Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
195-102
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, July 22, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2T-36 KUPARUK RIV UNIT 2T-36 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2025 2T-36 50-103-20228-00-00 195-102-0 G SPT 5776 1951020 1500 2620 2620 2620 2620 220 360 320 320 4YRTST P Adam Earl 6/21/2025 MIT-IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 2T-36 Inspection Date: Tubing OA Packer Depth 620 1800 1730 1710IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250625075232 BBL Pumped:3.8 BBL Returned:3.4 Tuesday, July 22, 2025 Page 1 of 1 1. Type of Request:Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing 2. Operator Name:4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool?N/A Yes No 9. Property Designation (Lease Number):10. Field: 11. Total Depth MD (ft):Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 15,471'N/A Casing Collapse Conductor Surface Production Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): 12. Attachments:Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations:OIL WINJ WDSPL Suspended 16. Verbal Approval:Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng 5,836' - 5,927' 7/25/2025 3 1/2" 7" 16" 9 5/8" 80' 4,762' 15,443'15,404' 121' 2,888' 121' 4,803' 6,047' Length Size Proposed Pools: L-80 TVD Burst 15,034' MD STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0025568 195-102 P.O. Box 100630, Anchorage, Ak. 99510 50-103-20228-00-00 ConocoPhillips Alaska, Inc. AOGCC USE ONLY Tubing Grade:Tubing MD (ft):Perforation Depth TVD (ft):Perforation Depth MD (ft): 15,116' - 15,258' Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi):Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY Other: Conductor Ext KUPARUK RIV UNIT 2T-36 KUPARUK RIVER KUPARUK RIVER OIL N/A 6,073'N/A Well Integrity Field Supervisor Brennen Green / Roger Mouser N1927@conocophillips.com 907-659-7506 SSSV: CAMCO DS LANDING NIPPLE Packer: BAKER SAB-3 PERMANENT PACKER SSSV: 518' MD / 518' TVD Packer: 15,006' MD / 5,767' TVD m n P 1 6 5 6 t N Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927 @conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.25 10:10:27-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green 325-383 By Grace Christianson at 1:36 pm, Jun 25, 2025 DSR-6/30/25JJL 6/27/25 10-404 A.Dewhurst 17JUL25*&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2025.07.17 14:24:59 -08'00'07/17/25 RBDMS JSB 071825 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 6/25/2025 Commissioner Jessie Chmielowski Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Chmielowski, Please find enclosed the 10-403 application for Sundry Approval from ConocoPhillips Alaska, Inc. for well KRU 2T-36 (PTD 195-102) to extend the conductor. Summary: Conductor has subsided or well has grown ~10” or more. With AOGCC approval we would like to add conductor material to cover the production casing. Please contact Brennen Green or Roger Mouser at 659-7506 if you have any questions. Sincerely, Well Integrity Field Supervisor ConocoPhillips Alaska, Inc. ConocoPhillips Alaska, Inc. Digitally signed by Brennen Green DN: C=US, O=ConocoPhillips, CN=Brennen Green, E=n1927@ conocophillips.com Reason: I am the author of this document Location: Date: 2025.06.25 10:09:38-08'00' Foxit PDF Editor Version: 13.1.6 Brennen Green P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Kuparuk Well 2T-36 (PTD 195-102) SUNDRY NOTICE 10-403 APPROVAL REQUEST 6/25/2025 This application for Sundry approval for Kuparuk Well 2T-36 is to extend the conductor to original height to stabilize tree and prevent corrosion to the surface casing. At some point during normal operations the conductor subsided or the well has grown ~10”. With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Extend the conductor to starter head. 3. File 10-404 with the AOGCC post repair with photo documentation. Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.062 Top (ftKB) 41.0 Set Depth (ftKB) 121.0 Set Depth (TVD) … 121.0 Wt/Len (l… 62.58 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.835 Top (ftKB) 41.0 Set Depth (ftKB) 4,802.7 Set Depth (TVD) … 2,888.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC Casing Description PRODUCTION OD (in) 7 ID (in) 6.276 Top (ftKB) 38.6 Set Depth (ftKB) 15,443.0 Set Depth (TVD) … 6,046.5 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MOD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.992 Top (ftKB) 37.8 Set Depth (ft… 15,034.0 Set Depth (TVD) (… 5,784.2 Wt (lb/ft) 9.30 Grade L-80 Top Connection AMB-EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 37.8 37.8 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 518.4 518.3 0.47 NIPPLE CAMCO DS LANDING NIPPLE w/2.856" NO GO NO GO 2.812 14,956.2 5,737.1 53.53 SLEEVE-C BAKER CMU SLIDING SLEEVE w/ CAMCO W PROFILE; CLOSED 10/21/95 2.812 15,005.2 5,766.5 52.51 ANCHOR K ANCHOR, RUN WITH PACKER 2.992 15,006.1 5,767.1 52.48 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 15,022.0 5,776.8 52.01 NIPPLE CAMCO D LANDING NIPPLE NO GO 2.750 15,033.1 5,783.7 51.67 SOS BAKER SHEAR OUT SUB, ELMD TTL @ 15021' during SWS CBL on 10/20/95 3.015 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (shots/f t)Type Com 15,116.0 15,172.0 5,836.2 5,872.0 C-4, A-3, 2T- 36 10/20/1995 4.0 2 1/8" Enerjet Zero deg. phasing; alternating BH/DP charges 15,221.0 15,235.0 5,903.4 5,912.4 A-2, 2T-36 10/20/1995 4.0 2 1/8" Enerjet Zero deg. phasing; alternating BH/DP charges 15,245.0 15,258.0 5,918.8 5,927.2 A-2, 2T-36 10/20/1995 4.0 2 1/8" Enerjet Zero deg. phasing; alternating BH/DP charges Notes: General & Safety End Date Annotation 9/13/2011 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLE2T-36, 7/24/2014 10:52:49 AM Vertical schematic (actual) PRODUCTION; 38.6-15,443.0 2 1/8" Enerjet; 15,245.0- 15,258.0 2 1/8" Enerjet; 15,221.0- 15,235.0 2 1/8" Enerjet; 15,116.0- 15,172.0 SOS; 15,033.1 NIPPLE; 15,022.0 PACKER; 15,006.1 ANCHOR; 15,005.2 SLEEVE-C; 14,956.2 SURFACE; 41.0-4,802.7 GAS LIFT; 2,197.8 NIPPLE; 518.4 CONDUCTOR; 41.0-121.0 HANGER; 37.8 Annotation Last Tag: SLM Depth (ftKB) 15,130.0 End Date 7/23/2014 Annotation Rev Reason: TAG Last Mod By lehallf End Date 7/24/2014 KUP INJ KB-Grd (ft) Rig Release Date 7/26/1996 Annotation Last WO: End Date 2T-36 H2S (ppm) Date ... TD Act Btm (ftKB) 15,443.0 Well Attributes Wellbore API/UWI 501032022800 Field Name KUPARUK RIVER UNIT Wellbore Status INJ Max Angle & MD Incl (°) 77.73 MD (ftKB) 6,632.41 MEMORANDUM TO: Jim Regg r7) / P.I. Supervisor ��ee, �00Z� FROM: Jeff Jones Petroleum Inspector Well Name KUPARUK RIV UNIT 2T-36 Insp Num: mitJJ210628154120 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, July 9, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 2T-36 KUPARUK RIV UNIT 2T-36 Src: Inspector Reviewed By: P.I. Supry Ja2 — Comm API Well Number 50-103-20228-00-00 Inspector Name: Jeff Jones Permit Number: 195-102-0 Inspection Date: 6/5/2021 Packer Depth Well 2T-36 Type Inj W, TVD 5776 Tubing PTD 1951020 Type Test SPT � Test psi 1500 IA BBL Pumped: 3 5 -BBL Returned_ Interval , 4YRTST IPF 3.2 P OA Notes' 1 well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min 1250 _ 1250 - 1250 1250 520 2000 — —1940 1930 400 I 600 580 580 " Friday, July 9, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg / / DATE: Thursday,June 15,2017 P.I.Supervisor tei to Z1 g7 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-36 FROM: Lou Laubenstein KUPARUK RIV UNIT 2T-36 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry Cge-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-36 API Well Number 50-103-20228-00-00 Inspector Name: Lou Laubenstein Permit Number: 195-102-0 Inspection Date: 6/5/2017 Insp Num: mitLOL170607154614 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2T-36 - Type Inj W TVD 5776 Tubing 2050 - 2050 .- 2050 2050 . PTD 1951020 Type Test SPT Test psi 1500 - IA 950 2700 • 2630 - 2620 - BBL Pumped: 4 - BBL Returned: 4 - OA 475 - 680 - 670 675 • Interval ; 4YRTST P/F P Notes: ScoNEO EP Val? Thursday,June 15,2017. Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢,~/~-- F ileNumberofWellHistoryFile PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: scanned by: Beverly Dian~Nathan Lowell Da~e:~~ Is/ TO RE-SCAN ' ~.. ' Notes: ~,~ 7' ~ Re-Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,June 03,2013 TO: Jim Regg k P.I.Supervisor 1, `( '''14 1� SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-36 FROM: Lou Grimaldi KUPARUK RIV UNIT 2T-36 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv- 1 NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2T-36 API Well Number 50-103-20228-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-102-0 Inspection Date: 6/1/2013 Insp Num: mitLG130601144412 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min - Well 2T-36 Type Inj W iTVD IA i 1940 - 1931 PTD T e Test p 1500 OA a 1 o 500-Test st s� 6 610 2000 1951020 SPT 490 490 IP/F / j Tubing l YP i 4YRTST P 1150 1150 1150 1150 Interval - - -- --_ --- ---_- - ---_ --- _— ----- _ - '- ---- --- ---- --- Notes: 2.64 bbl's diesel pumped,3.12 bbl's returned.Good solid test,crew well prepared. SCANNED FEB 2 0 21114 Monday,June 03,2013 Page 1 of 1 L ConocoPhillips Alaska P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 1, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: J~~ Ip~- ~q p~~ ~~ 1~ . `~ ~I~j~~ ~*~ ~&8 ., . C~ .~3~~tr)y~r~g~ G-+ssio~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 21St. The corrosion inhibitor/sealant was pumped July 30tH, 31St 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 8/01/10 2B. 2K. 2T PAD Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 26-13 50029211380000 1841040 64" 0.4 11" 7/21/2010 1.7 7/31/2010 2K-16 50103201150000 1890940 SF n/a 19" n/a 2.8 7/31/2010 2K-20 50103201200000 1891180 10" n/a 10" n/a 2 7/31/2010 2K-23 50103201250000 1900140 SF n/a 18" n/a 2.6 7/31/2010 2K-24 50103201220000 1891300 SF n/a 18" n/a 2.6 7/31/2010 2T-07 50103200690000 1861080 17" n/a 17" n/a 5.1 7/30/2010 2T-19 50103202140000 1950260 18" n/a 8" n/a 2 7/30/2010 2T-20 50103202150000 1950290 SF n/a 23" n/a 2.6 7/30/2010 2T-21 50103202120000 1950130 SF n/a 21" n/a 3.4 7/30/2010 2T-26 50103202230000 1950820 SF n/a 27" n/a 4.3 7/30/2010 2T-29A 50103202220100 2091360 SF n/a 29" n/a 7.7 7/30/2010 2T-30 50103202190000 1950570 SF n/a 30" n/a 6 7/30/2010 2T-31 50103202260000 1950990 30" n/a 30" n/a 6 7/30/2010 2T-36 50103202280000 1951020 SF 0.40 12" 7/21/2010 2.6 7/30/2010 2T-39 50103203920000 2011830 30" 0.54 14" 7/21/2010 4.3 7/30/2010 2T-201 50103202300000 1951220 60" 1.57 32" 7/21/2010 7.7 7/30/2010 2T-204 50103203270000 2000160 SF n/a 24" n/a 5.1 7/31/2010 2T-209 50103202810000 1982430. 40" 1.20 19" 7/21/2010 4.8 7/31/2010 2T-218 50103204490000 2030170 31" 0.73 9" 7/21/2010 2.6 7/31/2010 2T-220 50103202830000 1982530 38" 0.49 19" 7/21/2010 5.1 7/31/2010 MEMORANDUM To: Jim Regg r-;-->~ / P.I. Supervisor ~~ ~`1blt~ FROM: Jeff Jones Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-36 KUPARUK RIV UNIT 2T-36 Src: Inspector NON-CONFIDENTIAL Reviewed By: ~:~ P.I. Suprv J17~-- Comm Well Name: KUPARUK RIV UNIT 2T-36 API Well Number: 50-103-20228-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ090608130342 Permit Number: 195-102-0 ~ Inspection Date: 6/1/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Weil ~ 2T-36 ,Type nj j. N ~ TVD 5775 '~ IA T SSO I 1700 1610 ]600 P.T.D 020 TypeTest ~ sPT Test psi ~ 1500~QA 240 260 260 260 Interval 4YRTST per, P ,i Tubing 9so I 950 925 925 NOtes• 1 well inspected; no exceptions noted. Wednesday, June 10, 2009 Page 1 of 1 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg Kêtl9' 6(7/07 P,I. Supervisor í (.. DA TE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2T-36 KUPARUK RIV UNIT 2T-36 Src: Inspector ,ø..'6,-\O'ð" FROM: Chuck Scheve Petroleum Inspector Well Name: KUPARUK RIV UNIT 2T-36 API Well Number: 50-103-20228-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070603 145825 Permit Number: 195-102-0 Inspection Date: 6/2/2007 /' ReI Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2T-36 Type Inj. w TVD 5776 IA 1350 2550 I 2500 2500 P.T.D 1951020 ITypeTest SPT Test psi 1500 OA 820 900 i 900 900 I I l Interval 4YRTST P/F P ,/ Tubing 2160 2160 I 2160 2160 I Notes: Pretest pressures observed and found stable. Well demonstrated good mechanical integrity. / NON-CONFIDENTIAL Reviewed By: P.I. Suprv:[B,e... Comm sCANNED JUN· 2 0 2007 Wednesday, June 06, 2007 Page I of I MEMORANDUM TO: Randy Ruedrich Commissioner THRU: Jim Regg ,,'~' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 14, 2003 SUBJECT: Mechanical Integrity Tests Conoco/Phillips Kuparuk River Field 2T Pad FROM: John Cdsp Petroleum Inspector NON- CONFIDENTIAL Kuparuk River Unit Packer Depth Pretest Initial 15 Min. 30 Min. we,,I2T-3S IType,nj.I SI I 2 01 2 01 2 01 2 0 I'nter a'l 4 P.T.D.I 1951020ITypetesq P ITestpsil 3000 I Casingl 1300 I 3050 I 3000 I 3000 I P/F I E Notes: OA 500 psi. pretest 720 psi. during test. 4.1 BBL. Pumped. WellI 2T-201IType,nj.I S I T.V.D.I~ ITubi'g! 11oo 11100 11100 IllOOIlntervall 4 P.T.D.I 1951220 ITypetestl P ITestpsil 3000 I Casing| 1350I 2875I 2820I 2800I P/F I P Notes: OA 350 psi. during test. 1 BBL. Pumped, WellI P.T.D. I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: .J ype INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details I traveled to CJP's Kuparuk River Field to witness 4 year MIT's. No failures witnessed. Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 2 Number of Failures: 0 Attachments: Total Time during tests: 2 hrs, cc: MIT report form 5/12/00 L.G. 2003-0614_M IT_KRU_2T-20 l..jc.xls 6/24/2OO3 AUG 0 4 2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state. ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: FIELD / UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk/KRU/2T 06/14/03 Sauvageau/Brake - APC John Cdsp Well 12T-l 0 P.T.D.I'I860960 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type lnjI Sp I T.V.D. I 5771 I Tubing I 25501 25501 25501 25501 Interval TypeTest Test psiI 1500 I Casing I 11501 30801 30501 30401 P/F P.T.D.I'I950'I70 TypeTest Test psiI 15oo I Casing I 18001 29701 29501 29401 P/F Notes: P.T.D,I~950820 Type Test Test psiI 1500 I Casingl 10201 30101 30001 30001 P/F Notes: We,,12T-2S I Typelnj I SpI T.V.D. I I Tubing I 21201 2 201 2 201 212011ntervall i~ P.T.D..I~950920 TypeTest Test psiI 1500 I Casing I 13401 30501 30001 29801 P/F Notes: P.T~D:~I~tgS0750.. i Type Test Test psiI 1500 I Casing I 2401 29501 29251 29101 P/F Notes: P.T.D.I~95~020 TypeTest Test psiI 1500 I Casing I 13001 30501 30001 30001 P/F Notes: P.T.D.I'I95~220 TypeTest Test psiI 1500 I Casing I 13501 29501 29201 28751 P/F Notes: Carried MIT out for one hour Pressure at 45 rnin 1100/2820 1 hr 1100/2800 Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting MIT Report Form Revised: 05/19/02 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test 2003-0614_MIT_K RU_2T-10_-18_-26..-28_-29_-36_-201 .xls INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) 6/25/2003 RU ,~, yr MITs 2K & 2T Subject: KRU 4 yr MIT's 2K & 2T Date: Sun, 15 Jun 2003 16:23:23 -0800 From: "NSK Problem Well Supv" <nl 617@conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, jim_regg~admin.state.ak.us, tom_maunder~admin.state.ak.us CC: "nl 617" <n1617~conocophillips.com> Tom, Bob, Jim, Attached are the 4 yr MIT's for injection wells on 2K and 2T. Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224 (See attached file: MIT KRU 2T 06-14-03.xls) (See attached file: MIT KRU 2K 06-14-03.xls) ~MIT KRU 2T 06-14-03.xls Name: MIT KRU 2T 06-14-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 ~.MIT KRU 2K 06-14-03.xls Name: MIT KRU 2K 06-14-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 I ofi 6/25/2003 1:45 P STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 122 feet 3. Address Exploratoff__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 se~ce__X Kuparuk Unit 4. Location of well at surface 8. Well number 5259' FNL, 4725' FEL, Sec. 1, T11N, R8E, UM (asp's 498944, 5~9999) 2T-36 ~At top of productive interval 9. Permit number / approval number 195-102/_ ~At effective depth 10. APl number 50-103-20228 At total depth 11. Field I Pool 4810' FNL, 1191' FEL, Sec. 9, T11 N, R8E, UM (asp's 486640, 5965180) Kuparuk Oil Pool 12. Present well condition summary -I'otal depth: measured 15471 feet Plugs (measured) true vertical 6073 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 97 sx AS I 121' 121' SUR. CASING 4681' 9-5/8' 880 sx AS III Lead, 934 sx Class ( 4803' 2897' PROD. CASING 15321' 7" 265 sx Clsss G 15443' 6055' measured ~ ~6:-~?-~:-~,~J:'~, ~-~:'- A~i~'~ ................... RECEtVE D Perforation depth: ' ..... ~ - .-':- '- ........ · ":::;*;-:'::'.:::;:-!:? i*!ii!ii:--::':.i:::ii: i:iiZi.:::'i:.:'~:!. :::: :: :::? i:'!?!'?!!?::! true verticat ~:~;~8~'59:1~-...~:': '~;~.~2:7.~S:~36. :: ~:i::':i?.-':':.!.~:...:'.::;~ ?:~ ~ ~:::':i.:'i:!.~:i'.';':::i .:::j?.!:!!:~:.!:.;:i .i.::i-~!i:!:!::~; :i:?::i:?.-:i::.:.~:i:~.?).:?:_~i:i!{3:/-;ji-iii: :-:!-ii-i":):i!:i'i}/.::!:~:!.:' :.;i~:!~il & Gas Cons. Commission Tubing (size, grade, and measured depth) :~'.'~i~:~i:~!~;~i~.~.~'"~:i~.;ii'!'ii:.ii~:i!!:~i:.'}-::i:ii::ii:::' ! ::'::~:i:i!!':.'::!.::?-?i::':::: i'!i: i.i-.::-i.! Anchol'a~je 13. Stimulation or cement squeeze summary ~--:;!~-! ;:'"; ':'"":: ' -: :":': '"': :'~'"'~ ': '~ ~'~,,:'::"--"':::'::::'--:'~::::%' :'::-":::':;';::~ Intervals treated (measured) Treatment description including volumes used and final pressure .i:i.'i::.:' 14. Representative Daily Avera(3e Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X i:' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff spencer659-7~6 Signed -,~, 4~c~~ '13tle ProducUon Engineering Supervisor Date/~ /~-/~ ~)Z.-.-.- J~ff A. Spencer Prepared by Robert Ohristensen 659-7535 SCANNED APE 3 0 2002 Form 10-404 Rev 06/15/88' ORIGINAL ~eDMS BFL ~ P""'~' t0 .... : SUBMIT IN DUPLICATE 2T-36 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary t'..'"'- ......................................... ~ ...... :""" ........ ' ..... 1 t ARCO Alaska, Inc. Date: December 26, 1995 Transmittal #: 9311 R~"r~ ~RN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. ~j-: (~-? All items below include BOTH Biueline and Sepia. ~ ~ 2A-18 CBL 10/15/95 ,~'-~'~'f 2%32 CBL 10/19/95 ,~-- t~. 2%36 CBL 10/20/95 q~-- ~ 2. 1 Q-26 CBL 10/24/95 o~-.. ~t 1 Q-23 CBL 10/24/95 5800-6655 1313O-13636 14990-15325 5900-6885 8700-9866 Receipt ~.~ ¢~ Acknowledge' v.. Date' DISTRIBUTION' Sharon Aiisup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC :3001"Porcupine Drive A n c ho rage';7_AK; 99501' Erickson/Zuspan NSK Central Files NSK-box 69 .':'1A r~..,: ,~aska Oil & Gas Cons. ~i~chors.~ ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 4, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2T-36 (Permit No. 95-102) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 2T- 36. If there are any questions, please call 265-6206. Sincerely, Supervisor Kuparuk Drill Site Development MZ/skad STATE OF ALASKA ALASt,~ OIL AND GAS CONSERVATION COMrv .... ¢ION WELL COMPLETION OR REOOMPLETION REPORT AND LO"' of Service V~'el .//'~' . 1 Status of Well Classification ¢ ~//~,.~ OIL r'~ GAS ~ SUSPENDED ~ ABAN~NED ~ SERVICE ~ Classificalionc anged to Ware Injector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-102 3 Address 8 APl Number P.O. Box 100360, AnchoraCe, AK 99510-0360 50-103-20228 4 Location of well at surface ~ (:L~,.'~ [ ~:'?0~'~ ~ ~~~ 9 Unit or Lease Name 15' FSL, 556' ~L, Sec. 1, T11 N, RSE, UM ; ; ~'~-~~ Kuparuk River Unit ~ ; ..... ~ ~¢~ ~; 10 Well Number At Top Producing Inte~a, ~. ~'~~. ~,, -, ,1 Al Tolal Depth 467' FSL, 1189' FEL, Section 9, T11 N, RSE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease Designation and Serial No. RKB 41', Pad 81'~ ADL 25568 ALK 2666 12 Date Spuddedjuly 15, 1995 J 13 Datejuly 24,T'D' Reached1995 14 20-Oct-95Date C°mp' ' Susp' °r A~nd'(pe~d) [15 Water Depth. if offshoreNA feet MSL16 No. of Complotionsl ,7To,a. Uepth(MO+TVD, J 18P.ugBackDepth(MD+TVD) 19 DirectionalSu~ey~ ~ 120 DepthwhoreSSSVset J 21 Thicknessof~rmaffost 15471' M D & 6073' TVD 15353' MD & 5996' TVD YES ~ NO NA feet MD = 1380' ss APPROX 22 Type Electric or Other Logs Run GR/CDR/CDN.GR/CCUSLT-J 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEME~ ~RD 16" 151.53¢ X-65 SURF. 121' 36" 97 sx AS I 9.625" 40~ L-80 SURF. 4803' 12.25" 880 sx AS II1 Lead, 934 sx Class G Tail 7" 26~ L-80 SURF. 15443' 8.5" 265 sx Class G 24 Perfora¢ons open [o Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 15034' 15006' 15116'-15172'MD 4spf 5844'-5880'TVD 15221' - 15235' MD 4 spf 5912' - 5921' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 15245' - 1 5258' MD 4 spf 5927' - 5935' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lifl, e~c.) I Injection well Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD E ,. Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE E NA 28 CORE DATA Brief descri¢don of li~hology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. dAN 0 9 lSgB Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION -JESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 15112' 5842' Bottom Kuparuk C 15150' 5866' Top Kuparuk A 15150' 5866' Bottom Kuparuk A 15315' 5972' 31. LIST OF A~-fACHMENTS Daiiy Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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 JAN 0 9 1995 Date:Il/08/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:2T-36 RIG:PARKER 245 WI: 55% SECURITY:0 WELLID: AK8253 AFE: AK8253 TYPE:DEV AFE EST:$ 2096M/ 2730M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-103-20228 FIELD: KUPARUK SPUD:07/15/95 START COMP: FINAL: 07/15/95 (1) TD: 371'(371) SUPV:JT 07/16/95 ( 2) TD: 3434' (3063) SUPV: JT 07/17/95 (3) TD: 4815'(1381) SUPV:JT 07/18/95 (4) TD: 4815' ( 0) SUPV:JT 07/19/95 (5) TD: 5450' (635) SUPV: RLM 07/20/95 (6) TD: 9415'(3965) SUPV:RLM 07/21/95 ( 7) TD: 12355' (2940) SUPV: RLM 07/22/95 (8) TD:13512'(1157) SUPV:RLM 07/23/95 (9) TD:14317'(805) SUPV:RLM MW: 9.1 DRILLING Move to 2T-31. Drill to 371'. DAILY:S44,810 CUM:$44,810 PV/YP: 20/18 ETD:SO APIWL: 8.8 EFC: $2,140,410 MW: 9.2 PV/YP: 17/16 DRILLING Lost returns. Drilled from 375' to 3434'. DAILY:S89,890 CUM:$134,700 ETD:SO APIWL: 9.6 EFC: $2,230,300 MW: 9.4 PV/YP: 14/11 APIWL: 7.4 CIRCULATING Drilled from 3434 to 4815'. Had lost returns. Mix LCM. Tight hole problems. DAILY:S79,084 CUM:$213,784 ETD:SO EFC:$2,309,384 MW: 9.6 PV/YP: 16/11 NU BOPE Ran 9-5/8" casing. Cement casing. DAILY:S207,745 CUM:$421,529 ETD:SO APIWL: 8.2 EFC: $2,517,129 MW: 9.6 PV/YP: 20/20 APIWL: 8.0 DRILLING Test BOPE. Lifting handle broke off, missing piece in hole. Fishing for missing handle. Drill from 4825' to 4855' to ensure no junk on bottom. Directional drill 8.5" hole from 4855' to 5450'. DAILY:S126,712 CUM:$548,241 ETD:SO EFC:$2,643,841 MW: 9.7 PV/YP: 19/17 APIWL: 7.0 CIRCULATE FOR SHORT TRIP Directional drill 8.5" hole from 5450' to 9415'. DAILY:S69,743 CUM:$617,984 ETD:SO EFC $2,713,584 MW: 9.7 PV/YP: 21/16 APIWL: 5.5 DRILL 8-1/2" HOLE Directional drill 8.5" hole from 9415' to 12355' . DAILY:S79,563 CUM:$697,547 ETD:SO EFC:$2,793,147 MW: 9.7 PV/YP: 16/16 APIWL: 5.2 DRILL 8-1/2" HOLE Directional drill 8.5" hole from 12355' to 13512'. DAILY:S80,899 CUM:$778,446 ETD:SO EFC:$2,874,046 MW: 9.6 PV/YP: 14/16 APIWL: 5.6 DRILLING Directional drill 8.5" hole from 13512' to 14317'. DAILY:S79,378 CUM:$857,824 ETD:SO EFC:$2,953,424 Date:il/08/95 Page: 2 07/24/95 (10) TD:15116' (799) SUPV:RLM 07/25/95 (11) TD:15471'(355) SUPV:RLM 07/26/95 (12) TD:15471'( 0) SUPV:JT 07/27/95 (13) TD:15443'( 0) SUPV:JT ARCO Alaska Inc. DAILY DRILLING REPORT MW: 10.6 PV/YP: 16/17 APIWL: 4.8 DRILLING Directional drill 8.5" hole from 14317' to 15116' DAILY:S97,625 CUM:$955,449 ETD:SO EFC:$3,051,049 MW: 10.6 PV/YP: 21/17 APIWL: 4.5 POOH FOR 7" CASING Directional drill 8.5" hole from 15116' to 15471'. DAILY:S74,949 CUM:$1,030,398 ETD:SO EFC:$3,125,998 MW: 10.7 PV/YP: 22/19 CIRC W/CASING ON BOTTOM Ran 7" casing to 15443'. Circulate mud. DAILY:S222,244 CUM:$1,252,642 ETD:SO APIWL: 4.8 EFC: $3,348,242 MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Cement casing. Freeze protect annulus. Released rig @ 2330 7/26/95. DAILY:S114,912 CUM:$1,367,554 ETD:SO EFC:$3,463,154 Date:Il/08/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8253 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8253 TYPE:DEV AFE EST:$ 2096M/ 2730M STATE: API NUMBER: START COMP: FINAL: 09/15/95 (14) TD:15443' PB:15343' SUPV:MDD PREP TO PU DP MW: 8.6 SEAWATER Move rig from 2T-32 to 2T-36. Accept rig at 2230 9/14/95. NU BOP. Test BOPs, manifold, floor valves. DAILY: $22,350 CUM:$1,389,904 ETD:S0 EFC: $3,485,504 09/16/95 (15) TD:15443' PB:15353' SUPV:MDD TALLY, PU, RIH W/DP MW: 0.0 Load, tally, PU, and run in hole with drillpipe. DAILY:S31,200 CUM:$1,421,104 ETD:SO EFC: $3,516,704 09/17/95 (16) TD:15443' PB:15353' SUPV:MDD LOAD, RACK, TALLY 3-1/2" Continue to run in hole with drillpipe. DAILY:S33,200 CUM:$1,454,304 ETD:SO MW: 0.0 EFC: $3,549,904 09/18/95 (17) TD:15443' PB:15353' SUPV:MDD RIH W/ 3-1/2" COMPLETION MW: 0.0 Continue to load, drift, and tally first 300 joints of tubing. Run in hole with packer and tailpipe assembly. Load, drift, tally remaining 180 jts of tubing. Run in hole with 3-1/2" completion. DAILY:S33,200 CUM:$1,487,504 ETD:SO EFC:$3,583,104 09/19/95 (18) TD:15443' PB:15353' SUPV:MDD RIG RELEASED MW: 0.0 Continue RIH with 3-1/2" completion. Set packer. Freeze protect. Test tree. Secure well. Release rig at 1630 hrs. 9/18/95. DAILY: $127,830 CUM:$1,615,334 ETD:S0 EFC:$3,710,934 10/20/95 Completed cement bond log/perf A/C sand intervals 15116'-15172' 15221'-15235' & 15245'-15258' using 2-1/8" EJ with alternating BH/DP charges, 4 spf, 0© ph. Bond log indicated good cement for tbg tail down to 15110'; poorer quality cement below this depth. End of WellSummary for Well:AK8253 APl# GRI9 ~u~v=~ ANCLE 0:00 ~AT~: 25-dUL-?5 W~LL NUmBeR 0 -~.~ ....... ~ ........... '~ O,OO ij?(Ei-W) 0,00 AZimUTH FROM ...... "' ..... TO ~A~R~ l~ TIE :~ POIN::i:k: TRUE UER? }:P?H !2!,00 INuL!NA:Io~ AZIMUTH LATiTU~(N/-S) 0,00 !2i,00 i013,i6 1102,!2 .ii97,n°v, ~=5~ i7 24!~+ 96 2508,67 259?,75 . 27~8,~i 2~2,61 3068,57 ~.fi7 !092,55 !iS!,!?- TARGET S~ATiON AZIMUTH LATI?UD~ ~"'- I iU.s .... ft d~ ~e~ ft 0,oo 0,0~ 0,00 0,00 -= ~r, 3,50 "~ 00 !5,14 7,60 249,25 -7,7E' 94,8 !4~8,4fJ 47,27 !3,$0 252,3t -!7,60 96,a~ ~,'~? 250,74 !27,7& 20.52 2S~,!~.. = -42 ~.~ %94 84 75,i . v~.5 23!6~2n 2o~1.34 93.7 !Al,05 ....... 254,7i -~'" .. ~,.~¢ 254 -~n 2~!,76 29,!~ 25~,92 -S1,51 381,~ "~z ~$~ ~ 12 '-" ~,. JO,~ .... ~-~',~ -1 437,74 "~ =~ ;~F,. ~i: -i~'oz 49?.43 41,53 249+8! -iSi,A~, 630,5! zz,,=, ~o~ 24~.~,~e~''' -i'?~,12 ~ ~ 277,S 3999°78 !~4,I 4278,91 279,1 4560,42 2&1,5 4727,70 I~7,3 4944,~v~n 216,6 5225,?~ 26!,6 770,10 ~.=5 !004,39 :. 1085,22 !!74,38 1261.56 !350.00 .... ~49 ....... 55,34 246,19 -276.17 6i,6~ 247,?5 -336.41 _ . 64~40 2~~ .n :,~ '367.77 o/,., -' ........ .. ,~, 400,12 71.44 246.~2 -467.26 73.93 246.8? 2552.i4 2758,46 2827.84 2936.7! 30!!,14 t885.5~ 2!5I,t0 2327.78 2596,60 2868,77 73,03 247,0~ -683,34 73.57 248,68 -783.33 73.7~ 249.53 -846.34 75,53 75,5~ 251,01 -i234,10 it it O: 00 I, 39 0,,,.':3 1 -'i:<5 4,!5 _,- '3 ~,:: I5,~," AZIMUTH d~_'g fi ~ 0 0 I r, .--, i.'¥,L;J 21,f.,l? -.. . ~,., . 2 ?f -?0,95 ?6,6? 250,!6 2,L7 -!20+70 ~ ~t ~n vz '~ 94 !61,26 251 =~ -~,6~ ~¢A "" 252, -22~,06 236,79 252,6! ....... ' .... -~-1 ~=3,'"" -53'5',57 631,4f 251,71 £5i.4£ 249,92 £49,75 '&. ~ ~ ~. 'dj -1757.36 1885,54 248,75 -2003.4i 2!51,II 248,64 -21~8,47 2327.7~ 248.68 -2420.~8 259~,~2 -2677.43 2868.83 2~E.95 -2~29,69 3029.7? 2,2! 2,9¢ 2,76 { .'te' -' 1,3(.: 0,4..~ -0,5i ~: ! F'AC-E. N:,3, 7192,25 7472,75 775S,40 8032,!9 8214,41 ~250~7 999i.72 ~0740,34 iltii,21 !257~.~'~, 13795,66 I4t60,17 14252.55 14344,61 14436,56 14526,56 i46!7,62 A~.MUTH -- r ....~ -i~22,~' ~;'7-~ 77:tt .... - .... z~,~' -1621,^' -3772,~2 4"5~,~s~- ,. -~r¢';,76 4~'~ 40 %0,2 3475,6! "~:'" 3547,3~ £3¢,6 3628,40 r/O,o o~ ay)27 6224,35 7~,9~ ~'~-~ .... ~ O~ · ~-,.-., AZIMUTH 245',45 ..... 369,4 4241,72 7753,91 75,14 247,26 -E~i1,OO ~li~ i4 74,~9 ?~e,~O -2942,o~ ~ r, "~ ~ ~ ~ 249 30 DLE $ ~-=.-~ !, 2 '.:'. 0,22 -suoD,,...: 5418,$:;' 1.5 . __ a.'l ~ ~ /'"_,' 0 i, -.,.,o~,25 5'.a."5-~,~,~ z~v,~5 9,2,; ..,.,~.:.., 3b *.',224 · t' ?.,:,~, 5'4 0 ,2-'.', -..:. 05.'_;,: 0 ::'. .5494, .,.._.=~ 248,""¢: ,-.~. c-:. 1S2,4 4935.u~^n !83,9 4~7,70 1~2,5 5035,S0 -. .... 5z05 18!,4 5252,72 .~.,3 SiOn,07 10601,76 i0779,88 - 11131 ~ 11775,59 72,39 74 =' 20 75,08 ' ~ . , - . 75,47 248.66 75,02- 246,39 74,~7 244,6~ 72,77 245,!~ -1£26,w ,,.~ _ -7557,r~` gllO,17 ~,,.,.7 5362,84 12122,31 92.4 539~.=~ !220¢,22 5473,351~¢/¢,I5 ~v,O 5515,38 ;12454,71 5'0,5' s~C5,71.. .~..,. 245,~~.~ ~5,17 247,20 62,65 246'~6 ~i,67 248,4~ ~x ~a -3071,50" -78?4,44 S470.9! ...... ~ "' .... ,54 -332~,5~ -3569,59 5i93.6~ -,.,~,,15 -3832,81 -9584,7'7 10601,~5 -c~°',78~,~ -!0050,~3 10778 , ¢0 ' ~ !v,04,04 -3Y58o3S -10215,76 "~ . -4017,A?.. -.v¢...ln~l-li. 11131,46 -4209.27 -ln~12-79 -~27~,~2 -10972.3'0 11775,6? -4~4~,6~ -!1130,01 I!94g.38 24£:7S 246,77 248 248 ,.82- 248,~4 _ 248,84 248,S2 z4,_- ,76 248,7! 248 248,6! 24~:, 5'.;' 248- -4420,52 -1i287,57 12122,3! -d49!,44 -11442,68 '4.~0 -I1518,74 U~7 0,!7 1,14 5,82 0,23 !,!7 £ ' 57 2,75 -4553,75 -11592,38 12454.71 -45~2,43 -11666,69 !253~,97 -,..... - -4[.35,31 '111512,03 ft' U ARCO Alaska, inc. Date' December 26, 1995 Transmittal #' 9310 RETURN TO' ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 2T-27 r 2T-32 ,~¢-- ~,f ~2T-32 2T-30 2V-06 2%31 ~2T-36 %~2T-36 T-38 T-38 2T-37 1 Q-24 1 Q-26 1Q-23 CDR 04/17/95 REF #50-103-20217 CDN 04/30/95 REF #50-103-20218-00 CDR 04/30/95 REF #50-103-20218-00 CDR 05/12/95 REF #50-103-20219-00 TDTP 06/11/95 REF #95219 CDR 0713/95 REF #50-103-20226-00 CDR 07/25/95 REF #50-103-20228-00 CDN 07/25/95 REF #50-103-20228-00 CDR 08/03/95 REF #50-103-20229-00 CDN 08/03/95 REF #50-103-20229-00 CDR 08/10/95 REF #50-103-20227-00 ARC5 Array Resistivity Comp. 08/30/95 4206-7270 ARC5 Array Resistivity Comp. 09/22/95 3820-7010 ARC5 Array Resistivity Comp. 09/30/95 5156-9982 Acknowledged: Date' DISTRIBUTION' Mr. Vernon E. Pringte Jr. DeGIoyler and MacNaughton One Energy Square Dallas, TX 75206 Erickson/Zuspan NSK Central Files NSK 69 Sharon AIIsup-Drake DS Development ATO - 1205 Larry Grant _ AOGCC 3001 Porcupine Drive Anchorage, AK 99501: '-" ;-C ;- i ",i cU Gas Cons. u~.-.,~ .... Ancnor-,sge Clifton Posey Geology ATO - 1251 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9830 Company: 10/20/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape 2T-36 ~'.~,,-1(3"Z.--- 95269 CDPJCDN i~_~ ~(~. 950725 I I 1 2T-37 'q ,~""'-I~1 95310 ~ ~ , 950810 I 1 1 2T-31 ~-~ 95255 ~ ~-/~ ~'~ ~ , ' 1950713 1 1 1 ,, ......... , , SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ii': !'-:!:_. 1!,/!--. ARCO Alaska, Inc. Date: August 25, 1995 Transmittal #: 9291 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Records Clerk ATe- 1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following items. return one signed copy of this transmittal. 2A-18-~ Directional Survey 5/18/95 ~~-22 ~.~:- 0 G (~ Directional Survey 5/19/95 . Survey t9~ ...... "~ ~' ~ '~-¥ Date: Please acknowledge receipt and Directional Survey Directional Survey Directional Receipt Acknowledged: ?' / ~. .. '""') ./ ,, 6/23/95 6/9/95 Directional Survey 7/2/95 Directional Survey 5/31/95 Directional Survey 7/11/95 AK7621 AK8213 AK8173 AK8237 AK9229 AK8157 AK8181 AK8253 Mr. Vernon E. Pringle, Jr. DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 '?Earry Grant (2 copies), /~3333 3001 Porcupine Dr. Anchorage, AK 99501 ALASKA OIL AND GAS .'CONSERVATION COMMISSION TONY KNOWLES, GOVEFINOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (90?) 279-1433 FAX: (907) 276-7542 July 1 t, 1995 Michael Zanghi, Drill Site Develop. Supv. ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2T-36 ARCO Alaska, Inc. -' Permit No 95-102 Surf Loc 15'FsL, 556'FWL, Sec 1, T11N, R8E, UM Btmhole Loc 381'FSL, 1402'FEL, Sec 9, T11N, R8E, UM Dear Mr Zanghi: 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. ', Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness lhe test. Notice may be given by contacting the Commission pelroleum field inspector 659-3607. · Chairm~.,..... '~ ! _~'-.~ BY ORDER O MMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSi,.., PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill ~] 1 b Type of Well Exploratory D Stratigraphic Test ~] Development Oil X Re-Entry r-~ Deepen D Service [~ Development Gas r~ Single Zone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 81' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25568, ALK 2666 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 15' FSL, 556' FWL, Sec. 1, T11N, ReE, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 526' FSL, 1005' FEL, Sec. 9, T11N, ReE, UM 2T-36 #U-630610 At total depth 9. Approximate spud date Amount 381' FSL, 1402' FEL, Sec. 9, T11N, ReE, UM 7/20/95 $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 2T-15 15795' MD 526 ~ TD feet 12.0' @ 240' MD feet 2560 6237' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 600' feet Maximum hole angle 74.8° Maximum surface 1 71 7 psig At total depth (I'VD) 31 50 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD -I'VD MD · TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 BTC 4791' 41' 41' 4832' 2900' 840 Sx Arcticset III & HF-ERW 880 Sx Class G 8.5" 7" 26.0# L-80 BTCMO£ 15754 41' 41' 15795' 6237' 250SxClassG . HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Sc~r~(~tu~rta°lrR E ¢ E IV E D Surface Intermediate .... Production Linerd U L 0 6 1995 Perforation depth: measured j~,~, [iii & Gas Cons. C0_m~issl0_l~ true vertical '"~-..t ~C[I]0r~,.~.il-~ ; 20. Attachments Filing fee X Property plat [-I BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot D Refraction analysis [~ Seabed report D 20 AAC 25.050 requirements X 21. ~1 hereby certify that the~,foregoing is true and correct to the best of my knowledge S[gnedY[~/~/~M ~l,~[/~.~k~"-'' '~ -~ ~[~/[. ,~ ~J~ ~' T, tle' e ' Drill Site Develop. Supv. Date '~/~3/~' ~ !~ -- ~/ Commission Use Only Permit~lumber. I APl ~afnber m Approval date ..,, j letter for ¥~'--/~,~ I ~o-lo.Z-- ~~ ~ I ~'/./-~"' ISee c°ver other re(~uirements Conditions of approval Samples required D Yes ~' No Mud log required ~] Yes [] No Hydrogen sulfide measures ~' Yes r-~ No DirecUonal survey required [] Yes [~ No Required working pressure foraOPE ~--I 2M ~ 3M D 5M D 10a D 15M Other: Original Signed By David W. Johnston byorder of Approved by Commissioner the commission Date -~ '~/,/ ~ ~ Form 10-401 Rev. 7-24-89 Submit in triolicate GENERAL DRIllING PROCEDURE KUPARUK RIVER FIELD 2T-36 , , , 10. 11. 12. 13. 14. 15. 16. 17. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (4,832')according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (15,795') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU master valve and upper tree assembly. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" casing to 3500 psi. Run cased hole cement bond log. Perforate and run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED ,itli 06 1995 Aisska Oil & Gas Cons. Commission Anchors DRILLING FLUID PROGRAM Well 2T-36 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 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% Drilling 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 Notes: Weight up to TD 10.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% 0il E Gas Cons. Commission Anchor~ ,~' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1,717 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2T-36 is 2T-15. As designed, the minimum distance between the two wells would be 12.0' @ 240' MD. Annular Pumping Activities: 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 well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2T-36 surface/production casing annulus will be filled with diesel after setting 7" and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface. It is requested that 2T-36 be permitted for annular pumping occurring as a result of the drilling project on DS 2T, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. Surface casing will be set in the thick continuous shales below the base of the West Sak Sands. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Drilling Area Risks- Risks in the 2T-36 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. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 10.8 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. J JL 0 6 995 ~ask~ Oil .& Gas Cons. Commission Created by: Wolly H. For: D. PETRASH Date plotted : 5-Jul-95 Plot Reference is 36 Version #5. Coordinates ore in feet reference slot #36. True Vertical Depths are reference RKB . Baker Hughes INTEQ --- ARCO ALASKA, Structure : Pad 2T Well: 36 Field : Kuparuk River Unit Location : North Slope, Alaska < ~ ~ West Scale 1 : 400.00 8OO _ _ 1600 2400_ 3200_ 4000 _ 5600_ 12800 12000 11200 10400 9600 8800 8000 7200 64-00 5600 4800 4000 3200 2400 1600 800 0 TD LOCATION: 581' FSL & 1402' FEL SEC.g-T11N-R8E 250' RADIUS TARGET SURFACE LOCATION: 14.5' FSL & 556' FWL SEC. 1 -T11N-R8E ESTIMATED RKB ELEVATION: 125' TARGET LOCATION: 526' FSL & 1005' FEL SEC.9-T1 1 N-R8E S 68.57 DEG W 1,5021' (TO TARGET) o 8oo g _ 1600 0 _ (- _2400 ~ _3200 J - I _4000 V _4800 5600 ,5 O0 KO~ 'iVD=6~O TMD=§O0 DEP=O 9100 % 33.00T/ U6~ SNDS ~=1~ ~D=1592 OEP=252 ~ ~ ~ ~ ~ m- j j % 39.00 X~Woo .... _ v ~K-lO ~=5~O~3D~=5~e~ ..... ~]AVIkJIIkJ AKI~/C ~ - ~4.76 DEG TARGET ANGLE 60 D E G .~,. ~ ~.o. ~=~o. ,.,=,~o~ B / HRZ ~-5729 ~D-14992 D~-12825 ~8~0~ TARGET -T/ ZONE C (EOB) TVD=5879 TMD=15238 DEP=13021 T / ZONE A ~=5g05 ~B=15278 DEP=~52 T / ~ SNDS B / KUP SNDS ~--~18 ~0-15454 D~--13186 ~ / 7" CSG PT ~=6257 TMD=15795 DEP=I5447 J , , , , , , , ~ , , , , ~ ~ , , ~ ~ ~ ~ , , ~ , , , , , , , , , , , 0 800 1600 2400 3200 4000 4800 5600 6400 7200 8000 8800 9600 10400 11200 12000 12800 13600 Scale 1 · 400,00 Vertical Section on 248.57 azimuth with reference 0.00 N, 0.00 E from slot #,56 Created By: Wally H. Date plotted : 5-Ju1-95 Plot Reference is Version #5 Coordinates are in feet reference slot ~56. True Vertical Depths are reference wellhead. --- Baker Hughes INTEQ --- ARCO ALASKA, Sfrucfure : Pod 2T Well: 56 Field : Kuporuk River Unif Locofion : North Slope, Alosko Wesf scole 1. lO.OO ,320 ,300 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 ,--c~O0 140 l .. 120 '-~ 100 8O I I I I I I I I I I I I I I :100 140 120 o 100 0 6O 2O ~o0 1400 1600 1100 1200 13oo 2O o U') 20 (~ 40 I 6O 100 120 140 160 _ _ 180 _ _ 200 _ 220 6oI I ...%~o ~ooo 1 O0 ~_ 120 9oo _ 140 _ RECEIVED . . _ 180 ~ooo ,Ifil 0 6 1995 _ AlaSka Oil & Gas Cons. Commission _ 200 220 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 II I .320 300 280 260 240 220 200 180 160 140 120 1 O0 80 60 40 20 0 20 <-= Wesf Scole 1 ·10.00 I I V 0 0 iCreated By: 'dally H. iDote plotted : 5-Jul-95 !Plot Reference is Version #5 iCoordinates ore in feet reference slot !True Vertical Depths are reference wellhead. I --- 9aker Hughes INTEQ --- ARCO ALASKA Structure : Pod 2T Well: 36 Field : Kuparuk River Unit Location : North Slope, Alaska <-- West Scale 1' 20.00 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 .360 ,320 :80 160 I I I I I I I I I I I I I I t I I I I I I I I I I I I I I I I I I 160 120 _ 80 ..~.~ 0 _ _ oo_ ,~oi --o~x~% ~ 560 ~ I I I I I I I I I I I I [ I I I I I I I I I I I I I I I i I I I I 560 960 920 880 840 800 760 720 680 640 600 560 520 480 440 400 360 320 280 < West soo,~ ~ . ~o.oo _ 120 .. _ 0 _ 80 © I I V KUPARUK RIVER UN.. 20" DIVERTER SCHEMATIC 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. 1. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25,035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSUREOF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11~4 i 7 1 i I 5 4 13 5/8" 5000 Pi_ BOP STACK ACCtlJM ULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. J ! BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. ?_ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINLrrES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6x CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, UNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSi HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO3-1'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND MNES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING PosmON. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD ?_ 11" - 3000 PSI CASING HEAD 3. 11" - 3(XX) PSI X 1:~5/8" - 50(X) PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8"-5000 PSI DRLG SPCX3LW/ CHOKE AND KILL UNES ~ 13~5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED L 0 6 1995 Gas Cons. Commission WELL PERMIT CHECKLIST WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] aery [] oN oF ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate. ' 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary. 6. Well located proper distance from ~ther wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERIN~ 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pi% ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved.~-Y----N 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate ..................... 26~ BOPE press rating adequate; test to ~O psig~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis 9f shallow gas zones .......... / N 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports . . ./ . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISS ION: Comments/Instructions: TAB Z HOW/jo - A:~FORMS~cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organiZe this category of information. ALASKA COMPUTING CENTER SCHLUMBERGER ....... COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 2T-$6 FIELD NAME : KUPARUK RIVER BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-103-20228-00 REFERENCE NO : 95269 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-0CT-1995 16:32 **** REEL HEADER **** SERVICE NAME : EDIT DATE : 95/1~/17 ORIGIN : FLIC REEL NAME : 95269 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-36, API #5~-103-20228-00 **** TAPE HEADER SERVICE NAME : EDIT DATE : 95/10/17 ORIGIN : FLIC TAPE NAME : 95269 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-36, API #se-~o3-2e228-~ TAPE HEADER KUPARUK RIVER MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA 2T-36 501032022800 ARCO ALASKA, INC. SCHLUMBERGER WELL SERVICES 17-0CT-95 BIT RUN I BIT RUN 2 BIT RUN 3 JOB NUMBER: 95269 LOGGING ENGINEER: RUMINER OPERATOR WITNESS: MORRISON SURFACE LOCATION SECTION: TOWNSHIP: RANGE: 8E FNL: FSL: 15 FEL: 556 FWL: ELEVATION(FT FROM MSL KELLY BUSHING: 122.00 DERRICK FLOOR: 122.00 GROUND LEVEL: 80.50 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) lST STRING 8.5e0 9.875 4802.0 2ND STRING PAGE: LIS Tape Verification List|n9 Schlumberger Alaska Computing Center 17-OCT-199S 16:32 3RD STRING PRODUCTION STRING REMARKS: Well drilled 22-JUL through 25-JUL-9S with CDR & CDN. All data was collected in a single bit run with a short MAD pass. $ $ **** FILE HEADER ~*** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : 00itel DATE : 95/10/~7 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: e.sooe FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MWD 5432.0 1547[.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) ,EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE BIT RUN NO. MERGE TOP MERGE BASE CDR MAD I 5432.e 5642.0 CDR MWD I 13464.0 15471.0 CDN MWD 1 13390.0 15356.0 $ REMARKS: No depth adjustments were made as per Dave Sharer of ARCO. This file also contains the Very Enhanced QRO resisitivit¥ with 2~ average that was reprocessed at GeoQuest. FET CURVE DOES NOT EXIST OVER THE UPPER MAD PASS. $ LIS FORMAT DATA PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-0CT-1995 16:32 PAGE: DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 NAME DEPT RA RP VRA VRP DER ROP GR FET RHOB DRHO PEF CALN NPHI SET TYPE - CHAN ** SERV UNIT SERVICE AP1 AP1 AP1 AP1 FILE NUMB NUMB SIZE REPR ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE FT 548224 00 ~00 00 0 1 ! 1 4 68 MWD OHMM 548224 00 000 00 0 1 1 1 4 68 MWD OHMM 548224 00 000 00 0 1 1 I 4 68 MWD OHMM 548224 00 000 00 0 1 1 1 4 68 MWD OHMM 548224 00 000 Oe 0 1 1 1 4 68 MWD OHMM 548224 eO 000 00 0 I 1 1 4 68 MWD FPHR 548224 00 090 9~ 0 1 1 1 4 68 MWD GAPI 548224 99 999 90 9 I I I 4 68 MWD HR 548224 99 999 99 9 1 1 1 4 68 MWD G/C3 548224 99 999 99 9 1 1 I 4 68 MWD G/C3 548224 90 999 99 9 1 1 1 4 68 MWD BN/E 548224 99 9e9 99 0 ~ 1 1 4 68 MWD IN 548224 99 999 99 9 1 I 1 4 68 MWD PU-S 548224 99 999 99 9 1 1 1 4 68 PROCESS (HEX) DATA DEPT. VRP.MWD FET,MWD CALN.MWD 15471.599 -999.259 -999.259 -999.259 RA.MWD DER.MWD RHOB.MWD NPHI.MWD -999.259 -999.250 -999.250 -999.259 RP.MWD ROP.MWD DRHO.MWD -999.259 119.185 -999.259 VRA.MWD GR.MWD PEF.MWD -999.259 -999.250 -999.259 LIS Tape Verification Listing Schlumberger Alaska Computing Center 17-0CT-1995 16:32 PAGE: DEPT. 5432.900 RA.MWD -999.259 RP.MWD -999.259 VRA.MWD VRP.MWD -999.259 DER.MWD -999.259 ROP.MWD -999.259 GR.MWD FET.MWD -999,259 RHOB.MWD -999,259 DRHO.MWD -999.259 PEF.MWD CALN.MWD -999.259 NPHI.MWD -999.259 -999.259 89.291 -999.259 END OF DATA **** FILE TRAILER **** FILE NAME : EDIT .991 SERVICE : FLIC VERSION : 991Cel DATE : 95/le/17 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER FILE NAME : EDIT .002 SERVICE : FLIC VERSION ,: 9elcgi DATE : 95/10/17 MAX EEC SIZE : le24 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and clipped curves; all MAD runs merged using earliest passes. DEPTH INCREMENT: 9.5ege FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH MAD $ MERGED DATA SOURCE LDWG TOOL CODE 5442.9 5594.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE $ REMARKS: No depth adjustments were made as per Dave Sharer of ARCO. This file also contains the Very Enhanced QRO resisitivit¥ with 2' average that was reprocessed at Geoquest. This MAD pass includes CDR data onl¥~ BUT DOES NOT INCLUDE THE FET CURVE. LIS Tape Ver|f|catlon L|st|ng Schlumberger Alaska Comput|ng Center $ LIS FORMAT DATA 17-0CT-[995 [6:32 PAGE: 5 DATA FORMAT SPECIFICATION RECORD SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 32 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 1[ 66 32 [2 ,68 13 66 0 14 65 FT 15 66 68 16 66 0 66 SET TYPE - CHAN ** NAME SERV UNIT SERVICE. API API AP1 API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548224 ~e 000 eO 0 2 1 I 4 RA MAD OHMM 548224 ~e 0e0 ~0 0 2 1 1 4 RP MAD OHMM 548224 00 0~0 00 0 2 [ [ 4 VRA MAD OHMM 548224 00 0e0 ~0 0 2 1 1 4 VRP MAD OHMM 548224 0~ 000 0~ 0 2 [ 1 4 DER MAD OHMM 548224 00 000 eO 0 2 [ 1 4 ROP MAD FPHR 548224 00 000 00 e 2 1 [ 4 GR MAD GAPI 548224 eO 000 00 0 2 [ [ 4 ** DATA ** DEPT. 5642.500 RA.MAD VRP.MAD -999.250 DER.MAD -999.250 RP.MAD -999.250 ROP.MAD -999.250 VRA.MAD 1268.606 GR.MAD -999.250 -999.250 END OF DATA LIS Tape Verificat|on List|n9 Schlumberger Alaska Computing Center [7-0¢T-1995 [6:32 **** FILE TRAILER FILE NAME : EDIT .e~2 SERVICE : FLIC VERSION : O~lCO1 DATE : 95/10/[7 MAX REC SIZE : [024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 95/10/17 ORIGIN : FLIC TAPE NAME : 9526g CONTINUATION ~ : [ PREVIOUS TAPE : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-36, API #50-[03-20228-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 95/10/17 ORIGIN : FLIC REEL NAME ': 95269 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA, INC., KUPARUK 2T-36, API ~se-le3-20228-00 PAGE:
