 1.5% D79 Tail Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: 70 500 15.8 1.15 G Stage 2 tail cement - 60 sx AS1 at 15.8 ppg Additives: G + 1% S1 + 0.2% D46 + 0.3% D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6.8 6.8 230k Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 30 fpm 155k Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 249 bbls / 86 bbls 252 bbls / 90 bbls Calculated top of cement ' CP: Bumped plug: Floats held: surface Date:5/15/98 yes I yes yes / yes Time:O0:30 Remarks:Had full returns throughout job. Reciprocated pipe until 10 bbls before bump plug on 1st stage. Circ out cement contaminated mud after open stage tool. , Cement Company: I Rig Contractor: Approved By: DS I PARKER Dona d Lutrick CASING / TUBING / LINER DETAIL 7 5/8" Csa ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 3K-25 KRU DATE: 5/14/98 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 40.69 RKB to Landing Ring - Parker Rig #245 FMC Fluted Mandrel Casing Hanger 1.72 40.69 42 Jts 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #88 - #129) 1783.96 42.41 Jt'"B"' 7-5/8", 29.7#, L-80, ABM-BTC Casing - Baker Locked 39.46 1826.37 2.83 1865.83 Jt "A" 84 jts Gemoco '754' Stage cementing Tool 7-5/8", 29.7#, L-80, ABM-BTC Casing - Baker Locked 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #4 - #87) Gemoco Insert Shut-Off Baffle 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jt #3) Gemoco Float Collar 7-5/8", 29.7#, L-80, ABM-BTC Casing (Jts #1 & #2) Gemoco Float Shoe 1 Jt 2 Jts 41.81 1868.66 3521.21 1910.47 5431.68 42.75 5431.68 1.30 5474.43 83.06 5475.73 1.50 5558.79 5560.29 TD= 5570.00 PBTD= 5431.68 RATHOLE= 9.71 Baker Lock thru Insert Shut-Off Baffle, plus Sta~le Collar to Joints 'A' & 'B' Install Insert Shut-Off Baffle in Connection on Top of Jt #3 Run Sta~te Collar & Baker Locked Jts 'A' & 'B' on Top of Jt #8; Run FMC Han~ter on Top of Joint # 129 52 Bow Sprina~ Centralizers: One on each of first 12 joints (first two on stop rin~ls), Then one on every 3rd joint to surface, Plus one on a stop final on Baker Locked Jts 'A' & 'B Remarks: Parker Rig #245 Dr#ting Supervisor: Donald Lutrick C" .,ND LEAK-OFF FRACTURE TE~-_.,~ Well Name: KRU 3K-25 Supervisor: Donald Lutrick Date: 5/17/98 Casing Size and Descrip 7 5/8", 29.7#, L-80, BTC Casing Setting Depth: 5560' TMD 4152' TVD Mud Weight: 8.5 ppg EMW = Leak-off Pressure (PL+ MW 0.052 x TVD LOT = 1450 psi/(0.052 x 4158 ft)+8.5 ppg =15.2 pi Hole Depth (md)= 8785' Fluid Pumped = 2.21 bbls. Pump output = ,085 bps 3200 3100 30O0 2900 2800 27O0 2600 2500 2400 2300 2200 2100 2000 1900 1800 1700 1600 1500 1400 1300 1200 1100 IOO0 800 700 300 200 100 0 .::.':: ..... . / ~,/ + LEAK-OFF TEST ~ CASING TEST _ I 0 2 4 6 8 1012141618202224262830323436384042444648505254565860 STROKES ARC O Alaska, Inc. TUBING -- (0-9650, 0D:3.500, ID:2.992) SURFACE -- (0-5560, 0D:7.625, Wt:29.70) Gas Lift landrel/Dumm¥ Valve 1 (9546-9547, 0D:3.500) NIPPLE (9605-9606, 0D:3.500) 3RODUCTION (0-9640, 0D:5.500, Wt:15.50) PBR (9640-9641, OD:5.000) LINER (9640-10169, 0D:4.500, Wt:l 2.70) PKR (9650.9651, 0D:4.500) Perf (9754-9778) Perf (9792-9862) 3K-25 3K-25 APl: t 500292288100 SSSV Type: Annular Fluid: Last Tag: Rev Reason: NEW SCHEM by v§ Casing String - CONDUCTOR Size T~p 16.000 Casing String - SURFACE Size Top 7.625 0 Casing String - PRODUCTION Size Top 5.500 o Casing String - LINER Size Top 4.500 9640 Tubing String - TUBING Size Top 3.500 0 Well Type: ] INJ Orig 5/26/98 Completion: Last W/O: Last Tag Date: Last Update: 6/14/98 PBTD: 10170 ftKB TD: 10170 ftKB MaXAnqle:HOle 57 deg @ 6493 Angle @ TS: 54 deg @ 9566 Angle @ TD: 152 deg @ 10170 BottOm TVD Wt I Grade Thread 121 121 62.50 H-40 WELDED Bottom TVD VVt Grade Thread 5560 4150 29.70 L-80 ABM-BTC BoEom 964O Bottom 10169 Boffom 965O Perforations IntervalI TVD I Zone 9754- 9778 6615- 6629 A-3 9792- 9862 6638- 6680 ^-2 Gas Lift Mandrels/Valves I VIv Mfr Type Stn MD TVD Man Mfr Man Type BST Vlv 3.5 X BST DV I 9546 6489 1 AXT TVD I Wt Grade Thread 6546 15.50 L-80 LTC TVD Wt Grade Thread 6867 12.70 L-80 EUE TVD Wt Grade Thread 6552 9.30 L-80 EUE 8P, D Feet SPF Date TYpe Comment 24 4 5/24/98 2 1/8" ENERJET, DP 70 4 5/24/98 2 1/8" ENERJET, DP VlvOD Latch Port TRO Date Run 1.0 To1 0.000 0 5/24/98 Other (plugs, equip., etc.) - JEWELRY Depth 'I'VD Type 5271 5271 NIPPLE 96051 65251 NIPPLE 96401 65461 PBR 9650 6552 PKR 10170 10170 FLOAT SHOE Description ID CAMCO DS W/2.813 NG 2.813 CAMCO D NIPPLE 2.75" NG 2.750 Baker 5X4 PBR and Locator 2.992 BAKER GBH-22 SEAL ASSEMBLY W/15' SEALS AND 2.992 LOCATOR 3.958 General Notes Date 5/24/98 Note TBG AND ANNULUS FREEZE PROTECTED WI2000' DIESEL CAP. 7 5/8" X 5 1/2" ANNULS HAS NOT BEEN ARCTIC PACKED. DO NOT BLEED OFF. 5/24/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrle NO. 11392 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 8/3/98 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia LIS Tape 1A-23 TDTP/WFL 980308 I 1 1 L-13 PRODUCTION PRORLE 980701 I 1 1 L-17 ~,t ~ INJECTION PROFILE 980630 I 1 1 R-16 GAS LIFT SURVEY 980602 I 1 1Y-08 U~l C.._- WATER INJECTION PROFILE 980602 I 1 2 A- 24 PRODUCTION PROFILE 980619 1 1 2F-10 GAS LIFT SURVEY 980720 I 1 2T-36 il~ tvL~ ~- INJECTION PRORLE 980629 I 1 2X-14 PRODUCTION PROFILE 980601 I 1 2 X- 15 PRODUCTION PRORLE 980611 I 1 3 F- 15 INJECTION PROFILE 980720 I 1 3 F- 1 a GAS LIFT SURVEY 980703 I 1 3G-25X STATIC PRESSURE SURVEY 980607 1 1 3 K- 14 GAS LIFT SURVEY 980604 I 1 3K-25 i~[.I (_.. CEMENT MAPPING TOOL 980606 I 1 3K-31 CEMENT BOND LOG 980701 I 1 ;3K-31 STATIC BOTTOM HOLE 980715 I 1 3K-34 ~.~I ~ CEMENT BOND LOG 980623 I 1 3 K-34 STATIC PRESSURE/TEMP 980624 1 1 , , 3 O-04 GAS LIFT SURVEY 980612 1 I SIGNED: Please sign and return one copy of this transmittal to Sherrle at the above address. Thank you. DATE: AI lC'_ Anchorage WELL LOG TRANSMITTAL lro: State of Alaska July ,~-, 1998 Alaska Oil and Cras Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. -:- , ..-~ .-/ Anchorage, Alaska 99501 ?, RE: MWD Formation Evaluation Logs 3K-25. ~Mi-~MM-80229 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: .Mi Turker. Sperry-Sun Drilling Services, 5631 Silverado Way, #G. Anchorage, AK 99518 3K-25: 'DII 5I! ; x .MD Resistiviw & Gamma Ray Logs: 50-029-22881-00 2" x 5" TS.T) Resistivity & Gamma Ray Logs: 50-029-22881-00 1 Blueline 1 Folded Sepia 1 Blueline 1 FOlded Sepia 5631 Siiverado Way, Suite G · Anchorage. AlasKa 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. 0 !:t I I__1__ I I~ G S I::: I=t ~/I r' E S WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 8, 1998 3K-25, AK-MM-80229 1 LDWG formatted Disc with verification listing. API#: 50-029-22881-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETrER TO THE ATI'ENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. .anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company C! I:! I Ll--I N I~ c: ~ I:t~J I C ~ c: 26-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3K-25 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 10,170.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED PJ~,ka 0ii & Gu Cms, Commission An~or~e 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 7, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-25 (Permit No. 98-6.1.) Well Completion Report Dear Mr. Commissioner: Enclosed is a corrected well completion report for the completion on West Sak 3K-25. The location at bottomhole has been corrected. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kuparuk Drill Site Development GCA/skad ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 26, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3K-25 (Permit No. 98-61) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3K-25. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kuparuk Drill Site Development GCA/skad STATE OF ALASKA ' " ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~,,~e I¢'¢'~ ~JL 1 Status of Well Classification of Service Well OIL E~ GAS [~ SUSPENDED [~ ABANDONED~ SERVICE [~ Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-081 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22881 4 Location of well at surface:- : ~:: : :"_. - ?-'::~,':..,.;~ ..-7;::~;,,~'~-~' '~ i9 Unit or Lease Name '~ ~i"~I~T'IIC~ '~ Kuparuk River Unit At Top Producing Inte~al . . ~ ~ 10 Well Number At Total Depth ~ 11 Field and Pool 2595' FNL, 938' ~L, Sec. 26, T13N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease D~ignation and Sedal No. Kuparuk River Oil Pool Rig RKB 41', Pad 34' ADL25519 ALK2555 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 16 No. of Completions 13-May-98 23-May-98 25-May-98 NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of pe~afrost 10170' MD & 6868' ~D 10104' MD & 6827' ~D YES ~ NO ~ N/A feet MD 1556' APPROX 22 Type Electric or Other Legs Run GR/Res, CBL 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 151.53~ X-65 SURF. 121' 30' 3.5 cu. Yds 7.625" 29.7¢ L-80 SURF. 5560' 9.875" 364 sx DLW, 500 sx Cla~ G 5.5" 15.5¢/ L-80 SURF. 9640' 6.75" 310 sx Class G 4.5' 12.8~ L-80 9640' 10170' 6.75' (included above) 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9652' 9754'-9778' MD 6615'-6630' TVD 9792'-9862' MD 6638'-6680' ~D 26 ACID, FRACTURE, CEMEh 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9754'-9778', 9792'-9862' 8891¢ of 20/40 proppant, 3780¢ of diveder ~27 PRODUCTION TEST Date First Production Method of OperatiOnlnjector(FIowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FO OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE [ GAS-OIL RATIO I TEST PERIOI: Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Bdef description of lithology, porosity, fractures, apparent dips and pr~ence of oil, gas or water. Submit core chips. Form 10-407 Submit in duplicate Rev. ?-]-80 CONTINUED ON i~EVEPSE SIDE 29. 30. ~l/ GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, vlEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 9566' 6495' Bottom Kuparuk C 9619' 6526' Top Kuparuk A 9726' 6588' Bottom Kuparuk A 9937' 6710' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey 32, I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed/~~,..~ ~ Title ~/"~r~"~.~,~.~4-~'~ DATE Prepared by Mame/Number Sharon Allsup-DraE~/263-4612 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 Date: 6/18/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:3K-25 WELL_ID: AK9309 TYPE: AFC: AK9309 STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:05/13/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0%~ SECURITY:0 API NUMBER: 50-029-22881-00 05/12/98 (D1) TD: 121' (121) SUPV:DCL MW: 0.0 VISC: 0 PV/YP: 0/ 0 Clean out conductor (ice) Move rig 251' to 3K-25. NU diverter. APIWL: 0.0 05/13/98 (D2) TD: 1928'(1807) SUPV:DCL MW: 9.0 VISC: 145 PV/YP: 28/47 Drilling APIWL: 8.2 Accept rig 5/12/98 @ 2200 hrs. NU diverter and function test. Clean out conductor from 45' to 121'. Packed off flow line w/gravel. Clean out gravel. Drilling from 121' to 1928' 05/14/98 (D3) TD: 5243' (3315) SUPV: DCL MW: 9.4 VISC: 88 PV/YP: 26/34 Circ and cond mud after wiper trip Drilling from 1928' to 5243' APIWL: 7.2 05/15/98 (D4) TD: 5570'(327) SUPV:DCL MW: 9.5 VISC: 52 PV/YP: 17/12 APIWL: 8.8 NU BOPE Drill f/5243 t/5570' at 2300' POH. Minor swabbing and hole drag 05/16/98 (D5) TD: 5570'( SUPV:DCL 0) MW: 8.7 VISC: 44 PV/YP: 6/28 POH F/BHA CHANGE. APIWL: 20.0 Test BOPE to 300/3000 psi. Attempt to test csg. Plug leaking. Test csg to 2000 psi. Tag cement stringer at 5164' Drill out cement to 5421' 05/17/98 (D6) TD: 6088' (518) SUPV:DCL MW: 0.0 VISC: 44 PV/YP: 0/ 0 DRILLING. APIWL: 0.0 Drill f/5570 t/6088' Attempt survey w/no success. POH. Shallow test MWD. RIH to shoe. Fill pipe, take survey. 05/18/98 (D7) TD: 8835' (2747) SUPV:DCL/DB 05/19/98 (DS) TD: 9421' (586) SUPV:DCL MW: 10.2 VISC: 63 PV/YP: 27/29 Perform OH LOT APIWL: 4.5 Drilling from 6088' to 8835' MW: 11.5 VISC: 64 PV/YP: 31/28 CBU. MW 12.0 ppg APIWL: 3.8 Drilling from 8835' to 9120' Perform OH LOT, 10.2 MW. Drilling from 9120' to 9421'. Gas and oil cut mud to surface. Add fine barofiber and increase mud to 11.4. Continue to have small flow and gas and oil influx. No mud loss to formation. 05/20/98 (D9) TD: 9421'( SUPV:DCL o) MW: 12.2 VISC: 66 PV/YP: 36/31 RIH w/ rotary BHA APIWL: 4.2 Increase MW to 11.7 ppg. Monitor well. Flow back 1 gpm. CBU. Gas and oil cut mud to 9.7 ppg. Increase MW to 12.0 ppg. No flow. CBU. No gas cut mud. Short trip 10 stds. No problems. CBU. Perform OH FIT, 13 ppg EMW at TD. Increase MW to 12.2 ppg. 05/21/98 (D10) TD: 9565' (144) SUPV:DCL MW: 12.0 VISC: 60 PV/YP: 29/22 Drilling at 9701' APIWL: 4.2 RIH, break circ several times, Work through small bridges at 8633', 8972' and 9286'. Reduce MW to 12.0 ppg, add 3 ppb fine baroseal. No losses. Drilling from 9421' to 9565' 05/22/98 (Dll) TD: 9565' ( 0) SUPV:DCL MW: 12.0 VISC: 59 PV/YP: 27/22 INCREASE MW - 12.2 PPG. APIWL: 4.5 DRILL F/9565 T/10070' DRIVE SERVICE LOOP. REPAIR ELECTRICAL SHORT IN TOP 05/23/98 (D12) TD:10170'(605) SUPV:DCL MW: 12.2 VISC: 64 PV/YP: 34/27 RIH W/5.5" CSG. DRILL F/10070 T/10170' TIGHT SPOT @ 9400' APIWL: 4.6 05/24/98 (D13) TD:10170' ( 0) SUPV:DCL MW: 12.2 VISC: 58 PV/YP: 32/22 RIH W/3.5" COMPLETION EQUIPMENT. APIWL: 4.4 PJSM. RIH W/4.5" AND 5.5" CSG T/3564' T/8700' CIRC 60 BBLS. NO LOSS. RIH W/5.5" CSG 05/25/98 (D14) TD:10170' ( 0) SUPV:DCL MOVE RIG. MW: 12.2 VISC: 64 PV/YP: 33/28 APIWL: 4.5 PJSM. TEST ALL BREAKS T/3000 PSI. TEST CSG,TBG & ANNULUS T/3500 PSI, OK. INSTALL BPV. ND BOPE. 05/26/98 (D15) TD:10170' ( 0) SUPV:DEB MW: 0.0 VISC: Rig Released 0 PV/YP: 0/ 0 APIWL: 0.0 Freeze protect annulus. Release rig @ 0600 hrs. 5/26/98 ARCO'Alaska, Inc. KUPARUK RIVER UNIT '- ELL SERVICE REPORT K1(3K-25(W4-6)) WELL JOB SCOPE JOB NUMBER 3K-25 HPBD, HPBD SUPPORT 0531980729.5 DATE UNIT NUMBER 06/14/98 DAY KEY PERSON 1 DALLY WORK PUMP "A" SAND HPBD OPERATION COMPLETE I SUCCESSFUL ~ YesO "oI ® © "O Initial Tbg Press lFinal Tbg Press I Initial Inner Ann 380 PSI J 1588 PSII 545 PSI Final Inner Ann I 545 PSI ! SUPERVISOR SCHWENDERMAN Initial Outer Ann I Final Outer Ann 350 PSI! 350 PSI DALLY SUMMARY PUMPED "A" SAND HPBD MAXIMUM PRESSURE 8545 PSI. PUMPED TOTAL 8891 LBS OF 20/40 PROPPANT, 3780 LBS OF I DIVERTER. FINAL TUBING PRESSURE 5012 PSI @ 40 BPM. I TIME LOG ENTRY 07:00 MIRU DS FRAC UNIT (YOAKUM / LRS / APO) TGSM HIGH PRESSURE LINES. SET TREE SAVER AND RIG UP SURFACE LINES AND EQUIPMENT. 10:00 PT BACKSIDE AND LINES TO 4000 PSI, OK. PTTO 10,800 PSI, OK. PRESSURE UP ANNULAS TO 3500 PSI. 10:16 PUMPED STAGE #1 BREAKDOWN WITH J-313 SW , 40 BPM TBG PRESSURE AT 8545 PSI. 1PPA PROPPANT AT 40 BPM/5433 PSI. FINAL 40 BPM/5182 PSI. SD OBTAIN ISIP OF 1355 PSI. 10:37 PUMPED STAGE #2 DIVERSION/HPBD/SCOUR, 2 PPG ROCK SALT& GELLED DIESEL/SPACERS@7 BPM & FLU~ @ 3O BPM 10:45 FIRST AND SECOND SLUG ON PERFS NO INDICATIONS. FINAL FLUSH PRESSURE AT 40 BPM 4784 PSI. SD AND OBTAIN ISIP OF 1538 PSI. IA STABLE. 10:58 PUMPED STAGE #3 DIVERSION/HPBD/SCOUR, 2 PPG ROCK SALT & GELLED DIESEL/SPACERS @ 7 BPM. SW J313. IA STABLE AT 3495 PSI. 11:17 FIRST AND SECOND SLUG ON PERFS HAD PRESSURE INCREASE TO 5457 PSI. FLUSH PRESSURE AT 40 BPM 4797 PSI. SD OBTAIN ISIP OF 2444 PSI. 12:30 RDMO DS. NOTIFIED DSO WELL READY FOR INJECTION. ARCO 'Alaska, Inc. DAY 3 WELL JOB SCOPE 3K-25 PERFORATE, PERF SUPPORT DATE DALLY WORK 06/09/98 PERFORATE A2 & A3 SANDS KEY PERSON SWS-BARTZ KUPARUK RIVER UNIT 'wELL SERVICE REPORT K1(3K-25(W4-6)) IJOB NUMBER '0531980731.6 --UNIT NUMBER 2128 SUPERVISOR JONES OPERATION COMPLETE I SUCCESSFUL O Yes~) No I ® Yes © No Initial Tbg Press ~Final Tbg Press I Initial Inner Ann OPSlI 5oPslI OPSl Final Inner Ann I OPSI I Initial Outer Ann I 32O PSI I Final Outer Ann 320 PSI DAILY SUMMARY I~~~PERF~RATEDA3FR~M9754~T~9778~&A2FR~M9792~T~9862~~N4RUN~W/21/8~~EJ~4~PF~DP~~PHA~ED~~DEG~R~ENT~ TESTEDBOP'STO4500#. TIME LOG ENTRY 08:30 SWS (BARTZ & CREW) MIRU, HELD TGSM. RU BOP'S & TEST TO 4500#. (WAITED 30 MIN FOR TRIPLEX). 10:30 SECURED RADIO SILENCE. MU GUN & PT LUB TO 3000#. 11:45 MIH W/30' 2 1/8" E J, 4 SPF, DP, 0 PHASED & 0 DEG ORIENT. CORR TO SWS CMT LOG 6-6-98. PRESS TBG TO 300# & PERFED FROM 9832' TO 9862'. 14:15 POH & LD GUNS, ALL SHOTS FIRED. 15:30 MU GUN & PT LUB TO 3000#. 16:15 MIH W/24' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERF FROM 9754' TO 9778'. 17:15 POH & LD GUN, ALL SHOTS FIRED. 18:00 MU GUN & PT LUB TO 3000#. 19:00 MIH W/30' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 9802' TO 9832'. 20:30 POH & LD GUN, ALL SHOTS FIRED. 21:30 MU GUN & PT LUB TO 3000#. 22:15 MIH W/10' EJ GUN AS ABOVE, CORR TO ABOVE LOG & PERFED FROM 9792' TO 9802'. 23:30 POH & LD GUN, ALL SHOTS FIRED. RIGGED DOWN & RELEASED SWS @ 01:00AM.- NOTE, DID NOT DO A STATIC BHP SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-97729 Sidetrack No. Page I of 3 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO- #245 Field KUPARUK RIVER UNIT [114~ -=1 ~/'-~ Well Name & No. 3K PAD/3K-#25 Survey Section Name SPERRY SUN BHI Rep. WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S 1297.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. ENV Slot Coord. ENV 317.00 Magn. Declination 27.600 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft~ 30m~ 1Om0 Vert. Sec. Azim. 4.00 Magn. to Map Corr. 27.600 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (F'r) (FT) (Per 100 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 13-MAY-98 MWD 121.00 0.00 0.00 121.00 121.00 0.00 0.00 0.00 0.00 0.00 8"MACH 1C-AKO-1.4deg. 13-MAY-98 MWD 179.00 0.25 192.00 58.00 179.00 -0.13 -0.12 -0.03 0.43 0.43 *S/S GYRO* 13-MAY-98 MWD 268.00 0.27 206.00 89.00 268.00 -0.51 -0.50 -0.16 0.07 0.02 , 13-MAY-98 MWD 374.97 0.45 267.66 106.97 374.97 -0.79 -0.75 -0.69 0.37 0.17 13-MAY-98 MWD 465.94 1.92 297.10 90.97 465.92 -0.23 -0.07 -2.40 1.70 1.62 13-MAY-98 MWD 556.74 3.31 280.36 90.80 556.62 0.65 1.10 -6.34 1.73 1.53 13-MAY-98 MWD 648.20 5.09 289.69 91.46 647.83 2.04 2.94 -12.75 2.08 1.95 10.20 13-MAY-98 MWD 736.60 7.37 279.41 88.40 735.71 3.64 5.19 -22.04 2.86 2.58 -11.63 13- MAY-98 MWD 827.40 9.95 287.61 90.80 825.47 6.03 8.51 -35.27 3.14 2.84 9.03 13-MAY-98 MWD 916.55 13.04 285.58 89.15 912.82 9.87 13.55 -52.30 3.50 3.47 -2.28 13-MAY-98 MWD 1009.39 16.52 277.97 92.84 1002.58 12.88 18.19 -75.47 4.28 3.75 -8.20 13-MAY-98 MWD 1100.07 15.81 289.94 90.68 1089.70 17.17 24.19 -99.86 3.75 -0.78 13.20 13-MAY-98 MWD 1191.44 15.23 303.59 91.37 1177.77 26.52 35.08 -121.56 4.04 -0.63 14.94 , , 13-MAY-98 MWD 1285.43 14.91 310.86 93.99 1268.53 39.87 49.83 -140.99 2.04 -0.34 7.73 13-MAY-98 MWD 1381.58 15.52 320.09 96.15 1361.33 56.56 67.79 -158.60 2.60 0.63 9.60 13- MAY-98 MWD 1477.16 15.96 324.38 95.58 1453.33 75.89 88.28 -174.46 1.30 0.46 4.49 13-MAY-98 MWD 1571.39 17.33 332.37 94.23 1543.62 97.83 111.25 -188.52 2.83 1.45 8.48 13-MAY-98 MWD 1664.29 18.22 340.11 92.90 1632.09 122.89 137.17 -199.88 2.72 0.96 8.33 13- MAY-98 MWD 1759.10 20.07 346.62 94.81 1721.67 151.97 166.94 -208.69 2.98 1.95 6.87 13- MAY-98 MWD 1853.46 22.99 355.40 94.36 1809.46 185.66 201.07 -213.91 4.60 3.09 9.30 14-MAY-98 MWD 1948.45 26.59 359.29 94.99 1895.68 225.21 240.84 -215.67 4.16 3.79 4.10 14-MAY-98 MWD 2042.51 29.32 1.31 94.06 1978.76 269.20 284.92 -215.40 3.07 2.90 2.15 -- 14-MAY-98 MWDI 2138.22 31.78 ~.95 95.71 2061.18 317.81 333.52 -213.57 2.71 2.57 1.71 ~ ~ ' ' ~- , , , Fi ii i i i i i i ii ii i i · ' '" SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0450-97729 Sidetrack No.Page2 of 3 · _' [lJ:~,' I :~1 Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO - #245 Field KUPARUK RIVER UNIT / Well Name & No. 3K PAD/3K-#25 Survey Section Name SPERRY SUN BHI Rep. J~N'TL~ WELL DATA Target'l'VD (FT) Target Coord. N/S Slot Coord. N/S 1297.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 317,00 Magn. Declination 27,600 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m0 10m~ Vert, Sec, Azim. 4.00 Magn. to Map Corr. 27,600 Map North to: OTHER i i SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 Fl'}Drop (-) Left (-) 14-MAY-98 MWD 2233,43 33.84 0.98 95.21 2141,20 369.36 385.08 -211.82 2.44 2.16 -2,07 8"MACH 1C-AKO-1.4 DEG. 14-MAY-98 MWD 2328.85 36.73 0.81 95.42 2219,08 424.39 440,18 -210,97 3,03 3.03 -0.18 14-MAY-98 MWD 2423.24 40.22 0.97 94.39 2292,97 483.03 498,89 -210,05 3,70 3,70 0,17 14-MAY-98 MWD 2518,43 43.26 1.45 95,19 2363,99 546,32 562,24 -208.70 3.21 3.19 0.50 14-MAY-98 MWD 2613,29 45,75 0.57 94,86 2431,64 612,71 628,72 -207,54 2,70 2.62 -0,93 14-MAY-98 MWD 2707,97 49,36 1,25 94,68 2495,52 682.47 698,57 -206,42 3,85 3,81 0,72 14-MAY-98 MWD 2803,37 52,15 1.57 95,40 2555,87 756,27 772,42 -204.60 2,94 2,92 0,34 14-MAY-98 MWD 2897,42 55.18 3,05 94,05 2611.59 831,98 848.11 -201.53 3,46 3,22 1,57 14-MAY-98 MWD 2990.77 56.16 3,56 93,35 2664,24 909.07 925,07 -197.08 1,14 1.05 0,55 14-MAY-98 MWD 3279.18 55,16 3,42 288,41 2826,93 1147,20 1162,76 -182,58 0,35 -0,35 -0.05 14-MAY-98 MWD 3563.06 54,47 6.28 283,88 2990,53 1379,14 1393.91 -162,99 0.86 -0,24 1,01 14-MAY-98 MWD 3847,28 56.01 8,59 284.22 3152.58 1612,19 1625.41 -132.74 0,86 0,54 0,81 ., 14-MAY-98 MWD 4130,46 54,90 8,43 283,18 3313,16 1844,71 1856,08 -98,22 0,39 -0,39 -0,06 Ii' 14-MAY-98 MWD 4415,73 53.41 8,52 285,27 3480,21 2075.24 2084,79 -64,14 0,52 -0,52 0.03 '~ 14-MAY-98 MWD 4699,14 55,72 8,29 283,41 3644,51 2305,46 2313,21 -30,40 0,82 0.82 -0,08 14-MAY-98 MWD 4978,33 53.20 6.91 279.19 3806,79 2532,16 2538,36 -0.32 0,99 -0,90 -0,49 15-MAY-98 MWD 5264.36 54,51 7,08 286,03 3975,49 2762,82 2767.62 27.82 0,46 0.46 0.06 15- MAY-98 MWD 5492.33 52,91 5,87 227,97 4110,42 2946.38 2950.18 48.55 0,82 -0,70 -0,53 18-MAY-98 MWD 5925,62 55,75 6,69 433,29 4363,06 ,3298,06 3300,02 87,10 0,67 0.66 .0,19 4 3/4"MACH 1XL-AKO-1,2 DEG.W/S 18-MAY-98 MWD 6210.65 54.74 8.02 285,03 4525.55 3531,83 3532,27 117.06 0,52 -0.35 0,47 18-MAY-98 MWD 6493.30 57.14 6.40 282,65 4683,84 3765.60 3764,55 146,40 0,97 0.85 -0,57 18-MAY-98 MWD 6778,29 54,80 7,62 284,99 4843,32 4001,43 3998,95 175,19 0,89 -0,82 0,43 · , 18-MAY-98 MWD 7063,24 52,11 7,25 284,95 5012.98 4229,92 4225.93 204,82 0.95 -0.94 -0,13 1B-MAY-g~ MWD 734(~.§1 54.92 ~,73 ~83.~7 5182.85 4456.87 4451.64 230.45 0.89 0.78 -0.54 i ii iiii iii i i ii i iii "-rlllllllll I I I ! i I I ii i i -- --~--~ltl_rt-);I Company ARCO ALASKA, INC. Rig Contractor & No. PARKER DRILLING,CO - #245 Field KUPARUK RIVER UNIT II Well Name & No. 3K PAD/3K-#25 Survey Section Name SPERRY SUN BHI Rep. ~jllll~r~~ WELL DATA Target TVD (FO Target Coord. N/S Slot Coord. N/S 1297.00 Grid Correction 0.000 Depths Measured From: RKB ~ MSLC[ SSC~ Target Description Target Coord. ENV Slot Coord. E/W 317.00 Magn. Declination 27,600 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mC~ 10m~ Vert. Sec. Azim. 4,00 Magn. to Map Corr. 27,600 Map North to: OTHER SURVEY DATA . Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FO (DO) (DD) (ET) (FT) (FT) (FO Per 100 FT) Drop (-) Left (-) _ 18-MAY-98 MWD 7630.89 52.54 7.34 283.98 5352.04 4684.70 4678.22 256.37 0.77 -0.63 0.57 4 3/4"MACH 1XL-AKO-1.2 DEG.W/S · 18- MAY-98 MWD 7914.55 54.31 6.12 283.66 5521.07 4912,23 4904.43 283.04 0.71 0.62 -0.43 18-MAY-98 MWD 8196.96 52.14 6.75 282.41 ' 5690.13 5138,22 5129.20 308.37 0.79 -0.77 0.22 18-MAY-98 MWD 8480.52 53.18 6.17 283.56 5862.12 5363.45 5353.21 333.73 0.40 0.37 -0.20 18-MAY-98 MWD 8766.24 53.83 6.05 285.72 6032.05 5592.99 5581.60 358.17 0.23 0.23 -0.04 19-MAY-98 MWD 9047.20 54.50 5.38 280.96 6196.54 5820.66 5808.24 380.85 0.31 0.24 -0.24 19-MAY-98 MWD 9241.25 55.63 5,33 194.05 6307.66 5979.69 5966,63 395.69 0.58 0.58 -0.03 20-MAY-98 MWD 9333.97 54.63 6.57 92.72 6360,67 6055,72 6042.29 403.58 1.54 -1.08 1,34 24-MAY-98 MWD 10098.00 51,50 28.60 764.03 6823.35 6643.50 6618.90 583.79 2.34 -0.41 2.88 ROTARY ASSEMBLY SINGLE SHOT 24-MAY-98 MWD 10170,00 51.50 28.60 72.00 6868.18 6694.73 6668.37 610.76 0.00 0.00 0.00 CLO.DIST=6696.29AZI=5.23 ,.~. __ i ~iiiiii i I iii iiii i i i i ii lB i I i iii i 11 , ii i iiiii i iiiiiii ii Kuparuk Unit Kuparuk 3K 3K-25 SURVEY REPORT 26 June, 1998 Your Ref: API-500292288100 Last Survey Date 23.May.98 Job# AKMMS0229 KBE- 75.30' Sperry-Sun Drilling Services Survey Report for 3K-25 Your Ref: AP1-500292288100 Kuparuk Unit Measured Depth (ft) Incl. 0.00 121.00 179.00 268.00 374.97 465.94 556.74 648.2O 736.60 827.40 916.55 1009.39 1100.07 1191.44 1285.43 1381.58 1477.16 1571.39 1664.29 1759.10 1853.46 1948.45 2042.51 2138.22 2233.43 2328.85 2423.24 2518.43 2613.29 2707.97 0.000 0.000 0.250 0.270 0.450 1.920 3.310 5.090 7.370 9.950 13.040 16.520 15.810 15.230 14.910 15.520 15,960 17.330 18.220 20.070 22.990 26.590 29,320 31.780 33.840 36.730 40.22O 43.260 45.750 49.360 0.000 0.000 192.000 206.000 267.660 297.100 280.360 289.690 279.410 287.610 285.580 277.970 289.940 303.590 310.860 320.090 324.380 332,370 340.110 346.620 355.400 359.290 1.310 2.950 0.980 0.810 0.970 1.450 0.570 1.250 Sub-Sea Depth -75.30 45.70 103.70 192.70 299.67 390.62 481.32 572.53 660.41 750.17 837.52 927.28 1014.40 1102.47 1193.23 1'286.03 1378.03 1468.32 1556.79 1646.37 1734.16 1820.38 1903.46 1985.88 2065.90 2143.78 2217.67 2288.69 2356.34 2420.22 Vertical Depth (ft) 0.00 121.00 179.00 268.00 374.97 465.92 556,62 647.83 735.71 825.47 912.82 1002.58 1089.70 1177.77 1268.53 1361.33 1453.33 1543.62 1632.09 1721.67 1809.46 1895.68 1978.76 2061.18 2141.20 2219.08 2292.97 2363.99 2431.64 2495.52 / Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (o/looft) (ft) 0.00 N 0.00 E 6008291.50 N 529306.13 E 0.00 0.00 N 0.00 E 6008291.50 N 529306.13 E 0.000 0.00 0.12 S 0.03W 6008291.38 N 529306.10 E 0.431 -0.13 0.50 S 0.16W 6008291.00 N 529305.97 E 0.075 -0.51 0.75 $ 0.69W 6008290.75 N 529305.44 E 0.374 -0.79 0.07 S 2.40W 6008291.42 N 529303.73 E 1.697 -0.23 1.10 N 6.34W 6008292.57 N 529299.79 E 1.731 0.65 2.94 N 12.75W 6008294.39 N 529293.37 E 2.078 2.04 5.19 N 22.04W 6008296.60 N 529284.07 E 2.861 3.64 8.51 N 35.27W 6008299.88 N 529270.83 E 3.143 6.03 13.55 N 52,30W 6008304.84 N 529253.78 E 3.495 9.87 18.19 N 75.47W 6008309.40 N 529230.59 E 4.285 12.88 24.19 N 99.86W 6008315.30 N 529206.18 E 3.751 17.17 35.08 N 121.56W 6008326.11 N 529184.43 E 4.038 26.52 49.83 N 140.99W 6008340.77 N 529164.94 E 2.038 39.87 67.79 N 158.60W 6008358.66 N 529147.26 E 2.595 56.56 88.28 N 174.46W 6008379.09 N 529131.32 E 1.301 75.89 111.25 N 188.52W 6008402.01N 529117.18 E 2.827 97.83 137.17 N 199.88W 6008427.88 N 529105.71E 2.716 122.89 166.94 N 208.69W 6008457.62 N 529096.79 E 2.977 151.97 201.07 N 213.91W 6008491.73 N 529091.43 E 4.601 185.66 240.84 N 215.67W 6008531.49 N 529089.52 E 4.159 225.21 284.92 N 215.40W 6008575.57 N 529089.61 E 3.072 269.20 333.52 N 213.57W 6008624.18 N 529091.25 E 2.714 317.81 385.08 N 211.82W 6008675.74 N 529092.80 E 2.437 369.36 440.18 N 210.96W 6008730.85 N 529093.44 E 3.030 424.39 498.89 N 210.05W 6008789.56 N 529094.12 E 3.699 483.03 562.24 N 208.70W 6008852.92 N 529095.22 E 3.211 546.32 628.72 N 207.54W 6008919.40 N 529096.12 E 2.704 612.71 698,57 N 206.42W 6008989.25 N 529096.97 E 3.549 682.47 Comment 26Jun~ 1998-3:06 -2- Sperry-Sun Drilling Services Survey Report for 3K-25 Your Ref: A PI-5002922881 O0 Kuparuk Unit Measured Depth (ft) Incl. 2803.37 2897,42 2990.77 3279.18 3563.06 3847.28 4130.46 4415,73 4699.14 4978.33 5264.36 5492.33 5925.62 6210.65 6493.30 6778.29 7063.24 7346.91 7630.89 7914.55 8196.96 8480.52 8766.24 9047.20 9241.25 :9333.97 ~10098.00 10170.00 52.150 55.180 56.160 55.160 54.470 56.010 54.9O0 53.410 55.720 53.200 54.510 52.910 55.750 54.740 57.140 54.800 52.110 54.320 52.540 54,310 52.140 53.180 53.83O 54.50O 55.630 54.630 51.60O 51.600 Azim. 1.570 3.050 3.560 3.420 6.280 8.590 8.430 8.520 8.290 6,910 7.080 5.87O 6.690 8.020 6.400 7.620 7.250 5.730 7.340 6.120 6.750 6.170 6.050 5.380 5.330 6.570 28.6O0 28.600 Sub-Sea Depth (ft) 2480.57 2536.29 2588.94 2751.63 2915.23 3077.28 3237.86 3404.91 3569.21 3731.49 3900.19 4035.12 4287.76 4450.25 4608.54 4768.02 4937.68 5107.55 5276.74 5445.77 5614.83 5786.82 5956.75 6121.24 6232.36 6285.37 6747.53 6792.25 Vertical Depth (ft) 2555.87 2611.59 2664.24 2826.93 2990.53 3152.58 3313.16 3480.21 3644.51 3806.79 3975.49 4110.42 4363.06 4525.55 4683.84 4843.32 5012.98 5182.85 5352.04 5521.07 5690.13 5862.12 6032.05 6196.54 63O7.66 6360.67 6822,83 6867.55 Local Coordinates Global Coordinates Dogleg Vertical Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 772.42 N 204.60W 6009063,11N 529098.50 E 2.936 756.27 848.11N 201.53W 6009138.81 N 529101.27 E 3.462 831.98 925.07 N 197.08W 6009215,79 N 529105.42 E 1.143 909.07 1162.76 N 182.58W 6009453.54N 529118.98 E 0.349 1147.20 1393.91 N 162.99W 6009684.76 N 529137.66 E 0.858 1379.14 1625.41N 132.74W 6009916.37 N 529167.00 E 0.860 1612.19 1856.08 N 98.22W 6010147.18 N 529200.62 E 0.395 1844.71 2084.79 N 64.14VV 6010376.03 N 529233.79 E 0.523 2075.24 2313.21N 30.40W 6010604.58 N 529266.64 E 0.818 2305.46 2538.37 N 0.32W 6010829.84 N 529295.84 E 0.988 2532.16 2767,62 N 27.82 E 6011059.21N 529323,07 E 0.461 2762.82 2950,18 N 48.56 E 6011241.85 N 529343.09 E 0.822 2946.38 3300.02 N 87.10 E 6011591.84 N 529380,26 E 0.673 3298.06 3532.27 N 117.06 E 6011824.20 N 529409.31 E 0.522 3531.83 3764.55 N 146.40 E 6012056.60 N 529437.74 E 0.973 3765.60 3998.95 N 175.19 E 6012291.11 N 529465.60 E 0.894 4001.43 4225.93 N 204.82 E 6012518,20 N 529494.34 E 0.950 4229.92 4451.64 N 230.45 E 6012744.01N 529519.09 E 0.889 4456.87 4678.22 N 256.37 E 6012970.69 N 529544.12 E 0.775 4684.70 4904.43 N 283.04 E 6013197.01 N 529569.90 E 0.713 4912.23 5129.20 N 308,37 E 6013421.88 N 529594.35 E 0.789 5138.22 5353.21 N 333.73 E 6013645.98 N 529618.82 E 0,401 5363.45 5581.60 N 358.17 E 6013874.46 N 529642,37 E 0.230 5592.99 5808.24 N 380.85 E 6014101.19 N 529664.16 E 0.307 5820.66 5966.63 N 395.70 E 6014259.64 N 529678.38 E 0.583 5979.69 6042.29 N 403.58 E 6014335.33 N 529685.96 E 1.539 6055.72 6619.27 N 583.99 E 6014913.01N 529864.11E 2.334 6643.88 6668.81N 611.00 E 6014962.66 N 529890.92 E 0.000 6695.18 Comment Projected Survey -3- 26 June, f998 - 3:06 Sperry-Sun Drilling Services Survey Report for 3K-25 Your Ref: AP1-5002922881 O0 Kuparuk Unit All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 4.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 10170.00ft., The Bottom Hole Displacement is 6696.74ft., in the Direction of 5.235° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 0.00 0.00 0.00 N 0.00 E Tie-in Survey at Surface 10170.00 6867.55 6668.81 N 611.00 E Projected Survey 26 June, 1998 - 3:06 - 4 - ARCO Alaska, Inc. Kuparuk Drillsite Development Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 265-6206 Michael Zanghi Supervisor June 3, 1997 Mr. Blair Wondzell, PE Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: KRU 3K-25 Influx Weight Up Dear Mr. Wondzell: During the drilling of KRU well 3K-25, a fluid influx occurred prior to drilling into the Kuparuk reservoir which required weighting up the mud system from an initial weight of 10.2 ppg to a final weight of 12.2 ppg over a period of 24 hours. The weight up was made in 0.3 ppg increments and at no time was the well required to be shut in. Following is a short synopsis of the events surrounding the weight up: 05/19/98 00:00 - 14:00 14:00 - 24:00 Drilling to 9421' MD; no problems; MW-10.2 ppg Gas cut oil and mud to surface. CBU. Cont'd to have gas and oil influx after bottoms up. Add 10 ppb fine barofiber and increase MW from 10.2 ppg to 11.4 ppg in 0.3 ppg increments. Reduced pump rate from 300 gpm to 215 gpm during weight up's. Check flow and CBU after each increment. Cont'd to have slight flow (< 2 gpm) and gas and oil influx. No mud loss to formation. O5/2O/98 00:00 - 02:30 02:30 - 07:00 07:00 - 09:00 09:00 - 11:00 11:00 - 13:30 Increase MW to 11.7 ppg. Monitor well. Flow back at 1 gpm Increase MW to 12.0 ppg. No flow. CBU. No gas cut mud. Short trip 10 stds. No problems. Perform OH FIT. 13.0 EMW at TD and 13.5 EMW at shoe Increase MW to 12.2 ppg for trip margin. Monitor well. SPR. Following the trip to change BHA, the well was drilled to TD through the Kuparuk reservoir and a 5- 1/2" x 4-1/2" tapered casing string run to bottom and cemented with no further problems. This well was planned as an injector and a cement bond Icg will be run prior to commencing injection operations. It is believed that the cause of the influx was a small, pressured fault occurring between the base of the HRZ and the K-1 markers. This fault was not seen on the initial seismic data, but was visible on the LWD GR/Resistivity Icg. If you have any questions or require further information, please contact Tom Brockway, Operations Drilling Engine.~r at (907) 263-4135 or Chip Alvord, Kuparuk Team leader at at (907) 265-6120. Since~-,C,A~,~ / ., Thomas A. Brockway Operations Drilling Engineer ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany & Gas Cons. Cc~mmissio~ Anchorage MEMORANDUM State of Alaska :Alaska Oil and Gas Conservation Commission TO: Blair Wondzell ~~ P.I. Supervisor ~/~ DATE: May 20, 1998 FROM: John Spaulding, ;Z~.,. SUBJECT: Petroleum Insp..~~ Influx While Drilling Well 3K-25 ARCO KRU - Parker Rig 245 Tuesday May 19, 1998: I received a call from ARCO company representative Donnie Lutrick informing me of the following items: · Drilling at 9,421' MD with 10,2ppg mud, · Drilled into a fault above the Kuparuk formation, · Influx was not detectable, minor amount of flow was noted, · Kept circulating while weighting up the mud, final mud weight to kill the well was 12 PPg. · At no time during the operation was the well shut in. · ARCO's engineering group feel that the fault was charged up by a nearby injection well. The injection well was shut in and changes were immediately noticed (flow decreased). I spoke to Donnie Lutrick 5-20-98 and he informed that the well was dead and that they would probably resume operations using 12.2 ppg mud; they would make any further corrections to the mud weight while drilling. ARCO Alaska, Inc. Post Office Bo,, . o0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 °8/ Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular Injection during the first quarter of ! 999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See No~ #l below 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 100 0 27607 0 27607 3K-23 15 0 0 15 0 15 3K-25 4202 100 0 4302 0 4302 1C-15 16695 100 0 16795 0 16795 2L-313 8554 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously re ~orted volume of 220 barrels was pumped into this annulus during tile drilling of the well. This was the volume required to jhtsh and freeze protect the annulus durin,g initial drilling operations, not a volume of disposalfluids injected prior to the receipt of authorization .[or annular injection. Total Volumes into Annuli for which Injection Authoriaation Expired during the quarter [ Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume i Injected Status of Annulus 1C-12 34995 100 0 ! 35095 Open, Freeze Protected 1C-13 26800 100 0 } 26900 Open, Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two Total Total h(1) Total h(2) Total h(3) Volume Current Status of Well Name Volume Volume Volume Injected Annulus 2A-22 16749 100 0 16849 Open, Freeze Protected 2F-19 20725 100 0 20825 Open, Freeze Protected 3K-27 37173 100 0 37273 Open, Freeze Protected 3K-26 33970 100 0 34070 Open, Freeze Protected 1E-31 33645 100 0 33745 Open, Freeze Protected 1E-32 45205 100 0 45305 Open, Freeze Protected 3Q-22 6245 100 0 6345 Open, Freeze Protected 1Q-24 23158 100 0 I 23258 Open, Freeze Protected 1 Q-26 ] 25931 100 0I 26031 , Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Ma.,,, 8, 1998 Chip Alvord Drilling Team Leader ARCO Alaska, Inc. P O 1OO36O Anchorage, AK 99510-0360 Re: Kuparuk River Unit 3K-25 ARCO Alaska, Inc. Permit No. 98-81 Sur. Loc. 1297'FSL. 317'FWL, Sec. 35, T13N, R9E, UM Btmhole Loc. 2569"FNL, 801'FWL, Sec. 26, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal of drilling waste will not be approved until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. A Formation Integrits.' Test (FIT) must confirm the adcquacv of cement behind surface casing. Cementing records, FIT data,, and any CQLs must be submittc~l to the Commission with an Application for Sundrs' Approvals (form 10-403) prior to initiating disposal operations. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christcnson Commissioner BY ORDER OF THE COMMISSION dlffEnclosttre cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation ;v/o encl. STATE OF ALASKA i ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Reddll E~ lb TypeofWell Exploratory ~' StratigraphicTest E~ Development Oil r,~ Re-Entry [-' Deepen [~ Service X Development Gas [~ Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 34' feet Kuparuk River FieLd 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25519, ALK 2555 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 1297' FSL, 317' FWL, Sec. 35, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2410' FSL, 764' FWL, Sec. 26, T13N, R9E, UM 3K-25 #U-630610 At total depth 9. Approximate spud date Amount 2569' FNL, 801' FWL, Sec. 26, T13N, R9E, UM 5/16/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3K-06 10160' MD 764' @ Target feet 12.4' @ 100' feet 2560 6829' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 500' feet Maximum hole angle 54.4° Maximum surface 2445 psig At total depth ('I'VD) 2901 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD -I-VD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 9.875" 7.625" 29.7# L-80 LTC 5501' 41' 41' 5542' 4144' 555 Sx Arcticset III & HF-ERW 341 Sx Class G & 60 sx AS I 6.75" 5.5" x 15.5#/ L-80 LTC MOD 10119' 41' 41' 10160' 6829' 4.5" 12.8# HF-ERW 247 Sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface Intermediate Production APR 2 0 1998 Perf°rati°~i;;;th: truemeasuredvertical 0 RIG IN A L 20. Attachments Filing fee X Property plat [~ BOP Sketch X Diverter Sketch X Dril~i~'¢~¢~='~~'a~- X Ddlling fluid program X Time vs depth plot F' Refraction analysis [~ Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed/~'~___ ~/~~ /~m~(, CI,'II 'P J/~L~,~ Title Drilling Team Leader Date ~/t '~ommission Use Only Permit N~n~,er ~./ I APlnumber 50- 0~..,~ ~_2_, ~:~,,/ JApprovaldate ~/,~'""~_. ¢~ See cover letter for -- -. I .,.~.e.r requirements Conditio~s~f approval Samples required F- Yes ~ No Mud log required [-' Yes ~ No Hydrogen sulfidemeasures ~ Yes F- No Directional surveyrequired ~ F- Y es No Required working pressure for BOPE 2M [~ 3M F 5M E~ 1OM [~ 15M l-- Other: ~ [.-'~ :. ORIGINAL SIGNED BY' by order of Approved by Ro~il~ N. O.h. dcf-..-.=.._ Commissioner the commission Date .......... Form 10-401 Rev. 7-24-89 Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 3K-25 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 9-7/8" hole to 7-5/8" surface casing point (+/- 5542') according to directional plan. 4. Run and cement 7-5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight I~.¢.~cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 14.0 ppg EMW. 7. Drill 6-3/4" hole to well total depth (+/- 10160') according to directional plan, running LWD logging equipment as needed. 8. Rig up and run E-line logs if needed. 9. Run and cement 5-1/2" x 4-1/2" tapered casing string with polished seal bore as part of XO. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 10. Pressure test 5-1/2" x 4-1/2" casing string to 3500 psi. 11. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 12. Nipple down BOPE. Install tubinghead, master valve, and upper tree assembly. 13. Shut in and secure well. 14. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. 3K-25 TAB,04/17/98, v.2 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 3K-25 Drillin.q Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin~ 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +/-10% Drill out to Weight Up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drill out to TD 11.0-11.5 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillinq Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,445 psi. Therefore, ARCO Alaska, Inc. will test BOP equipment to 3,000 psi. MASP = (4144 ft)(0.70 - 0.11)psi/ft = 2445 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 3K pad are expected to be 3600 psi (0.58 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 11.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6414'. Well Proximity Risks: The nearest existing well to 3K-25 is producer well 3K-06. As designed, the minimum distance between the two wells would be 12' at 100' MD. Prior to spud, 3K-06 will be shut in and the annular pressures bled to 0 psi. Drilling Area Risks: Risks in the 3K-25 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. If lost circulation cannot be controlled with LCM and a reduction of circulatiing pressure, 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out 4-3/4" hole and run a 3-1/2" liner to TD. Careful analysis of pressure data from offset wells shows that a mud weight of 11.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing permitted 3K Pad well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3K-25 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 3K-25 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are pad of the Colville Group and are known to provide Medical barriers to fluid flow. The surface casing shoes will be set +_200' vertical below the base of the West Sak into the head of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4086 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85%of Burst 85%of (in) (Ib~t) Grade Range Type (psi) Collapse (psi) Burst 7.625 29.7 L-80 3 BTC 4790 4071 6890 5856 5.500 15.5 L-80 3 LTC-M 4990 4241 7000 5950 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080.(.~(1). 3K-25 TAB, 4/16/98, v..1 A C,~oteO by ~,c, For: BROCKWAY OGre l~etted : 14-Apr-g8 Plot Reference [s 25 Version ~2. C~ord;notes ~re in feet re~erence slot True Ver[[col Depths ore re~erence R~ (Porker 5OO 500 lOOO 1500 2000 250O 3000 3500 4000 45O0 50Ge 5500 6000 65OO 7000 500 I'ARCO Alaskaw, Ind.1 I1:25 / Fiel~fTU;fuU;°er~kP;ivjKunif Locofion : Norfh Slope, AIOSEOI RKB ELEVATION: 75' 4. O0 AZIMUTH (tO ***Plone of Proposol*** KOP TVD=500 TMD=500 DEP=0 3.00 OLS: 3.00 deg per 100 ft 9.00 BEGIN BUILD/TURN TVD=994 TMD=IO00 DEP=-5 14.41 TD LOCATION: 2569' FNL, 801' FWL SEC. 26, T13N, RgE TARGET LOCATION: 2410' FSL, 764' FWL SEC. 26, T15N, RgE TARGET TVD=6613 TMD=9788 DEP=6409 NORTH 7690 EAST 764 700 0 700 TD Buse Kup SondS~ Top Unit D ~ K-1 Morker¢ 7 5/8 Casing~ Bo~e Wem Sok Sends 16.16 Tala West Sak Sends ~'19.61 B/ PERMAFROST TVD=1631 TMD=1664 DEP=95 DLS: 3.00 deg per 100 ft k .... X% 39.80 '%, 45.38 1 N%51.04EOC TVD=2`518 TMD=2919 DEP=829 T UGNU SNDS WD=2691 TMD=3044 OEP=931 Bose Permefrost~ t ~SURFACE LOCATION' ~ T/ ~ SAK SNDS TVD=3412 TMD=4284 OEP=l e38 I 1297' FSL, 317' FW'L ?: ~m~N~C_l ~ SEC 55 T13N RgE , 54.44 DEG '-... B/w s^~ SN~S wB=3944 TM~=Sl~9 ~EP=2681 542 DEP=2960 T/ D 1VD=6414 TMD=g446 DEP=6131 T/T/ C -I-VD=6504 IMD=9`500 DEP=6257 T/ B WD=6535 TMD=9654 DEP=6300 TD - CSG PT TVD=6829 TMD=10180 DEP=6711 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 0 500 1000 1.500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 Verficol Section (feet) -> Azimuth 4.00 wHh reference 0.00 N, 0.00 E from slot,//25 7OOO 6300 5600 4900 4200 3500 28OO f 2100 1400 f 700 7OO Z 0 m C,eoted ~y ~h For: BROCKWAY Date ~otted : 14-Apr-g~ Plot Reference [s 25 Version CoardMates are in feet reference slot ~25. True Vert;cal Depths ore reference RgB (Perker 28O 260 240 220 200 180 160 140 120 100 8o 4o 2O IAi CO Alaaka Structure : Pad 3K Il: 25 Field : Kuparuk River Unit Location : North Slope, AlaskaI <- West (feet) 240 220 200 180 160 140 120 1 O0 80 60 40 20 I I I I f I I I I I I I I I I I I I I 1 600 ' 1700 , 12OO 3400 15O0 1400 1600 ', , \,, '~, 1500 "., 1400 1300 1200 90O I I I I I 0 ~ 900 3300 8OO 700 30 600 5O0 2O 40 60 80 I I I I I I 1100 000 80( 7OO 3100 500 2300 2o ~ 40 ~ 5300 60 80 , , , , , , , , , 240 220 200 180 160 1100 2900 50C 800 2700 27OO 2600 2600 %, ",~ 1 -. "--.. 1200 2100 2200 - 52OO 5100 2400 500 1100 .................... ...... .... ...... ° 2800 1000~% 2700 500~ 260O 2500 5000 70O ~----~-~'~--~4900 220~ 2400 27 ~-~ 4700 28O 260 240 22O 2OO 180 16O 140 120 1 oo 8O 6O 4O 2O 2O ' ' ' ~ ' ' ' ' ' 4'0 ~ '0 ' ~ ' 2' ' 4'0 ' 6~0 ' 80 140 120 1 O0 8'0 60 2 0 0 80 <- West (feet) /k I Z 0 I RCO Alaska, Structure : Pod 3K Well : 25 Field : Kuporuk River Unit Locdion : North Slope, AleskoI A I ~60 520 C- 480 O 440 c,,o~,~ u~ ~.~ For: BROCKGYAY O~te p~otted : 14-Apr-9§ plot Ref~ence ;s 25 Version ~2. Coordinotes are in feet reference s~ot ~25. True Ved;col Depths ore reCerence RKB (Porker ~245). <- West (feet) 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 880 I I I I I I I I t I I I I I I I I I ~U~.) I I I I I I I I I I I 4200 840 ~ 260O 800 2100 ~ 1900 41 76O 72o 2500i 4000 1800 2OOO 680 640 1900 I 1700 i 3900 6O0 } 2400 ~aoo 1600 3800 2300 1700N 1500 i N, oo 400 ~k~2200i ~ ~ 1400 1900 i 1500 13O --<° 1800~ I I I I I I I i I i I I I I I I I I [ I i i I i i 280 240 200 160 880 84O 8OO 760 720 680 640 6O0 480 440 4O0 360 520 1200 280 1100 1000 240 2OO A 560 I 100~ 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 o 40 <- West (feet) Z 0 520 ~.~ 160 For: BROCI~¥AY Creeled by finch Oate p~otted : 14-Apr-9§ Pier Ref~enc~ Js 25 V~rs;~ ~2. Coordinates are in feet re~erance slot ~2D. True Ve~ical Oepths ore re~erence RKB (Parker ~245). 2600 2500 2400 2300 2200 2100 2O0O 1900 1800 1700 1600 1500 1400 1300 1200 11o0 1000 9OO 8OO ARCO Alaska, Inb Structure : Pod 5K Well: 25 Field : Kuporuk River Unit Locotion: North Slope, Alosko East (feet) -> 600 500 400 300 200 t00 0 100 200 300 400 500 600 700 800 900 , I I , ~, , , , I , ,~1 I , I t , , I I I I I I I , , I , f 3800 4200 3500 41 O0 3400 i 3700 i 4000 330C [ 3900 ¢3600 / 3800 3200 / 3700 ~ 3500 3100 I 3600 j3400 3000 5400 2900 ~ 3300 3300 2800 i 3200 ! 5500 ~ 3200 I 3100 2700 2600 ~ 3100 ] 2900 / 2800 2500 5100 2700 470( 2400 \i2900 2600 460( 2300i 2500 450( 280~i ~2200 2400 4600 2500 / I2100 iO0 270~/ / 430( 2200 4200 /1 2100 I i i i i i i i i I i II 600 500 400 500 200 100 0 100 200 300 400 500 600 700 800 900 East (feel) -> I i I I I I i t i 2600 2500 2400 2300 2200 2100 2000 1900 A 1800 I Z 1700 ~0 --I- 1600 ~D 1500 1400 1300 1200 110o 1000 900 8OO ARCO Alaska, Inc. Pad 3K 25 slot #25 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 25 Version Our ref : prop2899 License : Date printed : 14-Apr-98 Date created : 30-Mar-98 Last revised : 14-Apr-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 25 48.667,w149 45 49.2 Slot location is nT0 26 1.423,w149 45 39.898 Slot Grid coordinates are N 6008290.700, E 529307.805 Slot local coordinates are 1297.00 N 317.00 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet DECREASING CLEARJ%NCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath PGMS <0-9960 PGMS <0-10944 PGMS <0-9150 PGMS <0-8900 PGMS <0-8980 PGMS <0-8140 PGMS <0-8100 PGMS <0-8500 >,,2,Pad 3K >,,32,Pad 3K >,,1,Pad 3K >,,3,Pad 3K >,,4,Pad 3K >,,5,Pad 3K >,,6,Pad 3K >,,7,Pad 3K PGMS <0-8500 >,,8, PGMS <0-7580'>,,9A, PMSS <5275 - 7443'>,, PGMS <0-7300'>,,10, PGMS <0-7853'>,,11, PGMS <0-7770'>,,12, PGMS <0-8580'>,,13, PGMS <0-8960'>,,14, PGMS <0-9275'>,,15, PGMS <0-9843'>,,18, PGMS <0-9584'>,,17, PGMS <0-9038'>,,16, PMSS (SS) <648-11180'>, PMSS <834 - 11690'>,, PMSS <121 - 10462'>,, PMSS <10187 - 10456'>, PMSS <463-10375'>,,3 Pad 3K Pad 3K 9,Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K Pad 3K ,22,Pad 3K 26,Pad 3K 23,Pad 3K ,27,Pad 3K 0,Pad 3K Closest approach with 3-D Minimtun Distance method Last revised Distance M.D. Diverging from M.D. 10-Oct-96 112.2 18-Jun-97 200.0 10-Oct-96 137.1 10-0ct-96 87.2 10-0ct-96 62.3 10-0ct-96 34.5 10-Oct-96 12.4 10-Oct-96 12.6 10-0ct-96 37.1 10-Oct-96 57.9 10-0ct-96 57.9 10-Oct-96 137.1 10-0ct-96 159.1 10-0ct-96 187.2 10-0ct-96 213.1 10-Oct-96 237.1 10-0ct-96 263.1 10-Oct-96 338.1 10-Oct-96 312.1 10-Oct-96 288.1 15-May-97 72.6 5-Jun-97 21.2 16-Jun-97 50.0 16-Jul-97 49.4 30-Jun-97 148.0 0 0 100 0 100 0 100 0 0 0 625 0 100.0 300.0 675.0 650.0 650.0 0.0 700.4 525.0 0.0 0 0 0 0 0 0 0 0 0 0 400 0 625.0 100.0 200.0 575.0 0.0 100.0 4060.0 100.0 1700.0 625.0 400.0 300.0 675.0 650.0 650.0 0.0 700.4 525.0 0.0 675.0 0.0 0.0 0.0 00 9340 0 625 0 100 0 200 0 575 0 PG~S <O-9000~>,,35,P~'~3K 31 Version #2,,31,Pad 3K 34 Version #3,,34,Pad 3K 6-Apr-98 30-Mar-98 30-Mar-98 272.4 175.0 250.0 400.0~i 550.0 200.0 400.0 550.0 200.0 ' o ~ ~CINI TY MAP o 5 o 6 SCALE: 1" = 2 MILES 25 · o 7 26 ~ 8 , o E~S~NC C~OUCTORS : JO * · NEW C~DUC TOR L OCA flON 32 ~ 12 0 ~ N , JJ · ~ , J6 · , : 0 17 ~ 0 18 i I J5 T. 13 N. ~4 _ r ~ T. 12 N. SEE SHE~ ~ 2 FOR NOTES ~D LO~TION INFORMATION 2 LOUNSBURY & ASS0ClAT~S. INC. E~EE~ P~N~ SU~YO~ ~6A' 31 YODULE XX UNIT' ~ ~ CO~UClO~S ~22-27, 30-35 LOCA~ON AS-BUILT i~Evl O^_T[ I ~"' I CK I ^PPI DESCRIPTION PER . ~.c~# K96140ACS 8Y OESCRIPTION OLIKTOK PT. NOTES 1. COORDINATES SHOWN ARE A,S.P. ZONE 4, N,A.D. 27, ELEVAtiONS SHOWN ARE BRItiSH PEIROLEUM MEAN SEA LEVEL. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE D.S, 3-K MONUMENTS PER LHD AND ASSOCIATES. 3. CONDUCTORS ARE LOCATED WITHIN PROTRACTED SECtiON 35, TOWNSHIP 13 NORTH, RANGE 9 EAST, UMIAT MERIDIAN. 4. SEE DRAWING NSK 86-31 (CEA-D3KX-86JI), FOR INFORMATION ON CONDUCTORS #I - ~18. 5. DA TE OF SURVEY: 02/26-27/97, FB: 97-04, PG 54-62, 05/01/97, FB: 97-04, PG 71-75. 6. DRILL SITE J-K GRID NORTH IS ROTA TED 179' 5.,7' 50' WEST FROM A.S.P. ZONE 4 GRID NORTH VIC/N/TY MAP Sec. $5, T. 13 N., R. 9 E. U.M. LA TI TUDE A.S.P.s 6, 008, 366. 54 6, 008, 34 I. 52 6, 008, 316. 31 6, 008, 29 I. 50 6, 008, 266. 25 6, 008, 24 ;. 56 6,008,141.37 6,008,116.37 6, 008, 09 ;. 62 6, 008,066. 76 6, 008, 04 I. 5 I 6, 008, 016. 48 6, 007, 99 I. $8 529,306.21 529, 306. tO 529, J06. 529, J06.13 529, J05. 78 529,305.97 529, 306. 04 529,305.88 529,305.51 529, J05. 49 529, J05. 79 529,305.79 529, J05. 46 ARCO Alaska, Inc · CADO FILE NO. DRA~NG N~. LK6311D9 70' 26' 02. I69 70' 26' 01.925" 70' 26' 01.675 70' 26' 01.4JI 70' 26' 01.182' 70' 26' 00.939" 70' 25' 59. 954' 70' 25' 59. 708' 70' 25' 59. 465 70' 25' 59.220" 70' 25' 58.972" 70' 25' 58. 726 70' 25' 58. 4 L ONGI TUDE SCALE: I"' = 2 MILES 149" 45' $9.9J6' 149' 45' 39.942' 149' 45' J9,944' 149' 45' J9.947' ;49' 45' J9. 960' 149' 45' 39.957" 149' 45' 39.967' 149' 45' J9.974" 149' 45' J9.988' 149' 45' J9.992" 149' 45' J9.986" 149' 45' J9.989" 149' 45' 40.001" SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT i ~ PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF M~RCH ,2. 1997. LOUNSBURY & ASSOCIATES, INC. E~EERS PLANNERS SUEVEYO~ AREA' 3K MODULE- XX DRILL SITE 3-K WELL CONDUCTORS #22-27, 50-36 LOCATION AS-BUILT SHEET: CEA-D3KX-6511D9 2 OF 2 UNIT' 05 KUPARUK RIVER ,iT 20" DIVERTER SCHEMATIC 6 3 DO NOT SHUT IN DIVERTER -.AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE: :~ OPI~RAT[ON UPON INITIAL INSTALLATION: · CLDSE VALVE AND FILLPREVENT13~wri'HWA~~ ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. C[.O~E ANNULAR PREVENTER IN THE L=v~r'i'NATAN INFLUX OFWF~ ~ mORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA. INC.. REQUESTS APPROVAL OF'THIS ONERTER SYSTEM AS A VARIANCE FROM 20AAC2~.035~) 1. 16' CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE2-1/16'- 2000 PSI BALL VALVE 4. 20' - 2000 PS! DRILLING SPOOL WITH ONE ! 6' OUTLET. 5. ONE ! 6' HCR KNIFE VALVE WITH 16' DIVERTER MNF_ THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER UNE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. $. 20' - 2000 PS! ANNULAR PREVENTER. 7 1,3 5/8" 5000BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULJC FLUID. ASSURE THATACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSi DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME. THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNIT'~ ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIMEAND 1200 PSI REMAINING PREE~URF_ BOP STACK TEar t [ 3 2 I. I$' - 2000 PSI STARTING HEAD ?_ 11' - 3000 PSI CASING HEAD II'-3(XX)PSIX 13-5/8'-5000 PSI SPACER SPOOL 4. 13-5/8' - 5(:XXI PSi VARIABLE PIPE RAMS 13-5/8' - 5000 PSI 0RLG SPOOL W/ CHOKE AND KILL UNES &' 135/8' - SO(X) PSI DOUBLE RAM W/ PIPE RAMS ON TOP. BLJNO RAMS ON BTM 7. 13-5~'- 5000 PSI ANNUI_4R 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2- CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND IN WELLHEAD. RUN IN LOCK-OOWN SCREWS IN HEAD. CLO~E ANNULAR PREVENTER AND CHOKES AND BYPAS~ VALVl~ ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEb'TALL COMPONENTS TO 250 PS! AND HOLD FOR 3 MINUTE~ INCREASE PRESS-~J~ TO 5000 PS1 AND HOLD FOR 3 MIN~ BLEED TO ZERO PSI. TESTANNULAR PREVENTOR TO ~ P~ ONLY. OPEN ANNULAR PREVENTORANO MANUAL KILL AND C~UNE VALVE~ CLOSE TOP PIPE Ft4M~ AND HCR VALVES ON KILL AND CHOK~ LINE~ 7. TESTTO 250 PSI AND 5000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVE~. UNE~. AND CHOKESYVITI~A LOWANDS00OPSIHIGH. TE~T AS IN STEP 4. OONOTP~ETEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOK~ OPEN TOP PIPE RAJVE$ AND CLC)E~ BOTTOM PIPE RAIVE~ TEb"r BOTI~M RAMS TO 250 PSi AND 5000 PSI FOR 3 M1NUTE$. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULLOUTOFI~::~I.F_ CLOSE BUND RAMS AND TESTTO 5000 PSI FOR 3 MINUTE~ BLEED TO ]0. OPEN BUND RAMS AND RECOVER TEST PLUG~ MAKE SURE MANIFOU:I AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SE'TIN THE 0RILUNG POSITION. ! I.TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTE~ 1~_ TEST KELLY COCKS AND INSIDE BOP TO 5000 PS! WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRlUJNG SUPERVISOR. 14. PERFORM COMPLETE BOPE TESTONCEA WEEK AND FUNCTIONALLY OPERATE BOPE D~ULY. NOTE: PRIOR TO DRILMNG OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TESTANO THE PRIOR 'ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH · WELL PERMIT CHECKLIST COMPANY FIELD & POOl. _ ........ _~/_ ~7~5_,//_~_<:~_ ...... INI1- CLASS ,/'" ADMINISTRATION A ...... ENGINEERING GEOLOGY 2 I ease ~Llrrrl)er appropriate 3 Unique well name and ntwnbet 4 Well Iocaled in a defined pool ......... 5 Well Iocaled proper distance lrom drillin~ unil boundary. 6 Well Iocaled proper distance [rom other wells . . 7 St~fficienl acreage available in drilling unit 8 If dev~aled is wellbore plal irlcluded (_;peralor only affected pa~y 10 ()peralor has appropriate bond in lorce 11 f'ern~il can be issued wilhoul conse~ation order 12 F'e~mit can be issued wilhoul administrative apploval (:;~ll l)Olrlllt be approved before 15-day wail WELl_ NAME ,/~/ ~,~/~-2..,?~'". PROG, RAM: exp [] dev [] redrll [] serv~wellbore segl ann disposal para req GEOL ~AREA 0~-~'<::) UNIT# ___ //',/'~..' _ __ ON/OFF SHORE ___O~_. . REMARKS 14 Cc)r~cJuCtOl sl~lng provided 15 5;t~rl~'~ce casing protects all k~owl~ LJSDWs. . . 16 C;kll' vol adequate to circulate on conductor & surf csg 17 C;M 1 vol adequate to tie-in long string to surt csg 18 CM"I will cover' all known productive horizons... 19 Casing designs adequate for C, 7. B & permafrost 20 Adequate tankage or rese~e pit ........... 21 If a re-d~ill, has a 10-403 for abandon~nent been approved. 22 Ad~ecltlalo wellbo~e sepa~alion proposed.. Il diverler reqtnred, does il meel regulations 24 [)lilllnft flt~i(I program ~;ctl(]rllalic & eqtlip list [i[leqtialo 25 [.J(.)['[. ~,. do lliey rneel regtJlatioll 26 BOPE pless raliilg appropriate' lest Io ~~ 27 Choke manilold complies w/APl RP-53 (May 84) 28 Work will occur wilhotIl operalion shutdown I~; l~reserlce ol H:,S gas probable. 30 l:'ern,it can be isstred w/o hydrogen sulfide measures 31 [)at;~ p~osenled on polenlial overpresstne zones 3:_) Se~s~n~c analysis ol shallow gas zones 33 Seabed condition stJrvey (if off-shore) . 2;,1 (':,~rdz~(:t llr]~]le/l')hor]e for we_eklyprogress repqlts le)~plorglot]/ only] ps~!] N Y N ............. (3EC)I C)C.i Y ENGINEERING COMMISSION B E V~._~_~?/P_ ~ DWJ_¢:;:~.,_._/ co s/t ~ _ .... , ...... C o m m e nts,I n.~u c~.):~n s/, . N N N N N N N 'N 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. Sperry-Sun Drilling Services LIS Scan Utility Mon Jul 06 17:54:18 1998 Reel Header Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Services Tape Header Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Services Library. Scientific Technical Library. Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MWD RUN 2 AK-MM-80229 P. SMITH D. LUTRICK MSL 0) 3K-25 500292288100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 06-JUL-98 MWD RUN 3 MWD RUN 4 AK-MM-80229 AK-MM-80229 P. SMITH P. SMITH D. LUTRICK D. LUTRICK 35 13N 9E 1297 317 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: .00 75.30 34.30 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 7.625 5560.0 6.750 10170.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL DEPTHS ARE DRILLER'S DEPTHS. DEPTH SHIFTING OF THE MWD DATA IS WAIVED AS PER THE CONVERSATION BETWEEN MIKE WERNER AND A. TURKER ON 06/16/98. MWD IS PDC. 3. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 4. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. MWD RUN 4 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. WELL 3K-25 REACHED A TOTAL DEPTH (TD) OF 10170'MD, 6,868'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED ~HASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX ROP $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 5537.5 10129.5 5544.5 10136.5 5544.5 10136.5 5544.5 10136.5 5544.5 10136.5 5544.5 10136.5 5572.0 10169.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 2 5590.0 6088.0 3 6088.0 9422.0 4 9422.0 10170.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0. Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD API 4 1 68 4 2 RPX MWD OHMS4 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPM MWD OHMM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 ROP MWD FT/H 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Name Min Max Mean Nsam Reading DEPT 5537.5 10169 7853.25 9264 5537.5 GR 32.7757 738.318 115.168 9185 5537.5 Last Reading 10169 10129.5 RPX 0.4443 2000 4.6423 9185 RPS 0.3258 2000 4.45423 9185 RPM 0.2232 2000 9.24797 9185 RPD 0.2083 2000 5.74052 9185 ROP 4.0319 659.766 190.798 9195 FET 0.1278 57.66 1.65204 9185 5544.5 5544.5 5544.5 5544.5 5572 5544.5 10136.5 10136.5 10136.5 10136.5 10169 10136.5 First Reading For Entire File .......... 5537.5 Last Reading For Entire File ........... 10169 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH STOP DEPTH 5537.5 6033.5 5544.5 6040.5 5544.5 6040.5 5544.5 6040.5 5544.5 6040.5 5544.5 6040.5 5572.0 6088.0 17-MAY- 98 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REA_L-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 ISC 5.06 CIM 5.46 MEMORY 6088.0 5590.0 6088.0 .0 .0 TOOL NUMBER P0921SP4 P0921SP4 6.750 6.8 LSND 169.20 45.0 9.0 5OO 9.2 .000 .000 .000 .000 26.3 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 t 68 4 2 RPX MWD 2 OHMM 4 1 68 8 3 RPS MWD 2 OHMM 4 1 68 12 4 RPM MWD 2 OHMM 4 1 68 16 5 RPD MWD 2 OHMM 4 1 68 20 6 ROP MWD 2 FT/H 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 Name DEPT GR RPX RPS RPM RPD ROP FET Min 5537.5 40 1162 0 9927 2 3682 0 2232 0 7229 53 9229 0 1377 First Max Mean Nsam Reading 6088 5812.75 1102 5537.5 132.953 97.3516 993 5537.5 2000 10.0911 993 5544.5 2000 8.60072 993 5544.5 2000 52.6764 993 5544.5 2000 20.0974 993 5544.5 659.766 303.759 1033 5572 57.66 3.80068 993 5544.5 Last Reading 6088 6033.5 6040.5 6040.5 6040.5 6040.5 6088 6040.5 First Reading For Entire File .......... 5537.5 Last Reading For Entire File ........... 6088 File Trailer Service name ............. STSLIB.002 · Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FI LE SUMMARY VENDOR TOOL CODE START DEPTH GR 6034.5 FET 6041.0 RPD 6041.0 RPM 6041.0 RPS 6041.0 RPX 6041.0 ROP 6089.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMPI) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): STOP DEPTH 9368.0 9375.0 9375.0 9375.0 9375.0 9375.0 9422.5 19-MAY-98 ISC 5.06 CIM'5.46 MEMORY 9422.0 6088.0 9422.0 52.1 57.1 TOOL NUMBER P0921SP4 P0921SP4 6.750 6.8 LSND 196.20 63.0 8.5 45O 4.5 5.200 3.010 3.300 8.500 49.2 TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 GR MWD 3 API 4 1 68 RPX MWD 3 OHMM 4 1 68 RPS MWD 3 OHM~ 4 1 68 RPM MWD 3 OHMI~ 4 1 68 RPD MWD 3 OHMM 4 1 68 ROP MWD 3 FT/H 4 1 68 FET MWD 3 HOUR 4 1 68 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max ' Mean DEPT 6034.5 9422.5 7728.5 GR 38.0463 738.318 121.631 RPX 0.4443 19.612 2.99808 RPS 0.3258 32.594 3.0277 RPM 0.2936 55.3712 3.08025 RPD 0.2083 ' 22.2498 3.13304 ROP 9.0145 636.768 209.614 .6667 FET 0.1278 10.4345 0.658865 6669 Nsam 6777 6668 6669 6669 6669 6668 First Reading 6034.5 6034.5 6041 6041 6041 6041.5 6089.5 6041 Last Reading 9422.5 9368 9375 9375 9375 9375 9422.5 9375 First Reading For Entire File .......... 6034.5 Last Reading For Entire File ........... 9422.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9353.0 10129.5 FET 9358.5 10136.5 RPD 9358.5 10136.5 RPM 9358.5 10136.5 RPS 9358.5 10136.5 RPX 9358.5 10136.5 ROP 9391.5 10169.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS 23-MAY-98 ISC 5.06 CIM 5.46 MEMORY 10170.0 9422.0 10170.0 .0 .0 TOOL NUMBER P0921SP4 P0921SP4 6.750 6.8 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 230.80 60.0 8.5 650 4.2 2.300 1.426 1.800 2.800 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 API 4 1 68 4 2 RPX MWD 4 OHMM 4 1 68 8 3 RPS MWD 4 OHMM 4 1 68 12 4 RPM MWD 4 OHMM 4 1 68 16 5 RPD MWD 4 OHMM 4 1 68 20 6 ROP MWD 4 FT/H 4 1 68 24 7 FET MWD 4 HOUR 4 1 68 28 8 54.9 Name DEPT GR RPX RPS RPM RPD ROP Min 9353 32 7757 1 9838 2 0356 2 0939 2 2503 4 0319 First Max Mean Nsam Reading 10169 9761 1633 9353 164.218 98.8768 1554 9353 126.01 8.16446 1557 9358.5 92.3129 7.88466 1556 9359 85.6728 7.83434 1556 9359 71.2068 7.69294 1556 9359 580.622 40.4736 1556 9391.5 Last Reading 10169 10129.5 10136.5 10136.5 10136.5 10136.5 10169 FET 0.9542 48.9873 5.52888 1557 9358.5 10136.5 First Reading For Entire File .......... 9353 Last Reading For Entire File ........... 10169 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/07/06 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 98/07/06 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing'Library. Services Scientific Technical Scientific Technical Physical EOF Physical EOF End Of LIS File
