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185-273
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 26, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Brian Bixby P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3F-12 KUPARUK RIV UNIT 3F-12 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/26/2023 3F-12 50-029-21483-00-00 185-273-0 W SPT 5657 1852730 1500 2795 2796 2799 2799 600 700 700 700 4YRTST P Brian Bixby 6/4/2023 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 3F-12 Inspection Date: Tubing OA Packer Depth 875 2010 1960 1950IA 45 Min 60 Min Rel Insp Num: Insp Num:mitBDB230607083103 BBL Pumped:1.1 BBL Returned:1.1 Wednesday, July 26, 2023 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 12, 2019 TO: Jim Regg P.I. Supervisor (� SUBJECT: Mechanical Integrity Tests CONOCOPHR-LIPS ALASKA, INC. 3F-12 FROM: Guy Cook KUPARUK RIV UNIT 3F-12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry -Tg!Z NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-12 Insp Num: mitODC190608155817 Rel Insp Num: API Well Number 50-029-21483-00-00 Inspector Name: Guy Cook Permit Number: 185-273-0 Inspection Date: 6/6/2019 - Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well I 3F -I2 Type Inj I W 'TVD s6n Tubin zo9z zoss zoea - 2093 -�-J - gl _ PTD 1ssn3o ype Test sPT Test psi 1500 - IA 630 2720 aao 2680 BBL Pumped: I -BBL Returned: 09 - OA szo _ 640 eao aso - ��- Intervall 4YRTST P/F P Notes: Job was completed with a Little Red Services pump truck and calibrated gauges. Wednesday, June 12, 2019 Page 1 of I 18 52 3036® Con©coPhillips TRANSMITTAL FEB 11 2119 FROM: Sandra D. Lemke, ATO -704 TO: Abby Bell ���°�;' ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 222 W. Th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: 3F-12 DATE: 02/11/2019 Transmitted: CC: 3F-12 - e -transmittal well folder Receipt: Date: Alaska/IT-GGREI CoQcoPhllljps Alaska I Office: 907.265.6947, Mobile 907 440 4512 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 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 r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD to WAG 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Explorator r 185-2730 3.Address: 6.API Number Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-029-21483-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643, 25632 KRU 3F-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7571 feet Plugs(measured) None true vertical 6095 feet Junk(measured) None Effective Depth measured 7374 feet Packer(measured) 6996 true vertical 5944 feet (true vertical) 5657 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 3255' 9 5/8 3292' 3033' PRODUCTION 7505' 7 7540' 6071' LINER 435' 41/2 7426' 5983' RECEIVED JAN 1 1 2017 Perforation depth: Measured depth: 7243-7250 True Vertical Depth: 5844-5849 fOG C Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 7036 MD, 5808 TVD Packers&SSSV(type,MD,and TVD) NIPPLE=CAMCO DS NIPPLE NO GO @ 491 MD and 491 ND SEAL ASSY= BAKER 80/40 SEAL ASSEMBLY W/7 FT SPACE OUT @ 6996 MD and 5657 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): +� Treatment descriptions including volumes used and final pressure: S�RN6�ED AF' 1 ZU�7. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation 3155 1200 1239 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ' Exploratory r Development r Service Stratigraphic r Copies of Logs and Surveys Run 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r 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: 316-622 Contact Scott Pessetto Email: scott.t.pessettoa,cop.com Printed Name Scott Pessetto Title: Petroleum Engineer Signature ✓ Phone:263-4146 Date V / 10/ 1 t71 I - - r Vri- 31251 17 Form 10-404 Revised 5/2015 � 07 Submit Original Only RBDMS �L, JAN 1 5 1017 • • 3F-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/14/16 PUMP 2OBBL METH DOWN FL AND TBG 12/27/16 Open well to injection service 01/08/17 (ISW) INITIAL STATE WITNESSED (Chuck Scheve) MITIA PASSED TO 2080 PSI • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday,January 10,2017 TO: Jim Regg P.I.Supervisor i(17--1 I 7SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-12 FROM: Chuck Scheve KUPARUK RIV UNIT 3F-12 Petroleum Inspector Src: Inspector Reviewed ByF:� P.I.Supry 312- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3F-12 API Well Number 50-029-21483-00-00 Inspector Name: Chuck Scheve Permit Number: 185-273-0 Inspection Date: 1/8/2017 Insp Num: mitCS170109062101 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3F-12 ` Type Inj W" TVD 5657 - Tubing 1332 1330 - 1330 - 1329 - PTD 1852730 Type Testi SPT Test psi 1500 - IA 460 2080 - 2030 - 2020 -T BBL Pumped: BBL Returned: OA 650 800 • 800 - 800 - Interval INITAL P/F P Notes: test performed post rig workover. - � b SPR 4J Tuesday,January 10,2017 Page 1 of 1 • • yOF TB • ,b,\ �yyy��� THE STATE Alaska Oil and Gas of/\ T /� }( /� Conservation Commission 111.�1-1� X1`1 333 West Seventh Avenue 1011-11w,., GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 1. Main: 907.279.1433 OF ALAS'0 Fax: 907.276.7542 www.aogcc.alaska.gov Scott Pessetto Petroleum Engineer MAR 3 o 2097; ConocoPhillips Alaska, Inc. SCANNED P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3F-12 Permit to Drill Number: 185-273 Sundry Number: 316-622 Dear Mr. Pessetto: 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, Cgezo Cath P. Foerster Chair DATED this 2/ day of December, 2016. RDDMS LA-DEC 2 2 2016 • S RECEIVED • STATE OF ALASKA DEC 1 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION I Z i ZQ 11 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well r Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing E Change Approved Program r Plug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other PROD to WAG Iq• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory r Development p- 185-2730 \ 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage, Alaska 99510 50-029-21483-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NA Will planned perforations require spacing exception? Yes r No '/ KRU 3F-12 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25643,25632 • 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): 7571 ' 6095 ' 7374' • 5944' . 3000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 3255' 9 5/8 3292' 3033' PRODUCTION 7505' 7 7540' 6071' LINER 435' 41/2 7426' 5983' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7243-7250 . 5844-5849 3 1/2 L-80 7036 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) SSSV=NONE PACKER=2RH ZXP PACKER w/HD Liner Top Packer • MD=6990 TVD=5653 12.Attachments: proposal Summary J7 WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service f✓ , 14.Estimated Date for 15. Well Status after proposed work: 1 2/1 8/1 6 Commencing Operations: OIL r WIND rgpL r Suspended r 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: Scott Pessetto Printed Name Scott Pessetto Phone:263-4146 Email: SCOtt.t.pessetto(c�cop.com Title: Petroleum Engineer Signature �---_'t-- Date: it/I4/',LO1 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ` – 2 Ca Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: Ease:- I-z- (z(:;, ( ) b Post Initial Injection MIT Req'd? Yes rr No r Spacing Exception Required? Yes r Norifir NaSubsequent Form Required: /f— 4 O ,/�� APPROVED BY Approved by: A5 �7��i—'„_`" COMMISSIONER THE COMMISSION Date:� 2 -Z/_ VTL /7/2 es//4, iK� 1.21(f/1s. /70/ Submit Form and Form 10-403 Revised 11/2015 (:) via i Id or 12 months from the date of approval. Attachments in Duplicate RDDMIS v/ (, DEC 2 2 2016 • 3F-12 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 3F-12 and its associated laterals L1, L1- 01, L1-02, L1-03(PTD# 185-2730, 216-0580, 216-0590, 216-0600, 216-0610)from Oil Production service to Water Alternating Gas Injection service as the pre-production period has been completed. Area of Review: Kuparuk well 3F-12 and its associated laterals was completed as an injector on 9/30/16 to provide enhanced recove i into the reservoir to increase the ultimate recovery of oil. This well wi support existing producers 3F-17, 3G-06, and 3G-08. The top of the A sand was found at 7231' MD/5835 TVD Area Map with 1/4 mile radius around target injection zone (see attached): The map attached shows that,with the exception of the offset injector 3F-15, there are no production/injection wells located within a 1/4 mile radius of the 3F-12, 3F-12L1, 3F-12L1-01, 3F-12L1-02, 3F-12L1-03 penetrations of the Kuparuk interval. Mechanical Condition of Well to be Converted: The mechanical condition of Kuparuk well 3F-12 and its associated laterals is good and is classified as a"CTD horizontal quad-lateral"well. The injection tubing/casing annulus is isolated via a Baker ZXP packer located at 6990' MD (5653'TVD). A State-witnessed MIT-IA will be performed once well 3F-12 is converted to water injection, online, and stabilized. CBL and interpretation of the cement quality: See attached AOR Detail The 4-1/2" liner was cemented in place with 97 sx of class"G"cement. The 16" Conductor was cemented with 316 sx AS II. The 9-5/8" Surface casing was cemented with 925 sx PF'E' and 410 sx PF 'C'. The 7" Production casing was cemented with 150 sx Class"G"and 175 sx PF"C". fel/1.<w cr y P f erft /Id � a w9 fefr3 fQ 2/i9 /6� • 1111 a v o a g5 0 .,,L. t ,- ,12 _ 2 s' ! . :a i o 3a 3a 3"' w 3u x 3� - r'v o�._ `w ,'. ,t s 3 E `m u° 'G'` '" c 3 p ^+ 3 r 3 �'n 3 u H io 3 1 3" G 3 E _ c c c F c w u n w w 4, w p m E m w p E T5_. 8 o u a 0 o vn o— A i H m � �ti 4b7i go z a w >> c m T " E v LL u G a ItN a g V O _ H O 9 N c 0 a N O O . H "2/3 N Q Od '8:i n r O 28 R r t I:1 L' z 3 m ,L1-, `a ADL025632 • ADL025547 3p-is 3F 3F-12L1-0` 3F-12L1 1‘) 3F-12L1-03 3F-12 3F-12L1-02 T1iNR8E 30 ADL 25548 T12NR9E ADL025643 Well Pad Wells within Radii 3F-12 Open Interval -3F-12L1 Open Interval Kuparuk PA ammo 3F-12L1-01 Open Interval — — — — — — — — — — — — 3F-12L1-02 Open Interval Tabasco PA mono 3F-12L1-03 Open Interval ConocoPhillips 1/4 Mile Radius 3F-12 1 N 1/4 Mile Radius 3F-12L1 Alaska,Inc. 1/4 Mile Radius 3F-12L1-01 ' A Injection SwapAnalysis Feet y 1/4 Mile Radius 3F-12L1-023F-12 Wells 0 500 1,000 i 1/4 Mile Radius 3F-12L1-03 Date: 12/15/2016 Document Path:\\conoco.net\ak_shared\ANC\Longterm\GKA Geoscience\geotech_projects\GKA Wells\3F_12\well_3F_12_map_new.mxd KUP INJ 0 3F-12 - ConocoPhillips 01 Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) crnoc ..,, 500292148300 KUPARUK RIVER UNIT INJ 49.66 3,400.00 7,571.0 1 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3F-13 10/13/20169.36:31 AM SSSV:NIPPLE Last WO: 10/20/1996 41.88 12/12/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation 'Last Mod By End Date ................................. Last Tag:SLM 7,293.0 4/15/2016 Rev Reason:ADD LATERALS lehallf 10/11/2016 HANGER;32.7 Iti al Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED _ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 37.0 3,292.4 3,032.6 36.00 J-55 BTC Casing Description OD(ie) ID(ie) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,539.9 6,070.9 26.00 J-55 BTC v,Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread II II LINER 41/2 3.958 6,990.9 7,425.5 5,983.2 12.60 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) CONDUCTOR;38.0.115.0---A 6,990.9 5,653.3 41.06 PACKER 2RH ZXP W/HD liner top packer 4.300 7,010.5 5,668.1 41.09 HANGER DG Flex lock liner hanger 4.200 7,025.6 5,679.4 41.03 SBE Baker 80/40 SBE 5"Tell X 4.5"BTC 4.000 7,338.0 5.916.3 40.37 COLLAR Baker type 1 landing collar 3.950 7,380.7 5,948.9 40.11 COLLAR Baker Float collar 3.938 SURFACE;37.0-3,292.4 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(lb/ft) Grade Top Connection TUBING 3.5 L-80 3 1/2 2.992 32.6 7,036.4 5,687.6 9.30 L-80 SUE 8rd EUE 8rd GAS LIFT;6.884.6 IIIL NIPPLE 6,9456 Completion Details I Nominal ID Top(566) Top(ND)(ftKB) Top Incl(°) Item Des Corn (in) 32.6 6,945.6 32.6 0.04 HANGER 7 1/16"X 3.5 SUE 8rd hanger 3.000 5,619.0 40.64 NIPPLE 3.5"X 2.813 X nipple 2.813 6,995.2 5,656.5 41.10 LOCATOR Locator sub 2.990 ® 6,996.4 5,657.4 41.11 SEAL ASSY Baker 80/40 seal assembly W/7 Ft space out 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) Cl Des Com Run Date ID(in) 7,179.0 5,795.6 40.66 WHIPSTOCK BAKER GEN II 4.5"WHIPSTOCK WITH TOP OF 4/2/2016 TRAY at 7,179.SET 24 DEG ROHS.RA TAG AT 7,186.5' IMI Perforations&Slots LOCATOR,6,995.2 Shot Dens M. -: Top(ND) Btm(TVD) (shotstt 11=11 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com SEAL ASSY;6,996.4 5 Mk 11 7,116.0 7,146.0 5,747.8 5,770.6 C-4,C-1, 1/24/1986 12.0 IPERF 120 deg.phasing;5"HJ UNIT B,3F-12 II Csg Gun 4 II Il 7,243.0 7,250.0 5,844.2 5,849.5 A-2,3F-12 4/17/2016 6.0 APERF 'w/2.5"and 60 Deg ,I.I, Millenium II Charges _ ) l' 7,246.0 7,280.0 5,846.4' 5,872.3 A-2,3F-12 1/24/1986 4.0 IPERF 90 deg.phasing;4"HJ IICsg Gun Mandrel Inserts • St ai IPERF;7,1160-7,146.0- on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type _ (in) (psi) Run Date Com 1 6,884.6 5,572.5 Camco MMG 1 1/2'GAS LIFT DMY RK 0.000' 0.0 4/15/2016 • • Notes:General&Safety End Date Annotation R g 10/20/1996 NOTE:WORKOVER LEFT PORTION OF ORIGINAL TBG STRING 6991'to 7196' Ia !a 11/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;7,162.0-9,400.0-- y LINER,L1-03;7,161.7-9,400.04/2/2016 4/2/2016 NOTE:Cleaned out to 7429 R. WHIPSTOCK;7.179.0 10/13/2016 Note:on 4/14/16 CDR reperfed from 7243'-7250'to allow pressure monitoring. 10/13/2016 NOTE:All Perforations except from 7243'-7250'behind 41/2"cemented liner for CTD set up g 91 APERF;7.243.0.7,250.0- g - g IPERF;7,246.0-7280.0- , Liner Cement;6.991.0 ftKB ' LINER;6,990.9-7,425.5 • 1 PRODUCTION;35.0-7.539.9 STATE OF ALASKA AL KA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Plug 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 E Plug for Redrill E Perforate New Pool r Repair Well r Re-enter Susp Well r Other: PROD>30 days 7 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 185-2730 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage, Alaska 99510 50-029-21483-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643, ALK 2574 KRU 3F-12 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7571 feet Plugs(measured) None true vertical 6095 feet Junk(measured) None Effective Depth measured 7411 feet Packer(measured) 6946, 6996, 7179 true vertical 5972 feet (true vertical) 5619, 5657, 5796 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77' 16 115' 115' SURFACE 3255' 9 5/8 3292' 3033' PRODUCTION 7505' 7 7540' 6071' LINER 435' 41/2 7426' 5983' RECEIVED NOV 08 2016 Perforation depth: Measured depth: 7116-7146, 7246-7280 True Vertical Depth: 5747-5770, 5846-5872 Tubing(size,grade,MD,and TVD) 2 7/8 ,J-55, 7195 MD, 5808 TVD Packers&SSSV(type,MD,and TVD) SSSV=NIPPLE CAMCO DS NIPPLE NO GO @ 491 MD and 491 ND NIPPLE=3.5"X 2.813 X NIPPLE ©6946 MD and 5619 ND SEAL ASSY= BAKER 80/40 SEAL ASSEMBLY W/7 FT SPACE OUT @ 6996 MD and 5657 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED tvw�� F� I E Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 0 0 Subsequent to operation 340 1403 3011 1350 282 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F Gas E WDSPL r Printed and Electronic Fracture Stimulation Data E GSTOR r WINJ r WAG E GINJ r SUSP r SPLUG E 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: N/A Contact Darrell Humphrey Email: n1139@conocophillips.com Printed Name Darrell Humphrey Title: NSK Production Engineering Specialist Signature 4RG/, ��� kgrL Phone:659-7535 Date I / _ s,.......s,....... ` t Form 10-404 Revised 5/Z015Zf f� Submit Original Only ,, 4/> r / RBDMS w Nov 1 0 2016 • • 3F-12 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/07/16 Convert to Producer(pre- produced water injector for> 30 days) KUP INJ • 3F-12 ConocoPhillips Ori Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ,-�oco,,,," 500292148300 KUPARUK RIVER UNIT INJ 49.66 3,400.00 7,571.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 3F-12,10/13120169:36'.31 AM SSSV:NIPPLE Last WO: 10/20/1996 41.88 12/12/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,293.0 4/15/2016 Rev Reason:ADD LATERALS lehallf 10/11/2016 HANGER;32.7 ILS tL Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 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 SURFACE 9 5/8 8.921 37.0 3,292.4 3,032.6 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,539.9 6,070.9 26.00 J-55 BTC """""zauxa utuni uanwaroxi "••imams I LOBOMraok Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ILINER 41/2 3.958 6,990.9 7,425.5 5,983.2 12.60 L-80 BTC Liner Details MM - 1_,..'°`A'•.".. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) CONDUCTOR;38.0-115.0- . 6,990.9 5,653.3 41.06 PACKER 2RH ZXP W/HD liner top packer 4.300 7,010.5 5,668.1 41.09 HANGER DG Flex lock liner hanger 4.200 7,025.6 5,679.4 41.03 SBE Baker 80/40 SBE 5"TCII X 4.5"BTC 4.000 7,338.0 5,916.3 40.37 COLLAR Baker type 1 landing collar 3.950 7,380.7 5,948.9 40.11 COLLAR Baker Float collar 3.938 SURFACE:37.0-3,202 4 4 Tubing Strings _ Set Depth(TVD)(...Wt(Ibitt) Grade Top Connection Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. fTUBING 3.5 L-80 31/2 2.992 32.6 7,036.4 5,687.61 9.30 L-80 EUE 8rd GAS LIFT;8,884.6 - EUE 8rd Completion Details Nominal ID : Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Cam (in) 32.6 32.6 0.04 HANGER 7 1/16"X 3.5 EUE 8rd hanger 3.000 6,945.6 5,619.0 40.64 NIPPLE 3.5"X 2.813 X nipple 2.813 NIPPLE;8,945.814 6,995.2 5,656.5- 41.10 LOCATOR Locator sub 2.990 6,996.4 5,657.4 41.11 SEAL ASSY Baker 80/40 seal assembly Wl 7 Ft space out 2.990 • Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) - _ Top(TVD) Top Incl Top(ftKB) (ftKB) 7) Des Corn Run Date ID(in) 7,179.0 5,795.6 40.66 WHIPSTOCK BAKER GEN 114.5"WHIPSTOCK WITH TOP OF 4/2/2016 F-- TRAY at 7,179.SET 24 DEG ROHS.RA TAG AT 7,186.5' Perforations&Slots LOCATOR;6,995.2 - Shot Dens Top(TVD) Stet(TVD) (shots/f Top(ftKB) Btm OMB) (ftKB) (ftKB) Zone Date t) Type Com SEAL ASSY;6,99fi.4 l'"- 7,116.0 7,146.0 5,747.8 5,770.6 C-4,C-1, 1/24/1986 12.0 (PERF 120 deg.phasing;5"HJ ` UNIT B,3F-12 II Csg Gun : lirIt 7,243.0 7,250.0 5,844.2 5,849.5 A-2,3F-12 4/17/2016 6.0 APERF w/2.5"and 60 Deg Millenium II Charges 7,246.0 7,280.0 5,846.4 5,872.3 A-2,3F-12 '1/24/1986 4.0 IPERF 90 deg.phasing;4"HJ IICsg Gun ' Mandrel Inserts St ati IPERF;7,116.0-7,146.0- y 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' 6,884.6 5,572.5 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/15/2016 Notes:General&Safety End Date Annotation 10/20/1996 NOTE:WORKOVER LEFT PORTION OF ORIGINAL TBG STRING 6991'to 7196' SLOTS;7,162.0-9,400.0- I I-, 11/9/2010 -NOTE:View Schematic w/Alaska Schemetic9.0 LINER,L1-03;7,161.7-9,400.0- 4/2/2016 NOTE:Cleaned out to 7429 ft. WHIPSTOCK 7,179.0 44 10/13/2016 Note:on 4/14/16 CDR reperfed from 7243'-7250'to allow pressure monitoring. ,L:.:1 10/13/2016 NOTE:All Perforations except from 7243'-7250'behind 41/2"cemented liner for CTD set up -moi APERF;7,243.0-7,250.0 IPERF;7,248.0-7,200.0- ' • Liner Cement;6,991.0 nKB ' II LINER;6,990.9-7,425.5 A IL PRODUCTION;35.0-7,539.9 NAM 17 WELL LOG TRANSMITTAL#903209521 ''*WOO To: Alaska Oil and Gas Conservation Comm. May 9, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 5 V6/204,0 K BENDER RE: Multi Finger Caliper, Bottom Hole Pressure Survey, Perforation Record: 3F-12 Run Date: 4/17/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-12 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-21483-00 Static Bottom Hole Pressure Survey 1 Color Log 50-029-21483-00 My-t--Ck 1—oci ?1.¢.. oQ.k.zr‘o? 1 L.o PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett scp0ED 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: tc65- 2_--13 0 MAY 1 7 niti WELL LOG TRANSMITTAL#903209521 A0000 To: Alaska Oil and Gas Conservation Comm. May 9, 2016 Attn.: Makana Bender GGE 333 West 7th Avenue, Suite 100 5 DATA L i� gicEoD - *-"-- M.K.BENDER Anchorage, Alaska 99501 RE: Whipstock Setting Record: 3F-12 SCANNED �ft Run Date: 4/18/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 3F-12 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-21483-00 Whipstock Setting Record (Field Print) 1 color log 50-029-21483-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ,,agesdzeL, - / ,.eftdi STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon T Plug Perforations 7 Fracture Stimulate 1"'" Pull Tubing F Operations Shutdown Performed: Suspend l Perforate 17 Other Stimulate Alter Casing E Change Approved Program T. Plug for Redrill Perforate New Pool '— Repair Well ;v Re-enter Susp Well E Other: CTD Setup �' 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I— Exploratory T 185-273 3.Address: 6.API Number: Stratigraphic EService P. 0. Box 100360,Anchorage, Alaska 99510 50-029-21483-00 — 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25643 KRU 3F-12 — 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7571 feet Plugs(measured) None true vertical 6095 feet Junk(measured) None Effective Depth measured 7374 feet Packer(measured) 6990 true vertical 5944 feet (true vertical) 5653 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3255 9.625 3292 3033 PRODUCTION 7505 7 7540 6071 LINER 435 41/2 7425 5983 SCANNED JUN ± Z016 RECEIVED MAY 0 2 2016 Perforation depth: Measured depth: 7243-7250 True Vertical Depth: 5844-5849 AOt.�1CC >riginal Perfs cemented off behind liner, the above interval perfed in post-rig work Tubing(size,grade,MD,and TVD) 3.5, L-80, 7036 MD, 5688 TVD Packers&SSSV(type, MD,and TVD) PACKER-2RH ZXP w/HD Liner Top Packer @ 6990 MD, 5653 TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 950 600 2725 Subsequent to operation shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations i✓ Exploratory I— Develo Development p Service F Stratigraphic Copies of Logs and Surveys Run n16.Well Status after work: Oil Gas l WDSPL Printed and Electronic Fracture Stimulation Data P GSTOR I— WINJ n WAG F GINJ r SUSP E SPLUG P 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: 316-167 Contact Daniel Kane (a,265-6048 Email Daniel.Kane(a�conocophillips.com Printed Name Daniel Kane Title Sr. Wells Engineer Signature Phone:265-6048 Date \ 25-AP2-201 Co vii- 5/1//c Form 10-404 Revised 5/2015 Submit Original Only /A:,4 RBDMS t, , MAY 0 2 2016 • • , i.i . 1.... 0 Operations Summary (with Timelog Depths) 3F-12 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-x Operation (ftKB) End.Depth(ftKE). 3/26/2016 3/26/2016 2.00 MIRU MOVE RURD P Work on derrick down check list. 0.0 0.0 19:00 21:00 Bridle up the blocks. RD berming around cellar,pits,cutting tank,and fuel tank. Lower the cattle chute. Prep the pits to be moved. 3/26/2016 3/26/2016 1.50 MIRU MOVE MOB P PJSM. Pull the pits away from the sub 0.0 0.0 21:00 22:30 and install the jeep. Roll up the herculite for the pits. Load up the shop and satellite office. Move the pits,satellite office,and shop from 1F pad to 3F pad. 3/26/2016 3/26/2016 1.00 MIRU MOVE RURD P PJSM. Lower the derrick. 0.0 0.0 22:30 23:30 3/26/2016 3/27/2016 0.50 MIRU MOVE MOB P PJSM. Jack up the sub and pull the 0.0 0.0 23:30 00:00 mats. Move the sub off well 1 F-03A and stage in the middle of the pad. 3/27/2016 3/27/2016 1.50 MIRU MOVE RURD P Clean up the cellar,roll up the 0.0 0.0 00:00 01:30 herculite,load rig mats,and clean up around well 3H-22. 3/27/2016 3/27/2016 3.50 MIRU MOVE MOB P Move the sub 5 miles from 1F pad to 0.0 0.0 01:30 05:00 the Oliktok Y. 3/27/2016 3/27/2016 1.50 MIRU MOVE WAIT P Wait for field wide change out. 0.0 0.0 05:00 06:30 3/27/2016 3/27/2016 7.50 MIRU MOVE MOB P Move the sub 9 miles from Oliktok Y to 0.0 0.0 06:30 14:00 3F pad. 3/27/2016 3/27/2016 0.50 MIRU MOVE RURD P PJSM. Raise and pin the derrick. 0.0 0.0 14:00 14:30 3/27/2016 3/27/2016 0.50 MIRU MOVE RURD P Hang the tree in the cellar,lay down 0.0 0.0 14:30 15:00 herculite for the cellar,and stage wellhead equipment behind the well. 3/27/2016 3/27/2016 1.50 MIRU MOVE MOB P Spot the sub over well 1 F-03A,set rig 0.0 0.0 15:00 16:30 mats,and lay down herculite for the LEPD tank. 3/27/2016 3/27/2016 2.50 MIRU MOVE MOB P Remove the jeep,spot the pits to the 0.0 0.0 16:30 19:00 sub,set rig mats,lay down herculite for the pits/cuttings box,and spot the cutting tank. 3/27/2016 3/27/2016 2.00 MIRU MOVE RURD P RU berming around the sub,pits,and 0.0 0.0 19:00 21:00 cuttings box. Hook up the interconnect. 3/27/2016 3/27/2016 1.50 MIRU MOVE RURD P Raise the cattle chute,tighten the 0.0 0.0 21:00 22:30 Kelly hose,and bridal down the blocks.Rig accepted at 22:30 hours on 3/27/16. Load the pits with 12.1 ppg viscosified NaBr brine. 3/27/2016 3/28/2016 1.50 MIRU WELCTL RURD P RU circulating liner for the well kill 0.0 0.0 22:30 00:00 operation. Blow steam and air through line to the kill tank and check connections. 3/28/2016 3/28/2016 2.00 MIRU WELCTL MPSP P PU and RU lubricator. PT to 2000 psi 0.0 0.0 00:00 02:00 (good test). Pull 3"ISA BPV(tubing pressure=850 psi,IA pressure=650 psi,and OA pressure=600 psi). RD and lay down the lubricator. 3/28/2016 3/28/2016 0.75 MIRU WELCTL RURD P RU circulating equipment for the well 0.0 0.0 02:00 02:45 kill operation. PJSM. PT all surface lines to 250/3500 psi(good test) Page 1/8 Report Printed: 4/25/2016 • • Operations Summary (with Timelog Depths) rzt 3F-12 Conoc 'Phillips Y` �3;oFks Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End Depth(ftKB) 3/28/2016 3/28/2016 2.50 MIRU WELCTL KLWL P Bleed the IA from 680 psi to 600 psi 0.0 0.0 02:45 05:15 (little gas mainly fluid). Bleed the tubing from 703 psi to 310 psi. Kill the well by reverse circulating 12.1 ppg viscosified NaBr brine(ICP at 3 BPM =880 psi and FCP at 3 BPM=537 psi)down the IA taking returns out the tubing to the kill tank. Pumped a total of 355 bbls getting good 12.1 ppg viscosified NaBr brine at surface. 3/28/2016 3/28/2016 0.50 MIRU WELCTL OWFF P Observe the well for flow for 30 0.0 0.0 05:15 05:45 minutes. The tubing and IA are on a slight vac. 3/28/2016 3/28/2016 1.25 MIRU WELCTL RURD P Blow down and RD all circulating 0.0 0.0 05:45 07:00 equipment. 3/28/2016 3/28/2016 1.00 MIRU WHDBOP MPSP T Attempt to install BPV but the SSV 0.0 0.0 07:00 08:00 partially closed. Pump open the SSV and install the 3"ISA BPV with dry rod. 3/28/2016 3/28/2016 2.00 MIRU WHDBOP NUND P RU wire slings to the TD and RU 0.0 0.0 08:00 10:00 slings to the tree. ND the tree and tubing head adapter. Pull the tree free with the TD. RU the bridge crane to the tree. Lay down the tree and tubing head adapter. Clean and inspect the tubing hanger lift threads(threads are good). Install the blanking plug(11- 1/2 right hand turns). 3/28/2016 3/28/2016 3.50 MIRU WHDBOP NUND P NU the DSA and NU the BOP stack. 0.0 0.0 10:00 13:30 Install the turn buckles and riser. Air up the air boots on the riser. 3/28/2016 3/28/2016 3.00 MIRU WHDBOP RURD P RU BOPE testing equipment. Grease 0.0 0.0 13:30 16:30 valves on the BOP stack and function rams. Flush/fill BOP stack and choke manifold with fresh water. Page 2/8 Report Printed: 4/25/2016 .. ___ A _ ....,s._. • • Operations Summary (with Timelog Depths) 3F-12 r«oa:WhitHip Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKB)l 3/28/2016 3/28/2016 6.50 MIRU WHDBOP BOPE P Conduct initial BOPE: test the newly 0.0 0.0 16:30 23:00 rebuilt choke manifold and blind rams to 250/5000 psi;test 2-7/8"x 5"VBR's (upper and lower pipe rams)to 250/4000 psi with 3-1/2"and 4-1/2" test joints;test annular to 250/4000 with 3-1/2"and 4-1/2"test joints; conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Brian Bixby via email on 3/28/16 at 05:06 hours. Tests: 1) Blind Rams,manual kill,Chokes 1, 2,3,&16(Passed) 2) Blind Rams,manual kill,Chokes 4, 5,&6(Passed) 3) Blind Rams, Manual Kill,Chokes 7, 8,&9(Passed) 4) Super Choke and Manual Adjustable Choke(Passed) 5) Blind Rams, Manual Kill,Chokes 8, 10,&11 (Passed) 6) Blind Rams, Manual Kill,Chokes 8, 12, 13,&15(Passed) 7) Blind Rams,Manual Kill,Choke 14 (Passed) 8) Annular with 4-1/2"test joint,2" Demco,HCR Choke, HT-38 TIW, HT- 38 Dart Valve(Passed) 9) Upper Pipe Rams with 4-1/2"test joint,HCR Kill,Manual Choke,HT-38 TIW(Passed) 10)Lower Pipe Rams with 4-1/2"test joint,HT-38 TIW(Passed) 11)Annular with 3-1/2"test joint, Manual Kill,Outer Test Spool,3-1/2" EUE 8rd TIW,Upper IBOP(Passed) 12)Upper Pipe Rams with 3-1/2"test joint, Inner Test Spool,3-1/2"EUE 8rd TIW,Lower IBOP(Passed) 13)Lower Pipe Rams with 3-1/2"test joint,3-1/2"EUE 8rd TIW(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2990 psi Accumulator Pressure After Closer= 1600 psi Pressure Gain of 200 psi=17 seconds Full System=97 Seconds Average N2(5 Bottles)= 1950 psi 3/28/2016 3/29/2016 1.00 MIRU WHDBOP RURD P Blow down and RD all BOPE testing 0.0 0.0 23:00 00:00 equipment. 3/29/2016 3/29/2016 0.50 MIRU WHDBOP MPSP P Pull the blanking plug. Check for 0.0 0.0 00:00 00:30 pressure under BPV(no pressure) and pull 3"ISA BPV with dry rod. 3/29/2016 3/29/2016 0.50 COMPZN RPCOMP RURD P RU GBR power tubing tong and 3-1/2" 0.0 0.0 00:30 01:00 tubing elevators. RU landing joint with 3-1/2"EUE 8rd TIW. MU landing joint to tubing hanger,and MU the TD. Page 3/8 Report Printed: 4/25/2016 • • • WOperations Summary (with Timelog Depths) slit . � 3F-12 ConocoPtiiiiiips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP PULL P PJSM. BOLDS,unseat the tubing 0.0 6,925.0 01:00 02:00 hanger at,and the tubing pulled free at 80K. Pull tubing hanger to the rig floor(PU=80K and SO=70K). Lay down landing joint,TIW,and tubing hanger. SimOps: Monitored the well and established a 24 bbls/hour loss rater 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP CIRC P Spot a 26 bbl 12.1 ppg Dyna Red 6,925.0 6,925.0 02:00 03:00 LCM balanced pill. Monitored the well to establish a 4 bbls/hour loss rate. Blow down the TD. 3/29/2016 3/29/2016 7.00 COMPZN RPCOMP PULL P POOH laying down 3-1/2"tubing. 6,925.0 0.0 03:00 10:00 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP RURD P RD Tbg handling equipment Ru Drill 0.0 0.0 10:00 11:00 pipe handling equipment 3/29/2016 3/29/2016 0.50 COMPZN RPCOMP SVRG P Service and inspect top drive. 0.0 0.0 11:00 11:30 3/29/2016 3/29/2016 0.50 COMPZN RPCOMP RURD P Install wearing. 0.0 0.0 11:30 12:00 3/29/2016 3/29/2016 1.50 COMPZN RPCOMP BHAH P Picked up BHA#1:spear assembly 0.0 317.0 12:00 13:30 3/29/2016 3/29/2016 6.50 COMPZN RPCOMP PULD P Pick up drill pipe.RIH with BHA#1 317.0 6,849.0 13:30 20:00 3/29/2016 3/29/2016 1.50 COMPZN RPCOMP SLPC P Slip&cut drilling line. 6,849.0 6,849.0 20:00 21:30 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP FISH P Set parameters: 6,849.0 6,944.0 21:30 22:30 Up wt= 145 K Down wt=95 K.SPR @ 2 BPM @ 465 PSI.Engaged grapple at 6944 ft.TOF @ 6938 ft. Open jars at 50 K.pulled up to 205 K Dropped back on TOF tagged @ 6941 with 10 K down. 3/29/2016 3/29/2016 1.00 COMPZN RPCOMP CIRC P Circulated BU volume at 3 BPM @ 6,944.0 6,938.0 22:30 23:30 800 psi.No gas to surface. 3/29/2016 3/29/2016 0.25 COMPZN RPCOMP OWFF P Pulled top stand.Blow down top drive 6,938.0 6,871.0 23:30 23:45 while monitoring well for flow. 3/29/2016 3/30/2016 0.25 COMPZN RPCOMP TRIP P POOH with BHA#1 &fish. 6,871.0 6,750.0 23:45 00:00 3/30/2016 3/30/2016 3.00 COMPZN RPCOMP TRIP P Continue to POOH with BHA#1 and 6,750.0 317.0 00:00 03:00 fish. 3/30/2016 3/30/2016 2.50 COMPZN RPCOMP BHAH P Lay down BHA#1 and fish. 317.0 0.0. 03:00 05:30 Recovered 52.85 ft 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP BHAH P Pick up BHA#2;overshot assembly 0.0 320.0 05:30 06:30 3/30/2016 3/30/2016 3.50 COMPZN RPCOMP TRIP P RIH with BHA#2 Up wt=147K Down 320.0 6,986.0 06:30 10:00 wt=90 K 3/30/2016 3/30/2016 0.50 COMPZN RPCOMP FISH P Est Parameters;Circulated @ 3 BPM 6,986.0 6,994.0 10:00 10:30 @ 590 psi. 150 Up wt.95 K down. 117K Rt wt @ 20 RPMs F/TQ=6K. Engaged OS @ 6988.0 Set grapple. Picked up to 185 K to open jar. continue to pick up string. Fish was free at 155K up wt. 3/30/2016 3/30/2016 1.50 COMPZN RPCOMP CIRC P Circulated BU @ 3 BPM.got packer 6,994.0 6,980.0 10:30 12:00 gas to surface.Slow rate to 1 BPM continue to circulate out gas. 3/30/2016 3/30/2016 6.00 COMPZN RPCOMP TRIP P POOH with BHA#2 and fish. 6,980.0 320.0 12:00 18:00 Page 4/8 Report Printed: 4/25/2016 • • AZ 0 Operations Summary (with Timelog Depths) 3F-12 T 18p iivka Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time rr End Time Dur(hr)'. Phase Op Code Activity Code. Time P-T-X Operation (ftKB) End Depth(ftKB)'.. 3/30/2016 3/30/2016 4.00 COMPZN RPCOMP BHAH P POOH with BHA#2:laid down fish. 320.0 0.0 18:00 22:00 Recovered SBR,RRH packer blast jts, sleave. Cut pup=3.68 ft. 3/30/2016 3/30/2016 1.00 COMPZN RPCOMP BHAH P Pick up BHA#3;5 3/4"Overshot with 0.0 317.0 22:00 23:00 2 7/8 graple. 3/30/2016 3/31/2016 1.00 COMPZN RPCOMP TRIP P RIH with BHA#3:overshot assembly. 317.0 3,500.0 23:00 00:00 3/31/2016 3/31/2016 1.50 COMPZN RPCOMP TRIP P Continue to RIH with BHA#3. 3,500.0 7,132.0 00:00 01:30 3/31/2016 3/31/2016 0.50 COMPZN RPCOMP FISH P Est circulation @ 2 BPM @ 350 psi. 7,132.0 7,165.0 01:30 02:00 Engaged overshot @ 7165 ft.top of fish @ 7163 ft.pulled seal assembly free with 15K over.Dropped back into packer pressure increased to 1000 psi. 3/31/2016 3/31/2016 3.00 COMPZN RPCOMP TRIP P POOH with BHA#3. 7,165.0 317.0 02:00 05:00 3/31/2016 3/31/2016 3.00 COMPZN RPCOMP BHAH P Laid down BHA#3 with fish.Seal 317.0 318.0 05:00 08:00 assembly.Pick up BHA#4 milling assembly 3/31/2016 3/31/2016 3.00 COMPZN RPCOMP TRIP P RIH with BHA#4 318.0 7,135.0 08:00 11:00 3/31/2016 3/31/2016 5.50 COMPZN RPCOMP MILL P Est Parameters: Up wt=150 K down 7,135.0 7,229.0 11:00 16:30 wt=90KRT/wt =115K.F.tq=7K @ 80 RPM.Circulating @ 5 BPM @ 1210 psi. Engaged mill on packer top @ 7165 ft. torque increased to 7-11K.milled packer free.pushed to 7229 ft.while continuing to circulate.small amount of packer gas to surface.circulated clean. 3/31/2016 3/31/2016 0.50 COMPZN RPCOMP TRIP P Trip out of hole.with milling assembly. 7,229.0 6,849.0 16:30 17:00 3/31/2016 3/31/2016 1.00 COMPZN RPCOMP SFTY P Crew appreciation dinner with both 6,849.0 6,849.0 17:00 18:00 crews 3/31/2016 3/31/2016 3.00 COMPZN RPCOMP TRIP P Continue to POOH with BHA#4 6,849.0 318.0 18:00 21:00 3/31/2016 3/31/2016 1.50 COMPZN RPCOMP BHAH P Laid down milling BHA#4 and Pick 318.0 317.0 21:00 22:30 up spear assembly. BHA#5 3/31/2016 4/1/2016 1.50 COMPZN RPCOMP TRIP P RIH with BHA#5 317.0 3,630.0 22:30 00:00 4/1/2016 4/1/2016 1.50 COMPZN RPCOMP TRIP P Continue to RIH with BHA#5 spear 3,630.0 7,231.0 00:00 01:30 assembly. 4/1/2016 4/1/2016 1.50 COMPZN RPCOMP FISH P Enaged packer with spear circulating 7,231.0 7,231.0 01:30 03:00 @ 3 BPM pressure increased from 780 psi to 1200 psi.continue to work spear into packer top. No claer drag from packer. 4/1/2016 4/1/2016 4.00 COMPZN RPCOMP TRIP P POOH with BHA#5 7,231.0 317.0 03:00 07:00 4/1/2016 4/1/2016 1.00 COMPZN RPCOMP BHAH T Laid down BHa#5 no packer 317.0 0.0 07:00 08:00 recovered 4/1/2016 4/1/2016 1.00 COMPZN RPCOMP BHAH T Make up BHA#6 clean out assembly 0.0 321.0 08:00 09:00 4/1/2016 4/1/2016 3.00 COMPZN RPCOMP TRIP T RIH with BHA#6 321.0 7,231.0 09:00 12:00 Page 5/8 Report Printed: 4/25/2016 i • Operations Summary (with Timelog Depths) ,--1 - , 3F-12 irtiips r;. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time' ra End Time Dur(hr) Phase Op.Code. Activity.Code Time P-T-X Operation (ft(S) End Depth(ftKE) 4/1/2016 4/1/2016 3.00 COMPZN RPCOMP MILL T Est Parameters: Up wt= 155 K down 7,231.0 7,236.0 12:00 15:00 wt=90 K.RT/Wt=115K.@ 30 RPM's @ 6K F/TQ.Milled out packer bore from 7231 ft.to 7236 ft. Circulated clean @ 5 BPM @ 1290 psi. Recovered sand 4/1/2016 4/1/2016 3.00 COMPZN RPCOMP TRIP T POOH with BHA#6 7,236.0 321.0 15:00 18:00 4/1/2016 4/1/2016 1.00 COMPZN RPCOMP BHAH T Swap out BHA#6 to#7 spear 321.0 317.0 18:00 19:00 assembly 4/1/2016 4/1/2016 3.00 COMPZN RPCOMP TRIP T RIH with BHA#7 317.0 7,132.0 19:00 22:00 4/1/2016 4/1/2016 1.50 COMPZN RPCOMP SLPC P Slip&cut drilling line. 7,132.0 7,132.0 22:00 23:30 4/1/2016 4/2/2016 0.50 COMPZN RPCOMP FISH T Est parameters Up wt=150 K Down 7,132.0 7,163.0 23:30 00:00 wt 95K.SPR=520 psi @ 2BPM 4/2/2016 4/2/2016 0.50 COMPZN RPCOMP FISH T engaged fish at 7163 ft dropped spear 7,163.0 7,168.0 00:00 00:30 to 7168 ft with 15 K down.pulled 10 K over set grapple.pulled 20 k over and packer pulled free.2-4 K drag 4/2/2016 4/2/2016 4.00 COMPZN RPCOMP TRIP T POOH with BHA#7: 7,168.0 317.0 00:30 04:30 4/2/2016 4/2/2016 2.00 COMPZN RPCOMP BHAH P Laid down BHA#7.Recovered 21.64 317.0 0.0 04:30 06:30 ft of fish 4/2/2016 4/2/2016 0.50 COMPZN WELLPR SVRG P Service and inspect top drive 0.0 0.0 06:30 07:00 4/2/2016 4/2/2016 1.00 COMPZN WELLPR BHAH P RIH with BHA#8:Junk mill clean out 0.0 341.0 07:00 08:00 assembly 4/2/2016 4/2/2016 2.50 COMPZN WELLPR TRIP P RIH with BHA#8 341.0 7,155.0 08:00 10:30 4/2/2016 4/2/2016 2.00 COMPZN WELLPR REAM P EST.Parameters Up wt 145K down 7,155.0 7,238.0 10:30 12:30 95 K, RT/WT 115K.Circulation at 5 BPM @ 1100 psi.washed down to 7238 ft unable to get any deeper. Circulated hole clean with Hi-Vis sweep.light sand recovered. 4/2/2016 4/2/2016 2.50 COMPZN WELLPR TRIP T POOH with BHA#8. 7,238.0 341.0 12:30 15:00 4/2/2016 4/2/2016 1.50 COMPZN WELLPR BHAH T Changed out BHA#8 to BHA#9 341.0 316.0 15:00 16:30 Tappered mill assembly. 4/2/2016 4/2/2016 2.75 COMPZN WELLPR TRIP T RIH with BHA#9 316.0 7,229.0 16:30 19:15 4/2/2016 4/3/2016 4.75 COMPZN WELLPR MILL T Est parameters:Up Wt=150 K,down 7,229.0 7,429.0 19:15 00:00 wt=95 K,RT/Wt @ 60 RPMs= 115K.F/TQ 6K.Circulating©5 BPM ©1100 psi. Milling @ 7-10 K W/-1K on mill. Feathering thru tight spot @ 7238 ft.to 7239 ft with both mills.2-3 Up Wt pulling back thru tight spot.Continue to clean out Tagged fill @ 7375 ft.CIO to 7429'sat down 5 k.qiut making hole. 4/3/2016 4/3/2016 1.50 COMPZN WELLPR CIRC P Circulated in 30 BBL Hi-vis sweep. 7,429.0 7,429.0 00:00 01:30 circulated©5 BPM @ 1100 psi. Circulated 1.5X's hole volume. 4/3/2016 4/3/2016 3.50 COMPZN WELLPR TRIP P POOH with BHA#9 7,429.0 317.0 01:30 05:00 Page 6/8 Report Printed: 4/25/2016 0 411 Operations Summary (with Timelog Depths) On 3F-12 Conoco thithps �.isska Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth --.Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-x Operation (ftK6) End Depth(ftKB)' 4/3/2016 4/3/2016 1.50 COMPZN WELLPR BHAH P Laid down BHA#9 317.0 0.0 05:00 06:30 4/3/2016 4/3/2016 1.50 COMPZN WELLPR RURD P RU GBR handling equipment 0.0 0.0 06:30 08:00 4/3/2016 4/3/2016 3.00 COMPZN RPCOMP PUTB P Picked up 4.5 liner assembly as per 0.0 443.0 08:00 11:00 detail. Pumped 3 BPM©135 psi to ensure that float is fuctioning correctly 4/3/2016 4/3/2016 4.50 COMPZN RPCOMP TRIP P RIH with liner assembly on drill pipe. 443.0 7,425.5 11:00 15:30 filling every 5 stands>spaced out drill pipe. 4/3/2016 4/3/2016 1.00 COMPZN RPCOMP CMNT P RU Cement head and lines 7,425.5 7,425.5 15:30 16:30 4/3/2016 4/3/2016 1.00 COMPZN RPCOMP CIRC P Broke circulation at 5 BPM @ 1260 7,425.5 7,425.5 16:30 17:30 psi. 4/3/2016 4/3/2016 6.00 COMPZN RPCOMP CMNT P PJSM:RU Schlumberger cementers. 7,425.5 6,980.0 17:30 23:30 Pumped 5 BBLs of fresh water ahead. PT pump&line to 4500 psi.Mix& pump 15 BBL's of 13.MP II,Mix& pump 20 BBL's Of G cement 15.8 PPG.flushed lines back to pump. Displaced with 10 bbls of fresh water, followed by 39 BBLs of 12.1 #brine. @ 3 BPM @ 600 psi.latched up plug to wiper sheared @ 3150 psi.latch up in landing collar©3300 psi.CIP @ 20:45 Hrs.Sat hanger.released from hanger.Circulated out cement @ 5 BPM @ 1025 psi.Set packer.& released running assembly. 4/3/2016 4/4/2016 0.50 COMPZN RPCOMP PRTS P PT liner top to 1000 psi for 10 min's 6,980.0 6,980.0 23:30 00:00 good test.Laid down head. 4/4/2016 4/4/2016 6.50 COMPZN RPCOMP PULD P POOH laying drill pipe.and running 6,980.0 0.0 00:00 06:30 assembly. 4/4/2016 4/4/2016 1.50 COMPZN RPCOMP WWWH P Pulled Wear ring and wash stack 0.0 0.0 06:30 08:00 4/4/2016 4/4/2016 10.00 COMPZN RPCOMP PUTB P Pick up&RIH with upper completion 0.0 7,042.0 08:00 18:00 as per detail. 4/4/2016 4/4/2016 2.00 COMPZN RPCOMP HOSO P Spaced out tbg installed hanger 7,042.0 7,000.0 18:00 20:00 4/4/2016 4/4/2016 2.00 COMPZN RPCOMP CRIH P Pumped Hi vis sweep.©3 BPM @ 7,000.0 7,000.0 20:00 22:00 480 psi.followed by 200 BBLs of Conqor 303 treated sea water.displace with 50 bbls of clean sea water. 4/4/2016 4/5/2016 2.00 COMPZN RPCOMP HOSO T Attempted to land seals no indication 7,000.0 7,037.0 22:00 00:00 of entering SBE. Laid down hanger. Re Space well.Appears that first tag was on liner top with locators sub. 4/5/2016 4/5/2016 1.00 COMPZN RPCOMP HOSO T Re Spaced out well. Engaged seal 7,037.0 7,037.0 00:00 01:00 while pumping.Saw PSI increase.to 200 psi.bled off pressure land hanger RILDS 4/5/2016 4/5/2016 1.00 COMPZN RPCOMP THGR P Swap out LDS on tbg spool. 7,037.0 01:00 02:00 4/5/2016 4/5/2016 1.50 COMPZN RPCOMP PRTS P PT Tbg to 3500 psi for 15 Min's.PT IA 7,037.0 7,037.0 02:00 03:30 to 3000 psi for 30 Min's.Shear SOV. Pumped thru valve both directions @ 2 BPM @ 260 Psi. Page 7/8 Report Printed: 4/25/2016 • Operations Summary (with Timelog Depths) ram �� -44� a , 3F-12 Con esccsthiliips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKD)< 4/5/2016 4/5/2016 0.50 COMPZN RPCOMP RURD P RD Landing jt and testing equipment. 7,037.0 7,037.0 03:30 04:00 4/5/2016 4/5/2016 0.50 COMPZN WHDBOP MPSP P Install BPV and test in direction of flow 7,037.0 7,037.0 04:00 04:30 to 1000 psi for 5 Mins. 4/5/2016 4/5/2016 2.50 COMPZN WHDBOP OTHR P Clear floor clean under table and traps 0.0 0.0 04:30 07:00 4/5/2016 4/5/2016 6.00 COMPZN WHDBOP SVRG P Complete BWM on BOPE stack. 0.0 0.0 07:00 13:00 4/5/2016 4/5/2016 1.00 COMPZN WHDBOP NUND P ND BOPE 0.0 0.0 13:00 14:00 4/5/2016 4/5/2016 4.50 COMPZN WHDBOP NUND P NU tree&test 250/5000.Pull Test 0.0 0.0 14:00 18:30 plug 4/5/2016 4/5/2016 4.00 COMPZN WHDBOP FRZP P PJSM:RU LRS to freeze protect well 0.0 18:30 22:30 with7l BBLs of Diesel.RD LRS.Let well equalize 4/5/2016 4/5/2016 0.50 COMPZN WHDBOP MPSP P Install BPV 22:30 23:00 4/5/2016 4/6/2016 1.00 DEMOB MOVE RURD P RD lines and valve system.secure 23:00 00:00 well SIPm=Tbg OPSI. IA 0 PSI .OA 659 PSI. Rig released @ 23:59 hrs. Page 8/8 Report Printed: 4/25/2016 • • Well Progress Summary Report 3F-12 c rzy_t poitl ps Job Type: DRILLING SUPPORT-CAPITAL Secondary Job Type: ZX70 Caliper AFE/RFE/Maint.#: 10390525 Job Category: WELL INTERVENTION Primary Wellbore Affected: 3F-12 Contractor: HES-Eline Last 24hr Summary: LOG 24 ARM CALIPER SURVEY FROM TAG AT 7314'TO 6500'.4.5" LINER LOOKS CLEAR OF ANY CEMENT SHEATHS, DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. PERFORATE INTERVAL 7243'-7250' USING 2.5" HSC LOADED 6SPF, PHASED 60DEG, 11.1GM DP MILLENIUM CHARGES. PERFROM BHPS, PRE JOB LUBE=1085 PSI,27 F BHPS AT 7250=3847 PSI, 129 F, 100'TVD GRADIENT SURVEY AT 7118'=3775 PSI, 127 F, POST JOB LUBE=1110 PSI, 29 F. LOGS CORRELATED TO SLB DENSITY-NEUTRON LOG DATED 10 DEC 1985. READY FOR WHIPSTOCK. Report Start Date: 4/17/2016 05.30 Report End Date: 4/17/2016 18:30 Time Log End Time Start Time Dur(hr) Operation 06:00 05:30 0.50 MORNING ROLLOUT MEETING, PREP FOR JOB,SYNC LAPTOP 06:30 06:00 0.50 DRIVE TO LOCATION,START EQUIPMENT 07:30 06:30 1.00 UNLOAD PCE BASKET,LAYOUT LINES, PREP TOOLSTRING, PJSM 08:30 07:30 1.00 PU LUBE, MU PCE(TOOLSTRING,CALIBRATE CALIPER, STAB ONTO WELLHEAD, PT 300 LOW, 3000 HIGH, OPEN SWAB 10:45 08:30 2.25 LOG PRE JOB INTO LUBE CHECK, RIH W/CH,SWIV,WB5, ROLL,WB5,TTTCU2,AUH, PKJ,QPC, PKJ, PRC17, MFC, PRC17, OAL:33'x2",CALIPER FROM XXX'TO 6500',4.5"LINER LOOKS GOOD, POOH 12:15 10:45 1.50 BUMP UP, BLEED PRESSURE, BLOW DOWN LUBE,BREAK AT QTS, POST CAL CALIPER,WAIT FOR EXPLOSIVES TO ARRIVE,CHECK FIRE,ARM GUN,STAB ONTO QTS,PT TO 3000 PSI,OPEN SWAB, 13:45 12:15 1.50 RIH W/CH, SWIV,WB5, ROLL,WB5,GPST, FH, 2.5"HSC, OAL:32'x2.5", PERFORATE INTERVAL 7243'-7250', CCL TO TOP SHOT: 7.7", CCL STOP DEPTH: 7235.3'.CORRELATE TO SLB DENSITY-NEUTRON LOG DATED 10 DEC 1985,POOH 14:15 13:45 0.50 BUMP UP, BLEED PRESSURE, BLOW DOWN LUBE, BREAK AT QTS, MU PRESSURE TOOLS,STAB ON TO QTS,PT TO 3000 PSI,OPEN SWAB 16:30 14:15 2.25 RIH W/CH,SWIV,WB5 ROLL,WB5,TTTCU2,AUH,QPC, CTF, OAL:27'x2", PERFORM BHPS AT 7250', 100' TVD GRADIENT SURVEY AT 7118', POOH 18:00 16:30 1.50 BUMP UP, BLEED PRESSURE, BLOW DOWN LINES, RIG DOWN PCE/TOOLSTRING,LAYDOWN LUBE, REHEAD WIRELINE,TIDY UP LOCATION 18:30 18:00 0.50 DRIVE BACK TO CAMP,SYNC LAPTOP Page 1/1 Report Printed: 4/26/2016 KUP a 3F-12 ConocoPhi(Hips 3 Well Attrib Max Ang MD TD Alaska.Inc. Wellbore APW WI Field Name Wellbore Statusnc!(°) MD(ftKB) Act Btm(ftKB) Co.,,,,,oVF1116ps 500292148300 KUPARUK RIVER UNIT INJ I 49.66 3,400.00 7,571.0 °°° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3F-12,4/25/20166:49:544 AM NIPPLE Last WO: 10/20/1996 41.88 12/12/1985 Verhoal schema.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RA 7,185.2 4/18/2016 Rev Reason:GLV C/O,PERF,SET pproven 4/19/2016 HANGER;32.7 �_ ' WHIPSTOCK 8 TAG I1` Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 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 SURFACE 95/8 8.921 37.0 3,292.4 3,032.6 36.00 J-55 BTC Casing Description OD(In) SID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6276 35.0 7,539.9 6,070.9 26.00 J-55 BTC Casing Description OD(in) -11)(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,v,r,,.r.rr,.,..,r,tr,r,,,,,,eI,,,i„ere,,,,n.r,r,r ,n, LINER 41/2 3.958 6,990.9 7,425.5 5,983.2 12.60 L-80 BTC Liner Details • Nominal ID I. Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 6,990.9 5,653.3 41.06 PACKER 2RH ZXP W/HD liner top packer 4.300 I 7,010.5 5,668.1 41.09 HANGER DG Flex lock liner hanger 4.200 CONDUCTOR,380-115.0 7,025.6 5,679.4 41.03 SBE Baker 80/40 SBE 5"TCII X 4.5"BTC 4.000 7,338.0 5,916.3 40.37 COLLAR Baker type 1 landing collar 3.950 7,380.7 5.948.9 40.11 COLLAR Baker Float collar 3.938 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ibl/t) Grade Top Connection SURFACE;37.03,292.4 Il TUBING 3.5 L-80 3 1/2 2.992 32.6 7,036.4 5,687.6 9.30 L-80 EUE 8rd EUE 8rd Completion Details 111 Nominal ID lop(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;6,884.6 32.6 32.6 0.04 HANGER 7 1/16"X 3.5 EUE 8rd hanger 3.000 6,945.6 5.619.0 40.64 NIPPLE 3.5"X 2.813 X nipple 2.813 6,995.2 5,656.5 41.10 LOCATOR Locator sub 2.990 6,996 4 5,657.4 41.11 SEAL ASSY Baker 80/40 seal assembly W/7 Ft space out 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) • _ Top(TVD) Top Incl NIPPLE;6,945.6 Top(ftKB) (MKB) 1°) Des Corn Run Date ID(in) 7,178.0 5,794.9 40.66 WHIPSTOCK BAKER GEN 11 4.5"WHIPSTOCK WITH TOP OF 4/2/2016 TRAY Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots) "•l•alf Top(ftKB) atm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn 7,116.0 7,146.0 5,747.8 5,770.6 C-4,C-1, 1/24/1986 12.0 (PERF 120 deg.phasing;5"HJ LOCATOR.6,9952 rcl.III UNIT B,3F- II Csg Gun 1 12 ml7,243.0 7,250.0 5,844.2 5,849.5 A-2,3F-12 4/17/2016 6.0 APERF w/2.5"and 60 Deg /II:-AvvV) SEAL ASSY,6,996.4 l; Millenium II Charges it s It 7246.0 7,280.0 5,846.4 5,872.3 A-2,3F-12 1/24/1986 4.0 IPERF 90 deg.phasing;4"HJ rail IICsg Gun bi .X10 Mandrel Inserts 0'A%i st ah l I} N Top(TVD) Valve Latch Port Size TRO Run w Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com '; 1 6,884.6 5,572.5 Camco MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/15/2016 Notes:General&Safety End Date Annotation IPERF',7,116.0-7,146 6 t t. E 10/20/1996 NOTE:WORKOVER LEFT PORTION OF ORIGINAL TBG STRING 6991'to 7196' Y 11/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 4 4/2/2016 NOTE:Cleaned out to 7429 ft. 0111 4/13/2016 NOTE:All Perforations are behind 4 1/2"cemented liner for CTD setup WHIPSTOCK 7,178.0 r i 1,1+ 1 ll APERF;7,243.0-7,250.0-. IPERF;7,246.0-7,260.0 I I I I LINER;8,990.9-7,425.5 I I PRODUCTION;35.0-7,539.9 • • y of D„, THE STATE Alaska Oil and Gas ' fAo LASIc:A Conservation Commission ___ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0Main: 907.279.1433 ALAS4_'P' Fax: 907.276.7542 www.aogcc.alaska.gov Daniel Kane Sr. Wells Engineer SEMMESA 4 h ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool,KRU 3F-12 Permit to Drill Number: 185-273 Sundry Number: 316-167 Dear Mr. Kane: 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, Cathy . Foerster Chair DATED this�ay of March, 2016. RBDMS l.L.MAR 1 0 2016 • • RECEIVED MAR 0 1 2016 STATE OF ALASKA 02:5 3/cr ALASKA OIL AND GAS CONSERVATION COMMISSION OGC A APPLICATION FOR SUNDRY APPROVALS ! V 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑., - Fracture Stimulate CIRepair Well Operations shutdown❑ Suspend ❑ Perforate Q Other Stimulate ❑ Pull Tubing Q - Change Approved Programs Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: en)SGf,p [!T' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. - Exploratory ❑ Development ❑ 185-273 " 3.Address: Stratigraphic ❑ Service ❑" 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21483-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ••04/a 16 1 KRU 3F-12 " Will planned perforations require a spacing exception? Yes ❑ No Q ✓ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL025643 • 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): • 7571' ' 6095' 4 7374' • 5944' 2763 ✓ 6973' 7437' Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 16" 115' 115' Surface 3254' 9.625" 3291' 3032' Intermediate Production 7503' 7" 7538' 6070' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7246'-7280' ' 5846'-5872' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): SSSV: CAMCO DS NIPPLE NO GO , MD=491 TVD=491 PACKER-BAKER FHL RETRIEVABLE PACKER • MD=6958 TVD=5628 PACKER-OTIS RRH RETRIEVABLE PACKER • MD=7025 TVD=5679 PACKER-OTIS WD PERMANENT PACKER . MD=7172 TVD=5790 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: 3/20/2016 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 2 • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Daniel Kane @ 265-6048 Email Daniel.Kane@conocophillips.com Printed Name Daniel Kane 265-6048 Title Sr.Wells Engineer Phone Signature -'-'4: 1:k.,. ..........._ Date 29-pea-2. (6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ Plug Integrity ❑ BOP Test Mechanical Integrity Test Location Clearance ❑ Other: 50 p f e5 f iv 3.,5-1)0 /SQ19 I /"`1 vc vl a l' p of Vz'vc tr✓ X1-5-t t" V'SU[7 S - r c raj C C J C� 11-4,74 G pti r ,>Lvs-t 5 d /1/i-a T !�4 v'c,t v/Yr cc s 1-a % 1 3 Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? Yes ❑ Nod Subsequent Form Required: {U —412 RBDMS I-I- MAR 1 0 2016 APPROVED BY Approved by: C M ISSIONER THE C MMISSION Date: 3 -5'• l` I 'it' 1/13%R I G I Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska MAR 01 2016 P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 February 29th,2016 Cathy Foerster State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approval to workover Kuparuk Injector KRU 3F-12(PTD# 185-273). Well 3F-12 was spudded in December 1985 and completed as a single-selective Kuparuk A-& C-sand producer in January 1986. After well testing and A-sand fracture stimulation,the well was converted to a single-selective A-& C-sand water injector in 1986. The well was later converted to a single-selective A- & C-sand MWAG injector in 1996 after a rig work-over was performed to upgrade the upper completion. KRU 3F-12 has injected without integrity issues until TxIA communication was discovered in July 2014 and the AOGCC was notified. Subsequent diagnostic work identified a tubing leak at 1,360' MD with a liquid leak rate.of 2.65.gpm and the well was placed on long-term shut-in until the leak could be repaired. While discussing repair options,the well was identified as a CTD development drilling candidate and was placed on the rig work-over schedule. In order to set-up the well to be used as a CTD multi-lateral WAG injector, the 2-%" permanent packer&tubing tail need to be wholly removed as the smaller tubing has insufficient through-tubing ID access for the CTD operations. The proposed rig work-over will consist of pulling the entire completion,setting&cementing a 4-%"scab liner with a liner-top packer to isolate the C-sand, &running a new 3-'/2" upper completion, &re-perforating the A-sands for pressure monitoring prior to CTD development drilling. This Sundry is intended to document the proposed work for KRU 3F-12 because of the intent to pull tubing,plug the existing perforations while cementing the scab liner, &to re-perforate the A-sands as well as to request approval to workover this well. If you have any questions or require any further information,please call me at 265-6048 or email me at danny.kane(&,,conocophillips.com. Sincerely, Danny Kane Wells Engineer CPAI Drilling and Wells • • • a KUP INJ 3F-12 ✓ C(�noc wi iIIip$ °i Well Attributes Max Angle&MD TD Alaska Inc Wellbore API/UWI Field Name Wellbore Status lint'(') MD(ftKB) Act Btm(ftKB) M 500292148300 KUPARUK RIVER UNIT INJ 49.66 3,400.00 7,571.0 ... Comment H25(ppm) Date Annotation End Data KB-Ord(ft) -Rig Release Date 3F-12,9/15/201412:35:57 PM NIPPLE Last WO: 10/20/1996 41.88 12/12/1985 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,374.0 7/19/2014 Rev Reason:Mandrel Orientations lehallf 9/15/2014 ■ HANGER;33.3- :IL.F `I Casing Strings Casing Description OD(in) ID(in) Top/960) Set Depth(ftKB) Set Depth(N0)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WI/Len(I...Grade Tap Thread SURFACE 95/8 8.921 37.0 3,292.4 3,032.6 36.00 J-55 BTC Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WI/Len(I...Grade Top Thread ''' ., PRODUCTION 7 6.276 35.0 7.539.9 6,070.9 26.00 J-55 BTC Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(k..Set Depth(TVD)(...WI(Ib/k) Grade Top Connection •AAA+✓TUBING WO 31/2 2.992 33.2 6,9914 5,653.7 9.30 L-80 ABM-EUE CONDUCTOR 38.0-115.0 a Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 33.2 332 0.04 HANGER FMC GEN III TUBING HANGER 3.500 NIPPLE;491.4 .1. 491.4 491.4 0.25 NIPPLE CAMCO DS NIPPLE NO GO 2.812 6,944.0 5,617.8 40.62 PBR BAKER PBR w/10'STROKE 3.000 6,957.7 5,628.2' 40.75 PACKER BAKER FHL RETRIEVABLE PACKER 3.000 6,972.9 5,639.7 40.89 NIPPLE CAMCO W-1 NO GO SELECTIVE PROFILE NIPPLE 2.812 6,989.9 5,652.5 41.05 OVERSHOT UNIQUE MACHINE OVERSHOT TUBING GUIDE 2.930 6,990.3 5,652.9 41.05 Overshot Eat OVERSHOT BODY EXTENSIONS/MULE SHOE 3.654 Tubing Description String Ma...ID(in) Top(ftKB) at Depth(ft..Set Depth(TVD)(...Wt(Ib/t) Grade Top Connection SURFACE;37.0-3,292.4 TUBING Original 41/2 2.867 6,991.4 7,196.0 5,808.5 9.30 J-55 BTC 3.5x2.875"@ 7164' ir Completion Details Nominal ID GAS LIFT;6,892.5 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) 7,012.1 5,669.2 41.09 SBR OTIS SBR 4.000 7,025.1 5,679.1 41.03 PACKER 'OTIS RRH RETRIEVABLE PACKER 2.970 7,096.0 5,732.7 40.73 BLAST RINGS CARBIDE BLAST RINGS(2) 2.867 `, 7,161.0 5,781.9 40.67 NIPPLE AVA BPL NEW STYLE BPI SLEEVE w/three 9/64"Ports 2.312 PBR;6,944.0 I PACKER;6,957,7 7,163.8 5,784.1 40.67 XO Reducing 'CROSSOVER 3.5 x 2.875 2.875 7,170.3 5,789.0 40.67 SEAL ASSY OTIS LOCATOR SEAL ASSEMBLY 2.441 7,172.1 5,790.3 40.67 PACKER 'OTIS WD PERMANENT PACKER 3.000 NIPPLE;8,972.9, I 7,187.8 5,802.3 40.66 NIPPLE CAMCO D NIPPLE NO GO 2.250 PLUG;6,973.0 7,195.3 5,808.0 40.65 SOS CAMCO SHEAR OUT SUB 2.44) Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(In) 6,973.0 5,639.8 40.89 PLUG SET 2.81"MA-1 PLUG(GAL 24")1.75"PRONG, 7/20/2014 OVERSHOT;6,989.9 2.3"BODY 7,161.0 5,782.0 40.67 SLEEVE 2.75"AVA NEW STYLE BPI w/three 9/64"Ports 8/2/2009 2.310' Perforations&Slots Shot II Dens SBR;7,012.1 - j Top(TVD) Btm(TVD) (shotsh Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date II Type Com PACKER;7,025.1 ' 7,116.0 7,146.0' 5,747.8 5,770.6 C-4,C-1, '1/24/1986 12.0'IPERF 120 deg.phasing;5"HJ • UNIT B,3F-12 II Csg Gun INJECTION;7,059.611 7,246.0 7,280.0 5,846.4 5,872.3 A-2,3F-12 1/24/1986 4.0 IPERF 90 deg.phasing;4"HJ IICsg Gun i Mandrel Inserts - at ti IPERF;7,116.0.7,146.0- on Top(TVD) Valve Latch Port Size TRO Run N Top(TIKE) (ftKB) Make Model OD(In) Sery Type Type (in) (psi) Run Date Cam ;i t 6,892.5 5,578.6-CAMCO MMM 11/2 GAS LIFT DMY RK 0.000 0.0 11/26/1996 2:00 NIPPLE;7,161.0 !' 2 7,059.6 5,705.1 CAMCO KBUG 1 INJ DMY BK 0.000 0.0'10/200996 SLEEVE;7,161.0, el I Notes:General&Safety End Date Annotation SEAL ASSY;7,170.3 es 10/20/1996 NOTE:WORKOVER LEFT PORTION OF ORIGINAL TBG STRING 6991'to 7196' 11/9/2010 NOTE:View Schematic w/Alaska Schematic9.0 PACKER;7,172.1I NIPPLE;7,187.8 ;"*F SOS;7,195.3 III J IPERF;7,246.0-7,280.0 PRODUCTION;35.0-7,539.9 • • KRU 3F-12 Proposed Rig Workover ConocoPh i I I i ps Pull Tubing, Install Cemented Scab Liner(CTD Set-Up) Original PTD#:185-273 Alaska Current Status: KRU 3F-12,a single-selective Kuparuk A-&C-sand WAG injector,is currently shut-in after failing a MIT-IA as a result of a tubing leak identified at 1,360' MD;this well has been identified as a CTD development drilling candidate and therefore,a rig work-over has been planned to repair the well&prepare it for service as a CTD multi- lateral WAG injector. Please see below for a history of the well&leak diagnostics: - 1985—KRU 3F-12 was drilled. - 1986—KRU 3F-12 was completed as a single-selective Kuparuk A-&C-sand producer. o The A-sands were fracture-stimulated. o The well was converted to a water injector. - 1996—KRU 3F-12 was worked-over&converted to a WAG injector. o Tubing had to be swapped to EUE-8RD AB-Mod for gas injection. - 2002—Bubbling gas reported—1-2' from the wellhead. Sampling showed gas to be from gas hydrates within the thaw bulb of the well. MIT-OA to 1,800 psig passed. - 2003—Bubbling gas reported again. Sampling again showed gas to be from gas hydrates being thawed by the well. MIT-OA to 1,800 psig passed. - 2006—Top of conductor topped-off with cement&sealant. - 2014—Tubing leak discovered at 1,360' MD&well shut-in. o July—TxIA communication noticed. T-POT,T-PPPOT,IC-POT,IC-PPPOT all passed. MIT-IA failed w/2.65gpm liquid leak rate. CMIT-TxIA passed. Well shut-in. o September—Leak found at 1,360' MD with PDS Leakpoint tool. Also found on caliper. - 2015-2016—Well remained shut-in and was identified as a CTD development drilling candidate with proposed service as a multi-lateral WAG injector. Scope of Work: The objective of this proposed RWO will be to pull the entire existing 3-1/2"x 2-7/8"completion and replace with a new 3-1/2" x 4-1/2" cemented scab liner completion suitable for CTD development drilling. The scope of this proposed RWO will be to pull&fish the entire existing completion,run and cement a 4-1/2"scab liner with a liner- top packer to isolate the C-sand,and run a new 3-1/2"upper completion. Page 1 of 3 • S KRU 3F-12 Proposed Rig Workover ConocoPh i I I i ps Pull Tubing, Install Cemented Scab Liner(CTD Set-Up) Original PTD #:185-273 Alaska General Well Info: Well Type: Kuparuk A-&C-Sand Single Selective MWAG Injector MPSP: 2,763 psig using MASP=(PP-(0.1*TVD)),or dry gas gradient to surface. 2,763 psig=(3,344 psig—(0.lpsig/ft*5,810' TVD)) NOTE: The MPSP will be updated with the new SBHPs requested as part of the pre-rig work. Reservoir Pressure/TVD: Kuparuk A/C Mid-Perfs—3,344 psig/5,810' TVD(11.1 ppg EMW) Wellhead Type: FMC Gen III(5M Tubing Head/3M Casing Head) BOP Configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-IA Failed 16-Jul-2014 Last passed 05-Jun-2011, diagnostics found tubing leak at 1,360'MD. CMIT-TxIA Passed 19-Jul-2014 Passed after 2.81"MA-1 Plug Set at 6,973'MD MIT-OA Passed 20-Feb-2016 Earliest Start Date: 20-Mar-2016 Production Engineer: Marina Krysinski Workover Engineer: Danny Kane (907)265-6048 danny.kane@conocophillips.com Summary of Proposed RWO Procedure: Completed&Proposed Pre-Rig Work: 1. Function-test T&I.C.LDS. Test T&I.C.pack-offs. 2. Pull DV from GLM#1 (RWO circulation point). 3. Pull the 2.81"MA-1 plug from the Camco W-1 Nipple at 6,973' MD. 4. Tag bottom,&obtain a Kuparuk A-sand SBHP. 5. Set a 2.25"CA-2 plug in the Camco D Nipple at 7,188' MD. 6. Pull the BPI sleeve from the AVA BPL Nipple at 7,161' MD. 7. Obtain a Kuparuk C-sand SBHP. 8. Pull the 2.25"CA-2 plug from the Camco D Nipple at 7,188'MD. 9. Obtain a GR/CCL jewelry tie-in log from bottom to 6,500' MD. 10. Perform a 2-7/8"tubing cut at 7,165'MD. 11. Set BPV prior to rig arrival. o fit Proposed Ri2 Workover Procedure: Q(�C C 1. MIRU RWO Rig. 2. Pull BPV. Reverse circulate kill-weight fluid. Obtain SITP&SICP,if still seeing pressure t surface,calculate new KWF&repeat circulation as necessary. Perform 30-minute flow check to verify wel is static. 1.. 3. Set BPV&blanking plug. ND tree,NU BOPE,&test BOPE to 250/3 sig low/high. 3 5-00/2514 8 5! a. NOTE: The BOPE test pressure will be the greater of what is proposed above(250/3,000 psig) or apve-SS L-ve minimum of 200 psig higher than the new MPSP calculated from the updated SBHP to be measured as part of the pre-rig work. 4. Pull BPV,screw in landing joint,BOLDS,&unseat tubing hanger. 5. P/U on tubing,pull/jar the 10' Baker 80-40 seals from the PBR,&pull the tubing hanger to the rig floor. 6. Verify the well is static&TOH laying down the 3-'/2"upper completion to the Baker 10' 80-40 seals. 7. M/U&TIH w/spear dressed for the 10' Baker 80-40 PBR,engage&rattle/jar the PBR/FHL packer free to the poor-boy overshot. Verify the well is static&TOH laying down the fish. Page 2 of 3 • • KRU 3F-12 Proposed Rig Workover C Ph i I I i ps Pull Tubing, Install Cemented Scab Liner(CTD Set-Up) Original PTD #:185-273 Alaska 8. M/U&TIH w/overshot&grapple dressed for the 3-1/2" 9.3#J-55 EUE-8RD tubing stub, engage&rattle/jar the tubing stub free to the SBR. Verify the well is static&TOH laying down the fish. 9. M/U&TIH w/overshot&grapple dressed for the Slick-Stick above the Otis RRH packer, engage&rattle/jar the Slick-Stick/Otis RRH packer free to the pre-rig tubing cut at 7,165' MD. Verify the well is static & TOH laying down the fish. 10. M/U&TIH w/overshot&grapple dressed for the 2-7/8" 9.3#J-55 EUE-8RD tubing stub, engage&rattle/jar the tubing stub free from 7,165'MD to the Otis Locator Seal Assembly. Verify the well is static&TOH laying down the fish. 11. M/U&TIH w/packer mill&mill the Otis WD packer at 7,172' MD. Once free,push to bottom,verify the well is static,&TOH w/the milling assembly. 12. M/U&TIH w/spear dressed for the Otis WD packer,engage,&pick-up the packer. Verify the well is static& TOH laying down the fish. 13. M/U&TIH with a casing clean-out assembly&clean-out down to the 7"float collar at 7,450' MD. Verify the well is static&TOH laying down the clean-out assembly. 14. M/U&TIH w/4-1/2"liner&liner-top packer on drill pipe,correlate,&set pipe in slips once on depth. 15. R/U cementers,establish circulation,&cement the liner as per the cementing program. 16. Pressure-up to set the liner hanger. Slack-off to verify the hanger set properly. Pressure-up to release the liner running tools. 17. P/U to expose the rotating dog sub & slack-off to set the liner-top packer. Pick-up & reverse circulate any cement out of the well above the liner-top packer. Once returns are clean,TOH&L/D liner setting tools. 18. M/U&TIH with new 3-'/2"upper completion to just above the liner-top packer SBE. 19. Sting seals into the SBE until fully-located,space-out as needed,mark the pipe at surface,&lay-down two joints. 20. Space-out with tubing pups, M/U tubing hanger,land hanger,&RILDS. 21. Pressure-test tubing to 3,500 psig&IA to 3,000 psig. Bleed the IA&then the tubing. Ramp up the IA pressure quickly to shear the SOV. 22. Back-out landing joint&install BPV. 23. ND BOPE,NU tree, install tree test plug,&pressure test tree. 24. Freeze protect well through SOV. 25. Set BPV. 26. RDMO RWO Rig. Proposed Post-Rig Work 1. Pull BPV. 2. RU Slickline to swap the GLM#1 SOV with a DV&perform a tag in the cemented liner. RDMO Slickline. 3. RU E-Line to re-perforate the A-sands for pressure-monitoring. a. Perforate Kuparuk A-2 from 7246'to 7280' MD. RDMO E-Line. 4. Reset well house(s)&re-attach flow line(s). 5. Turn well over to operations. Page 3 of 3 • • FMC Gen Ill 11/11.'" (5 b _Hgr KRU 3F-12 • / • • 7-1/1fi'x 3'A"EUE Tbg ConocoPhillips Kuparuk A-&C-Sand Injector Current Status—29-Feb-2016 16"62.5#H-40 WLD,115'MD- Surface Casing Primary Cement -41)---491'TVD,3-%"Camco 2.812"DS Nipple 325 bbls 12.1 ppg Permafrost'E' 69 bbls 15.8 ppg Permafrost'C' -ill--1360'MD,Tubing Leak Identified w/PDS Leakpoint Log 14-Sep-2014 OA Shoe Squeeze Est TOC 1817'MD 29.6 bbls 15.6 ppg Permafrost'C' 54 bbls 7.4 ppg Arctic Pack 9-%"36#J-55 BTC,3292'MD—IP- Drilling ►Drilling Mud/Spacer 3'/z'9.3#L-80 EUE-8RD AB-Mod Tbg Lead Cement Arctic Pack Diesel Kill-Weight Brine 6892,Camco 3-W x 1-1/2"MMM,DV go v( ' 6943'TVD,Baker 10'80-40 Seal Assm.&PBR t4 6957'TVD,Baker 7"x 3-%"FHL Packer 6972'TVD,31/2"Camco 2.812"W-1 Nipple Pre-Rig:2.81"MA-1 Plug to be Removed 6989'ND,UM Overshot Tubing Guide 6991'MD—3-14"9.3#J-55 EUE-8RD Chem Cut Tbg Stub 7012'MD,Otis SBR ® 4 7025'MD,Otis 7"x 3-%"RRH Packer 7059'MD,Camco 3-%"x 1"KBUG GLM,DV = r Kuparuk C-Sand Perforations I r , F—7096'-7156'MD,2x 3-A"9.3#J-55 BTC Jts C-4,1986-7116'-7146'MD 40'Blast Rings Spaced Across Kuparuk C-Sand Perts — -411 7160'MD,Camco 3'A"AVA BPL Ported Nipple Pre-RigIsolation Sleeve to be Removed -7165'MD-Proposed Pre-Rig Tubing Cut- Production Casing Squeeze :. . ', : - —7172'MD,7"x 3.1/2"Otis WD Packer w/5'SBE Perforated 7206'-7208'MD le '' Packer XO ed to 2-4" Squeezed 31 bbls 15.8 ppg Class G Estimated TOC Squeeze 7135'MD Tr Primary Job had Poor Cement ■i 7187'MD,2'/e'Camco 2.25"D Nipple Between Kuparuk A-&C-Sands 9 7195'MD,2'/a'Camco Shear-Out Sub Kuparuk A-Sand Perforations A-2,1986-7246'-7280'MD Production Casing Primary Cement TOC-6275'MD(CBL 07-Jan-1986) 33 bbls 15.6 ppg Class G Tail Lost Returns Middle of Job Baker 3BB Bridge Plug,-7437'MD—. . 7"26#J-55 BTC,7539'MD ► I Date: 29-Feb-2016 I Drawn By: Danny Kane • S FMC Gen III(5M) KRU 3F-12 7-1/16" '/: /is"x 3- "EUE Tbg Hgr ConocoPhillips Kuparuk A-&C-Sand Injector Proposed 2016 RWO 16"62.5#H-40 WLD,115'MD-� Surface Casing Primary Cement 325 bbls 12.1 ppg Permafrost'E' 69 bbls 15.8 ppg Permafrost'C' OA Shoe Squeeze Est TOC 1817'MD 29.6 bbls 15.6 ppg Permafrost'C' 54 bbls 7.4 ppg Arctic Pack 9-'Ai"36#J-55 BTC,3292'MD—110---4 Drilling Mud/Spacer 3-1/2"9.3#L-80 EUE-8RD AB-Mod Tbg Lead Cement Arctic Pack Diesel Kill-Weight Brine 6892,Camco 3-'A"x 1-Y."MMG,DCR-1 SOV Pinned 2000 psig IA- Tubing Shear 4 6939'MD,3-1/2"HES 2.813"X Nipple ii ' '4 6992'MD,Baker GBH-22 Locator wl 80-40 Seal Assembly(Spaced-Out to SBE) ii 7000'MD,Baker ZXP Liner Top Packer -t 7018'MD,Baker`DG'Flex-Lock Liner Hanger -4 7028'MD,Baker 80-40 Sealbore Extension Kuparuk C-Sand Perforations C-4,1986-7116'-7146'MD Production Casing Squeeze Perforated 7206'-7208'MD Squeezed 31 bbls 15.8 ppg Class G Estimated TOC Squeeze 7135'MD Primary Job had Poor Cement t 4'/"11.6#L-80 IBT-M Centralized Liner Cemented to Liner-Top Packer Between Kuparuk A-&C-Sands 7138'-7222'MD Kick Off Joints w/o Centralizers for CTD Drilling 1 Production Casing Primary Cement TOC-6275'MD(CBL 07-Jan-1986) 33 bbls 15.6 ppg Class G Tail Lost Returns Middle of Job Kuparuk A-Sand Perforations A-2,1986-7246'-7280'MD I 7308'MD,4-'/:"Landing Collar Re-Perforate A-2-7246'-7280'MD a -7339'MD,41/2"Float Collar Baker 3BB Bridge Plug,-7437'MD—� -411--7372'MD,4'h"Liner Shoe 7"26#J-55 BTC,7539'MD ► r�� I Date: 29-Feb-2016 Dawn By: Danny Kane Image Project Well History File CoVer Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier RESCAN DIGITAL DATA O Color items: o Diskettes, No. o Grayscale items: o Other, No/Type Poor Quality, Originals: Other: NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL OATE: OVERSIZED (Scannable) o Maps: o Other items scannable by large scanner OVERSIZED (Non-Scannable) Logs of various kinds [] Other ~SI Project Proofing [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ISl Scanned (done) III IIIIIIIIIII PAGES: ~,j~ ~ (at the time of scanning) SCANNED BY; BEVERLY BREN VINCENT SHERYL ~)LOWELL ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SNERYL MARIA LOWELL DATE: /s/ General Notes or Comments about this file: PAGES: ~ ~-~ Quality Checked (done) IIIIIIIIIIIllllll MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 07, 2011 TO: Jim Regg e'416 .•/ / P.I. Supervisor SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3F-12 FROM: John Crisp KUPARUK RIV UNIT 3F-12 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3F-12 API Well Number: 50-029-21483-00-00 Inspector Name: John Crisp Insp Num: mitJCrl 10605215039 Permit Number: 185-273-0 Inspection Date: 6/5/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3 Type Inj. W TVD 5628 " IA 680 2120 " T 2080 T 2070 P 1852730 TypeTest sP Test psi I, 1500 OA 120 260 260 260 Interval P/F 4YRTST P Tubing 2750 2750 2750 2750 Notes: 1.9 bbls pumped for test. No problems witnessed. Ai-,ii-4tikj SUN 1 n Tuesday, June 07, 2011 Page 1 of 1 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile: 3F-12 Run Date: 10/23/2009 November 19, 2009 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3F-12 Digital Data in LAS format, Digital Log Image file, Interpretation Report SO-029-21483-00 Injection Profile Log ,~,`,~,~~~ ,.1~l~ L 4 ~~~ 50-029-21483-00 1 CD Rom 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUR_~TING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. ~~ -r C Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@halliburton.com Date: ~s`-~ar5 • n, ~F ;~'~ i Signed: ~' ''~~ :~ /~~~ ^; / / ~ ~ ~ ~ ~ ~ - - - ;- -- i , L.._.--- G ; ~ -----~.-._- p ~3~'s~~~~~~ ~ A I~,k ,i is NO.5035 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Com an p y' Alaska Oil & Gas Cons Comm ATTN: Beth - ~~n~; Attn: Christine Mahnken ~4i5 ~ ~, 3 - 333 West 7th Ave, Suite 100 -~ Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Color CD 3F-05 12115003 PRODUCTION PROFILE ~ ~,j - '~):'.f,'.) " t; r_ :~ 12/20/08 1 1 1 E-22 12115008 INJECTION PROFILE ~ 12/24/08 1 1 3F-12 12115005 INJECTION PROFILE , > =x «,- _~_--:3-? r. ~' 12/25/08 1 1 i D-136 12115008 INJECTION PROFILE ,-, '~ - 's _ ::) ;, .._ ~~ L,1, ~,~1 12/26/08 1 1 3F-06 AZED-00003 PRODUCTION PROFILE '~~,`j"- -?<'~~:_:+ '_G ,~:~ . 12/27/08 1 1 3J-02 12115008 INJECTION PROFILE ; i "~ ~ ., _ -. / ~„ •-z~ ~ ~ C- L ~ 12/29/08 1 1 2N-332 12096514 SBHP SURVEY =,~.~~ .._ _-,~_ ':/ ~'~~~-~ _~ 12/30/08 1 1 2N-323 AZED-00008 SBHP SURVEY ~- -:;- - ~ "" i ''-'% ~-r J -} ._ /~j~. ' 12/30/08 1 1 2N-342 12096514 SBHP SURVEY ~)~. "-~ __ ~;-_.-.- ~'-'.. i. ~-/~ ,„ 12/30/08 1 1 2N-302 AZED-00007 SBHP SURVEY . ; - - ~ ~ l._. I ,..- i ! , L - 12/30/08 1 1 2P-417 AZED-00012 SBHP SURVEY , f - (:',.~"; ~ -_) ;r_/~ -~-. 01/02/09 1 1 2V-03 12115000 INJECTION PROFILE tJ' -` " - 4:~ - 12/17/08 1 1 1 R-13 AYS4-00019 - __ INJECTION PROFILE ~. f<". -'~) i-L"~ 01/03/09 1 1 18-02 AYS4-00020 INJECTION PROFILE '.": '.. " ~J~a ( I°;~ '> -1~'=' f. ~ ~~-C-/~~t~ 01/04/09 1 1 01 /08/09 • u Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. JVIEJVIORANDUlVI . TO: o- r" ?!.:c'_o;- \<:. L -{ Jim Regg P_L Supervisor FROM: John Crisp Petroleum Inspectol' Well Name: KUP/\RUK RIV UNIT 3F-12 Insp Num: mitJCr0706l21 l2054 ReI Insp N urn: Packer State of Alaska \laska Oil and Gas Conservation Commission [)\TE: TuesJa\ iunè 12. 2!Jrr t?/ \ Slß.JFCT: \1cchrJl1kal !rHc.~rlt\ ["sto \I.\SK.·\ . 5''''-~ 1:3 \C& Reviewed By: P.I. Suprv~ß-- Comm Inspector Name: John Crisp Inspection Date: 6/8/2007 -~_......__..._---~- -- --~~-~ ---~"..- .'-¡------ Well i 3F-12 ¡Type Inj. I W . TVD I 5628 IA! 740 -----~--._-----;--~-------+_.---1-----------.-------------r--.- -------- ------- --- P.T.D 1852730 ITypeTest I SPT' Test psi 1500 ¡ OA 630 780 _.' ...._.____._._._.~ .u_ ~_ _~._ ___ ~_.~____ Interval 4YRTST _J'/L . ~___v ___u T_u~ing_ 2740 .. In 2710 ____L~ 271(~ 15 Min. 30 Min. 45 Min. 2190 , 2200 ! , 780 . Notes: 2.1 bbl's pumped for test Tuesday June 12. 2007 KUP·\RUK RlV UNIT 3F,I2 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-029-21483-00-00 Permit Number: 185-273-0 Depth Initial ! 2220 I .-- 780 Pretest SCANNED JUN 2 1 2007 60 lVIin. - -- -- -----. -----_._-~ 2740 -~_..._---~- ----__..--_1____--_---..- Page 1 of 1 . ~ ConocoPhillips Alaska . P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2006 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 SGANNED SEP 0 8200B \q, S~ '}-Î:3 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Kuparuk field (KRU) 3F Pad. Each of these wells was found to have a void in the conductor by surface casing annulus. The voids that were greater than 6 feet were first filled with cement to a level of 2.5 feet. The remaining volume, 2.5 to 6 feet of annular void respectively was coated with a corrosion inhibiter, RG2401, then filled with a viscous hydrocarbon based sealant, RG casing filler, engineered to prevent water trom 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 top- fill operation was completed on August 14, 2006 and is reported as follows. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor and sealant were pumped in a similar manner August 21-29, 2006. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or myself at 907 -659-704~"lt you have any questions. // Sincerely, # 1/'/ / ,If" /'? /' ,. . ///~~ /-' 1 , ;( M.J. loveland ConocoPhillips Well Integrity Supervisor Attachment . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement and Sealant Top-off Kuparuk Field 8/31/2006 Initial Top Cement Final Top Sealant Well Name PTD # of Cement Volume of Cement Cement Volume Sealant Feet Barrels Feet Date Gallons Date . ;·~F.;pt.' ., ..' ·18~~a2&., ,.'",. A·s". :. 'NA .' , . . . 'NA. 8'{2-1fiQQ() " d., , 3F-02 1 85-226 24' 7.0 8/14/2006 7.5 8/21/2006 3P:':Q3' . " 1'aßft2:7: .' ·13~4~' "': -2.3 '. ,.; .' 8/1:'f11QQ~ ".'.. ~ ~ :"': . 8Ì:~1f/ï.Ð[6 ';' . 3F-04 1 85-228 80' 22.7 1 0' 8" 8/14/2006 38.2 8/21/2006 . 3IF~5~;i,·'. ~ ..... 5.1 . ':. '. ...... ···;apt4t/2Ó'Ø'6 '.' . 1~5< . .' :g/21í2:Ö(î6< '. 3F-06 1 85-244 Did not modify 3ji;:0>7 .' " .' f8,G?Z,45 " . ·6;6 . 8/1'4/20.06 ;f 7.6 . .8/2 tj2Q06: 3F-08 1 85-246 1 1 '4" 2.6 8/1 4/2006 6.6 8/21/2006 3F~O~. 1-$~t10 . Did not modify 3F-1 0 1 85-271 SF NA NA 6.6 8/21/2006 31;:::11 '185t~12. ,; .: ,.,':$F· ;.., NA. . , .- . 1.:7 t1/23¡~~lQ~ ,'. 3F-1 2 1 85-273 7'4" 1 .8 8/14/2006 6.2 8/23/2006 ·1'â9m'~1'o.· . ·NÄ ..... '. .··.··,·2f·' .' '... " ' 'Øj2Sf1Q,d~')i '-'.> ;"-:x',,,0, "_n:,~,;~~}t:~~ . ~' L·.. " " " 3F-14 1 85-292 Did not IIUU ~ '. . 2A,' . , ",': . : ,', JfttAI'2s'l(:Í~:, , ,.' .' "'~SI23'!~ØØ6: ;"'> .. .. ., 3F-16 1 96-1 51 6" NA NA 2.7 8/23/2006 &J;:,;;t7 '.' ~ ~ .) '11'" , . , 3:1 '.' . , 8r1~/20flå ..... · . 8:'. . . . Ø'12~t2ØOf¡i 3F-1 8 1 96-1 1 2 4' NA NA 28 8/23/2006 ~3F:,,~9, ... 2O:;~Qt6">. .c;: . . 'R"".· .. '. . ,8". . , NA,' '~.' 2 -- ...iàï~$'12ØØ6;.; ,', " 3F-20 199-079 36" NA NA 1 7.7 8/23/2006 3F-21 ' .. 2QÔ~2Ð3, ' 45" , . NA NA 31 812f~2Ð06 Sch!umbgrger RECEiVEU jÎLr' r 9 1 Z005 u_'-' "-' NO. 3615 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: C ""'~:.-<:';-~'" ~ Cft & Gas ~"fìS. VI i,~; _:-~,,-,""I' Aocnorage Field: -...~ Well Job # Log Description Date BL 1 Y -19 11144040 PIEZO SONA TOOL 11/19/05 1 1Y-27 11072935 PRODUCTION PROFILE W/DEFT 11/22/05 1 20-09 11072933 SBHP SURVEY 11/18/05 1 1 R-15 11072932 SBHP SURVEY 11/18/05 1 3F-05 N/A PRODUCTION LOG 11/13/05 1 1 L-25 11056689 SBHP SURVEY 09/14/05 1 3F-12 ¡' ~~ "'.?-r:.') 11057064 INJECTION PROFILE í~ì \ '-- 11/06/05 1 3H-01 11056685 PRODUCTION PROFILE W/DEFT 09/10/05 1 1 Q-16 11141232 PRODUCTION PROFILE WIDEFT 12/01/05 1 1 E-33 N/A GLS & BHP 12/04/05 1 3N-13 11141234 INJECTION PROFILE 12/03/05 1 2N-329 11141236 SLIM CHFR 12/08/05 1 1 C-07 11141231 PRODUCTION PROFILE W/DEFT 11/30/05 1 1 Q-09 11141233 INJECTION PROFILE 12/02/05 1 3B-16 N/A INJECTION PROFILE 12/08/05 1 1 Q-06 N/A PRODUCTION PROFILE W/DEFT 12/10/05 1 2A-21 11141237 INJECTION PROFILE 12/12/05 1 2A-24 11144049 PROD PROFILE W/DEFT 12/15/05 1 1 Q-1 01 11144044 MDT 11/24/05 12/20/05 t t65 .,LJ- F Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color CD 1 SIGNED: DATE&~ MIß'EIn Ii t\ 1).. 6'ì. 0 2.005 {jCA~11~'\1&;;j t.j~PJ if: ~ Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 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/3F 06/05/03 Arend/Brake- APC Chuck Scheve WelI I3F.07 Type lnj T.V.D. 15~s0 I Tubingl 25001 25001 25001 25001Interval I P.T.D. I1852450 TypeTest TestpsiI 15001CasingI 11001 23001 22751 22751 P/F INotes: I welll3F'08 ITypelnj I Gp I T.V.D. I 5726 I Tubing I 36501 36501 36501 36501 Interval P.T.D. I1852460 TypeTest Test psiI 1500 I Casing I 8001 22751 22501 22501 P/F I Notes: P.T.D.I'I852720 TypeTest Test psiI 1500 I Casingl 11001 23001 22751 22751 P/F Notes: P.T.D,]'I852730 ITypeTest Test psiI 1500 I Cas!ngl 11501 22751 22501 22501 P/F NoteS: P.T.,D.I'I852930 TypeTest Test psiI 1500 I Casing I 14001 230°1 228°1 22801 P/F Notes: We"I3F'~OA ".1 Typelnj I Sp I T.V.D. 14988 I Tubingl 25501 25501 25501 25501,nterva, I 4P P.T.D.I~961510 TypeTest Test psiI 1500 I Casing I 01 23001 23001 23001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form 'Revised: 05/19/02 SCAkaNE~::/t,-~UG 0 ~ 200'3 2003-0605_M IT_K RU_3F-07.-08_-11_-12_-15_.-16A.xls 6/25/2003 ,KRU MIT's Subject: KRU MIT's Date: Fri, 6 Jun 2003 15:28:32 -0800 From: "NSK Problem Well Supv" <nl 617~conocophillips.com> To: bob_fleckenstein~admin.state.ak.us, tom_maunder~admin.state.ak.us, jim_regg~admin.state.ak.us CC: "nl 617" <nl 617~conocophillips.com> Attached are the 4 year cycle MIT Results for 3B and 3F. Please call with any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: MIT KRU 3F 06-05-03.xls) (See attached file: MIT KRU 3B 06-05-03.xls) ~_~MIT KRU 3F 06-05-03.xls Name: MIT KRU 3F 06-05-03.xls Type: EXCEL File (application/msexcel) ,Encoding: base64 ~MIT KRU 3B 06-05-03.xls Name: MIT KRU 3B 06-05-03.xls Type: EXCEL File (application/msexcel) Encoding: base64 I of 1 6/25/2003 4:37 PM 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/3F 06/05/03 Arend/Brake - APC Chuck Scheve Well 13F.07 P.T.D. 1'1852450 Notes: Well 13F.08 P.T.D. I1852460 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I I TypelnjI Gp I T.V.D. 15850 I TubingI 25001 25001 25001 25o011ntervall i~ I Type Test Test psiI 1500 I Casing I 11001 23001 22751 22751 P/F ITypeInj I Gp I T.V.D. 15726 I Tub,,~I 3~01 ~01 3~S01 365011nterval] ~ Type Test Test psiI 1500 I Casing I 800] 22751 22501 22501 P/F P.T.D. I1852720 Type Test TestpsiI 1500 I Casing I 11001 23001 22751 22751 P/F Notes: P.T.D. It852730 Type Test Test psiI 1500 I CasingI 115o1 22751 22501 22501 P/F Notes: P.T.D. I1852930 TypeTest Test psiI 1500 I Casing I 14001 23001 22801 22801 P/F Notes: P.T.D. I1961510 TypeTest Test psiI 1500 I Casing I 01 23O01 23001 23001 P/F Notes: Test Details: TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey. D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3F 06-05-031 .xls 7/~ 0/2003 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU' Jim Regg ("~L2~i~ ~.,. ~.~,sor "l'i~'~'~ FROM: Chuck Scheve Petroleum Inspector DATE: June 5, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3F Pad KRU NON- CONFIDENTIAL WenI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.] Notes: WellI P.T.D.I Notes: 3F-07 I Type 185-245 Type 3F-08 I Type 185-246 Type 3F-11 I Type 185-272 Type 3F-12 I Type 185-273 Type 3F-15 IType 185-293 Type 3F-16A Type 196-151 Packer Depth Pretest Initial 15 Min. 30 Min. '.i.I ~ I~'.v.~. I~o I Tubing I~oo I~oo I~oo I~oo I lntervall 4 testI P I Testpsil 1463 ICasingI 1100I 2300I 2275I 2275I P/F I P testI P I Testpsil 1432 I CasingI 800 I 22751 22501 22501 P/F I P I ,nj.I s I T.V.D. I 5599 I Tubing 11850 11850 11850 11850 I,nterva, I 4 testI P I Testpsil 1400 ICasingI 1100I 2300I 2275I 2275I P/F I P testI P I Testpsil 1407 I Casing l 115O1 22751 22501 22501 P/F I P I '.i.I ~ IT.v.D. I~ I Tubing I35°° I35°° I35°° I35°° I'"'~v~'l '~ testI P ITestpsil 1418 ICasingI 1400I 2300I 2280I 2280I P/F I P j,.' Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3F Pad in the Kuparuk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then perfonned with all wells demonstrating good mechanical integrity. M.I.T.'s performed: _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 200'3-0605 MIT KRU 3F-16A cs.xls 6/24/2003 ~ CANNF. D JUL 0 ? 2003 ARCO Alaska, Inc.~;~'' Post Offic9 Box 10036~ A[~chorage, Alaska 99510-0360 Telephone 907 276 1215 January 9, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3F-12 (Permit No. 85-273) Well Completion RePort ORIGINA, Dear Mr. Commissioner: Enclosed is the well completion report to cover any changes completion during the recent workover operations on KRU 3F-12. If there are any questions, please call 263-4622. made to the Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED Oil & Gas Cons. Commission "- STATE OF ALASKA , ALAS{r,,',.~ OIL AND GAS CONSERVATION (~,.,MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. StatUs of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator ARCO Alaska Inc. ' "-~ 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50-029-21483 4. Location of well at surface t . "" ,'".."' I 9. Unit or Lease Name 42' FSL, 136' FEL, Sec. 19, T12N, RDE, UM,.~_..7~_ ~)~I~I ~! ::'i Kuparuk River Unit At top of productive interval '!'. -,-.-Ti il 0. Well Number 1354' FNL, 1478' FWL, Sec. 30, T12N, RDE, UM ~ 3F-12 Attotal depth ..~.~.T.7~.~,.,, il 1 Field and Pool 1490' FNL, 1217' FWL, Sec. 30, T12N, RDE, UM Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. RKB 93'I ADL 25643, ALK 2574 12. Date Spudded12/06/85 ]13' Date I'D' Reached 114' Date C°mp" Susp" °r Abandi15' Water depth' if °fish°re 116' N°' °f C°mpleti°nsl 2/10/85 10/22/96 N/A MSL[ Two 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19' Directional Survey]20. Depth where SSSV set~21. Thickness of Permafrosl 7571 6095' FT~ 7411 5972 Pr] i-lYes {~N0 ] N/A MDI !465~ (Approx.) 22. Type Electric or Other Logs Run 23. CASING, LINER AND CEMENTING RECORD CASING SE'I-rING DEPTH HOLE SIZE VV]'. PE.R..FT. GRADE , TOP BQ_TTOM_ _ SIZE__ ~EM_E__NT!_N_G _.R_.E~__O__R_D_ ............. AMOUNT PULLED 16" 62.5# H-40 Surf. 115' 24" 316sxAS II 9-5/8" 36.0# J-55 Surf. 3292' 12.25" 925 sx PF 'E' and 410 sx PF 'C' 7" - 26.0# - J-55 Surf. 7540' 8.5' 150 sx Class G and 175 sx PF 'C' ......... 24. Perforations open to Production (MD+TVD of T°p and Bottom 25. ' ........................... TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MO) 3.5"x 2-7/8" 7164' / 7196' 6958' & 7025' & 7172' MD TVD MD TVD 7116'-7146' 5747'-5770' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 7246'-7280' 5846'-5872' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED "~'~i ................... PRODUCTION TEST ' Date First Production IMethod of Operation (l~l°wing, gas lift, etc.) I Water Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAs-OIL RATIO TEST PERIOD ' ~ ............. ; ................ ! ....................................... Flow Tubing Casing PressureCALCULATED · OIL-BBL GAS-MCF !WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HouR RATE "~'8'. ' C~RE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL JAN 10 1997 Alaska 0i~ & Gas Cons. Coramissio~ Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Mar(~ 30. ~' Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Total Volume Pumped to Date = 4288 bbl Top Kuparuk C 7116' 5748' Bottom Kuparuk C 7145' 5769' Top Kuparuk A 7231' 5835' Bottom Kuparuk A 7339' 5917' Freeze protected annulus with diesel. ,,, 31. List of Attachments Summary of Daily Drilling Reports 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed L.~.~ ~ ~ :~_ Title 0~,~u.__~r,~L~ ~r, ll~& ~ Date Prepared By Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 gZ~866'ZZe~ :~o~ X:~eummgzIe~ ~o pu3 '96/~/0~ 's~q 009~ ~ 6TZ peseeZe~ 'zze~ e~n3e9 'ZZem ~sa& 'TS~ 000~ p~e Ts~ 0~g o~ ee~ ~seL '~Z gas 'ee~q. ~N '~AOS ~N 'AAS geS 'MO 'segnulm gI zo~ lsd 00gg og 6ulqn7 %seL 'MO 'segnulm 0{ zo~ lsd 00g~ o7 8ulqn% ~Ul%Se% qSlUl2 M$~IOG 0'0 'MH GZSVZqZH DIH 9:XqIVG (g SaG: AA~iS O) 96/g~/0I 9gI'~Ig O:OAa 0 O:GLZ 9gI'6I~ 9:H~0 00g'Ig 'Ulm 0g zoz Bulqn% %seL 'zeroed ~HS %es ~ lsd 00§~ o% ~ulqn% e~nsse~g 'H%S ~8L69 ~ ~nld %eS '~ulqn% pue% · ~e6ueq ilegSui 'XlqU~eSse uol%eld~OO ,,g'E 6uluun~ qSlUlS SAG: ACIDS ,0cj~,t :Scl ~OL§L : ti,T, 9 6/-[Z:/0-E 9gL'I§9 ~:0~ 0 9:GLZ 9§L'9§g ~:HnO 960'~0I · Xlqmesse UOl~eidmoo ,,g'g unH 'A~le~e~ pue 6ulqn~ ~S~N L'TT:MH NOILZqLHOO ,,g'~ DNINN~ S,q'G: Aa[iS ,0cj~'L ,OLgL (C O) 96/0g/0I 'lsd 00gg/00g o% adOS %saL 'adOS SN 'acs% GN 'AdS %eS 'Ieselp ~%!~ eu!l~Olg %oege2d ezee~g 'peep IIe~ ou 'iie~ sog!UOH 'sg2ed pues ,Y, e I!e% %ne qsnlg e% eu!~q %oe~uI 's~ed pu~s ,~, ~ ile% %no qsnI~ o% ~egeM ecs ~S~N L'IT:MH Z~OS ONILSZL (~ ,0g~L :sa ~OLgL :GL O) 96/6I/0I 861'CCC ~:O,~.~ 0 ~:G,T,.~ 86I'8C ~:H~lO 660'6I '96/8I/0I 's:~q 0010 $ ~T:~ %deoo~ '~I-.~ o% ~I-.~C mo:~ ~T:~ anon 0'0 :MN Ac~ ~t~IFlc~ O,T, ~H $: X~I~fG SaG: A~QS ,0~[zL :Scl ,0 :GL (I O) 96/8I/0I 00-E8~I~-6~0-0§ :HZSNQN IaV 0'XLI~QOZS %0 :IM 96/8I/0I:~HO0 LH~LS ge/90/~t:Gnas :MooTs LIND HZAIH LS~Z ldOqS HLHON :XLNO/~ZH~ :Z~XL ~I~866 :GI DIG~ON:DI~ ~I-~{:q~ZM SNOIL~HZaO NOILZTAHOO GN~ 7~IG~HZ~ 'ONI ~XSV2~ OOH~ , 9'6/6I/II :a%eG ARCO Alaska, In(~ Post Office'. .x ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 April 30, 1990 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Subject: Kuparuk River Field Water Injection Surveys In compliance with Rule 4 of Conservation Order No. 198, KUparuk River Field Waterflood Rules, we are hereby submitting injectivity surveys for Kuparuk water injection wells for the First Quarter, 1990. The data is provided in the form of separate zone surveys or as spinner logs listed in Attachment 1. Injection rates determined by separate zone surveys are also listed in Attachment 1. The blue line and sepia' copies of the spinner logs are also included. If you have any questions concerning the information reported, please contact me at 263-4978. Sincerely, S. E. Schmidt Operations Engineer SES:LLP Attachment ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfigldCompany 3C-02 ~.~3F-12 ~,.-3F-16 fl30-12 02921414 02921493 02921502 02921804 01/09/86 07/05/86 O5/lO/89 08/24/89 o3/ol/9O 11/15/89 11/24/89 03/09/90 SEP ZONE SPINNER SPINNER SPINNER FOLLOWUP .FOLLOWUP FOLLOWUP INITIAL A&C A&C A&C A&C SS SS SS SS 1450 1200 600 3900 6400 40O 6600 450 1450 00266000 00267O00 0027O000 00280000 00290000 00300000 CO310000 00320000 00330000 00340000 00350000 00360000 00370000 Alaska Oil & Gas Cons. commission ARCO Alaska, Inc. Post Office B 360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. (~onversions 3N-11, 3N-10, 3N,05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1 E-lA, 1E-04, 1 E-16 and1E-27 Fractures and Stimulations '3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 perforations 3N-11, 3F-11 and 3N-8A 1E-30 .Failed MIT If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 3N-12, 3N- RECEIVED NOV 1 ~ 1988 0il & t~as Con C4)malssl~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany 1. Type of Request: 2. Name of Operator STATE OF ALASKA~"~'' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 42' FSL; 136' FEL, Sec. 19, T12N, R9E, UM At top of productive interval 1351' FNL, 3361' FEL, Sec. 30, T12N, R9E, UM At effective depth 1451' FNL, 3555' FEL, Sec. 30, T12N, R9E, UM At total depth 1486' FNL, 3623' FEL, Sec. 30, T12N, R9E, UM 7470' MD feet 6093' TVD feet 12. Present well condition summary Total Depth: measured true vertical measured 7452' MD feet true vertical 6003' TVD feet Length Size 115' 16" 3292' 9 5/8" 7540' 7" Effective depth: measured 7246'-7280' MD, true vertical 5846'-5872' TVD, Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Other 6. Datum elevation (DF or KB) RKB 93' 7. Unit or Property name Kuparuk River Unit 8. Well number 3F-12 ~,~ ~ ~-~7, ~,~, 9. Permit number/approval number ~- 249 10, APl number 50-029-21453 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Junk (measured) NONE Cemented 316 Sx AS II 925 Sx PF-E & 410SxPF-C 150 Sx Class G & 175Sx PF-C 7116'-7146' MD 5747'-5770' TVD Tubing (size, grade, and measured depth) 3-1/2", 9.3# 7038' Packers and SSSV (type and measured depth) Otis RRH @ 7038'/Otis "WD" @ 7185' 13. Stimulation or cement squeeze summary feet Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Measured depth True vertical depth 115' MD 115' TVD 3292' MD 2995' TVD 7540' MD 6070' TVD Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations RE£EiVED Ak~.~ ~il& Gas G0ns. C0mlTlissi0n ReDresentative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2072 5822 0 1000 460 0 0 ,10~211 50 1 000 16. Status of well classification as: Oil __ Gas Suspended Service Water In!ecti0n 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 0/6/15/88" SUBMIT IN DUi~i'ICATE ARCO Alaska, Inc.i'r ~ Subsidiary of Atlantic Richfield Company · WELL _ CONTRACTOR ,lARKS IPBDT WELL SERVICE REPOR'I IFIELD - DISTRICT- STATE ,~,~,,,/,,~" .,~,C,-~, ,~',~/,,~/ ~~ IDAYS I ~b~RAfiON At RE~RT TI~E IDATE Gas Cons. Commis$io~ A~hurage '1--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK [ Slgn~ ARCO Alaska, Inc, Post Office 00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: February 26, 1987 Transmittal # 5926 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-8 2H-6 2H-5 3F-13 3F-12 2H-8 2H-7 3F-14 3K-5 3K-3 3K-4 3F-12 CBL 2-16-87 6195-9264 CET 1-17-86 7400-8873 CET 1-16-86 6525-7959 CET 1-7-86 6160-7920 CET 1-23-86 6946-7250 CET 1-1-86 8000-8650 CET 1-1-86 6800-7938 CET 1-7-86 4700-6760 CET 7-16-86 6988-7990 CET 7-14-86 7595-8800 CUT 7-14-86 7793-8787 CET 1-7-86 6050-7416 /' Alaska Oil & Gas Cons. Commissior~ ' Anchorage DI~~ ' N SK Dr i 11 in g : .S:t ate. :(+ :' i s.ep ia)/ BP AE Ch ev r o n SAPC Mobil Unocal Vault (film) ARCO Alaska, Inc. is a Subsidiary of AllanticRichfieldCompany i STATE OF ALASKA ALASK~-, ,.)IL AND GAS CONSERVATION CO~. .... ,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon L3 Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, ]:nc RKB 93' feet 3. Address 6. Unit or Property name PO Box 100360, Anchorage, AK 99510 Kuparuk River Unit 4. Location of well at surface Atlo2¢ F, SL- 136' intEerv~alSeC. of prdducuve F L 19, T12N, R9E, UM 1351' FNL, 3361' FEL, Sec. 30, T12N, R9E UM At effective depth ' 1451' FNL, 3555' FEL, Sec. 30, T12N, RgE, UM At total depth 14R6' FNI ; ~F;?.'q' FFI ~ ReC~ 3fl~ TI?N~ DgF~ I_IN1 11. Present well condition summary Total depth: measured 7470' MD feet true vertical 6093' MD feet ~.FW_ ~1~ number 8. Permit number Permit #85-273 9. APl number 50-- 029 2 I~83 10. Pool K:!par:!k River Oil Pool Plugs (measured) None Effective depth: measured true vertical Casing Length Structural Conductor 115' Surface 3292' Production 7450' xx~RR"xxxxxx Perforation depth: measured true vertical 7452' MD feet Junk (measured) None feet 6003' MD Size Cemented Measured depth 16" 316 SX AS11 115' MD 9-5/8" 925 SX PF-E 3292' MD 410 SX PF-C True Vertical depth ,1 150 SX Class G & 7540' MD 175 SX PF-C 7246'-7280' MD, 7116' -7146' MD 5846'-5872' TVD, 5747'-5770' TVD Tubing (size, grade and measured depth) 3-1/2" 9 3# 7038' , · Packers and SSSV (type and measured depth) Otis RRH @ 7038'/0tis "WP" @ 7!85' 12.Attachments Description summary of proposal [] 115' TVD 2995' TVD 6070' TVD Detailed operations program [] BOP sketch [] Conversion from prnductinn tn wai'.~r in~ntion into the A & C Sands_ 13. Estimated date for commencing operation July 3, 1986 14. If proposal was verbally approved Name of approver Mi ke Mender,;-, "' · July 3, 1986 15. I hereby, certify that the foregoing is true and correct to the best of my knowledge Signed ,,4/, ,, ~¢,¢~::~",~.~,,Z,.',-/ Title Sr. Operations Engineer Commission Use Only D~y 3, 1986 Conditions of approval Approved by Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Form 10-403 Rev 12-1-85 NO. Commissioner by order of the commission Date '7 "~/ Submit in triplicate MEMORA, UM 'Sta, of Alaska ALASKA OIL A~D GAS CONSERVATION COI~MI!~,o~O~ TO: C. V/. ~~terton DATE: July 11, 1986 Chai~ F~LENO.: D.BDF.54 THRU: FROM: Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector TELEPHONE NO.: SUBJECT: Mech Inte§rit¥ Test ARCO KRU 3F- 12 Kuparuk River Field Wednesday,. J..u.!y 2, 1986: The test began at 9:55 a.m. and was c0~ciuded at 10:30 a.m. As the attached documents show, the test on the 7" casing, performed in accordance with AOGCC regulations 20 AAC 25.030(g), 20 AAC 25.412(c) and 20 AAC 25.252(d), was successful. In summary, I witnessed the mechanical integrity test on Standard Alaska Production Company well 3F-12. 02-001 A ( Rev 10-84) ..~. :,' ';. 1 STATE OF ALASKA "' ALASKA O~L AND GAS CONSERVATION C(~v~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL~ GAS [-] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-273 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21483 4. Location of well at surface 9. Unit or Lease Name 42' FSL, 136' FEL, Sec.19, T12N, R9E, UM Kuparuk River Unit At Top Producing Interval 10. Well Number 1351' FNL, 3361' FEL, Sec.30, T12N, R9E, UM 3F-12 At Total Depth 11. Field and Pool 1486' FNL, 3623' FEL, Sec.30, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 93' RKB ADL 25643 ALK 2574 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1 2/06/85 1 2/10/85 1 2/1 2/85*I N/A feet MSLI 1 , , 17. Total Depth (MD+TVD) 18.Plug Ba~:k Del~th (MD+TVD) 19. Directional Sur'vey I 20. Depth where SSSV set 21. Thickness of Permafrost 7570 'MD ,6093 'TVD 7452 'MD ,6003 'TVD YES~ NO []I 1791 feetMD 1500' (Approx) , 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL/GR/Cal, Cal, GR, CET/GR/CCL, GCT, CRT ., 23~ ...... CASING, LINER AND cEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H'-40 Surf 1i5' 24" .... 3'16 sx'AS II ..... 9-5/8" 36.0# J-55 Surf 3292' 12-1/4,, 925 sx PF "E" & 410 sx PF "C" , 7" 26.0# J-55 Surf 7540' 8-1/2" 150 sx Class G & 175 sx PF "C" '24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING REcoRD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) .... 7246' - 7280' w/4 spf 3-1/2" 7209' 7038' & 7185' 7116' - 7146' w/12 spf 26. ' 'ACID, FRACTURE, CEMENT sQuEEZE, ETC. DEPTH IN'~ERVAL(MD) AMouNT& KIND OF MATERIAL USED 7206' - 7208' 150 sx Class 6 See.,. addendum ;ttacfed to Well Completion Report. dated 3/31/86.. '27.N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours'Tested'" PRODUCTION FOR 'OIL-BBL GAS-MC'F ' WATEI~-BBL" CHOKE S'I'ZE 'l G.A'S~01L RATIO ' ' TEST PERIOD I~ I Flow Tubi'ng ca$in'~ Pressure cALCULATED' OIL-BBL G'AS-~CF' WATER BB'L' '0IL GRAvIT~ APl (c°rr) .......... Press. 24-HOUR RATE ~ 28. CORE DATA Brief description of 'l'iih01ogy, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. JUN 2 6 19~6 Alaska 0it & G~s Cons. Commi~,sio'~, Anchorage Form 10-407 * NOTE: Tubing was run & well perforated 1/25/86. WC1/054 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS 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 7115' 5746' N/A Base Kuparuk C 7147' 5771' Top Kuparuk A 7236' 58~8' Base Kuparuk A 7339' 5917' 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed (~ ~ ~ Title Associate Engineer Date 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 a's 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 (G L) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng 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 STATE OF ALASKA ( , ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~XX GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-273 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21483 4. Location of well at surface 9. Unit or Lease Name 42' FSL, 136' FEL, Sec.19, T12N, R9E, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 1351' FNL, 3361' FEL, Sec.30, T12N, R9E, UM 3F-12 At Total Depth 11. Field and Pool 1486' FNL, 3623' FEL, Sec.30, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Kuparuk River 0il Pool 93' RKB ADL 25643 ALK 2574 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore 116. No. of Completions 1 2/06/85 1 2/10/85 1 2/1 2/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey 20. Depth where SSSV set 21. Thickness of Permafrost 7570 'MD ,6093 'TVD 7452 'MD ,6003 'TVD YES [~(X NO [] 1791 feetMD 1500' (Approx) 22. Type Electric or Other Logs Run D IL/SFL/SP/GR, FDC/CNL/GR/Cal, Cal, GR, CET/GR/CCL, GCT, CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not yet received. 9-5/8" 36.0# J-55 Surf 3292' 12-1/4" 925 sx PF "E" & 410 sx PF "C" 7" 26.0# J-55 Surf 7540' 8-1/2" 150 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7246' - 7280' w/4 spf 3-1/2" 7209' 7038' & 7185' 7116' - 7146' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7206' - 7208' 150 SX Class G See attached Add..ndum, dated 2/27/86. 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~l~ Flow Tubing Casing Pressure CALCULATED.I~:OIL'BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE RECEIVED APRO 1986 Alas~ Oil & Gas Cons. Commission Anchorage Form 10-407 * NOTE: Tubing was run & well perforated 1/25/86. GRU13/WC14 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS 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 7115' 5746'I N/A Base Kuparuk C 7147' 5771' I Top Kuparuk A 7236' 5838' Base Kuparuk A 7339' 5917' ., 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer Signed ~~ ~ Title Date 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 rneasurennents 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: Atta"ch'ed Sbpp[e~:ental records for this well should show the details of any multiple stage cement- ing and the I,.o,.~cation of the cementing tool. Item~.27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- j ec t i ~i:~.~?~:~.:'i ni"e¢ ,ti o:n ~:~ S I~ U.t? i ,n... ,.;,?:~.:t..h e r-e x plain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 12/23/85 1/09/86 2/11/86 3F-12 Arctic Pak w/175 sx PF "C", followed by 54 bbls Arctic Pak. Rn CET/GR/CCL f/7416'-6100'. Rn GCT gyro f/7422'-40'. Begin frac work at 1725 hrs, 2/11/86. AFE AK0502 Frac'd Kuparuk "A" sand perfs 7246'-7280' in 3 stages per 2/10/86 procedure using gelled diesel w/20/40 mesh, 8 ppg sand. Press'd ann to 1880 psi w/diesel. Tst ins to 7950 psi; OK. Pmp'd 40 bbls 5% Musol + 64 bbls diesel @ 3/4 BPM, 2600 psi prior to start of frac. Stage 1: 18 bbls gelled diesel @ 7.4 BPM w/final pressure of 3270 psi. Stage 2: 21.5 bbls gelled diesel w/20/40, 8 ppg sand @ 8.4 BPM w/final pressure of 2050 psi. Stage 3: Lost prime @ end of sand stage. Pmp'd total of 62 min & 66 max of gelled diesel flush behind the 20/40 sand, 8 ppg stage @ 3400 psi. M&P 6048# 20,40, 8 ppg in formation leaving questionable amount in 7" csg. Load to recover 203 min bbls of diesel. Job stopped @ 1808 hrs, 2/11/86. Drilling S~perintendent z D~te ARCO Alaska, Inc. { Post OfficeB~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3F-12 Dear Mr. Chatterton- Enclosed are the Well Completion Report and gyroscopic survey for 3F-12. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L123 Enclosure ARCO Alaska, inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA · ALASKA fL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL E~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-273 3. Address 8. APl Number P. 0. Box 100360~ Anchorage~ AK 99510 _ 50- 029-21483 4. Location of well at surface LOCATIONS 9. Unit or Lease Name 42' FSL, 136' FEL, Sec.19, T12N, R9E, UM YE~IF~D Kuparuk River Unit At Top Producing Interval Surf. ~'... 10. Well Number 1351' FNL, 3361' FEL, Sec.30, T12N, RgE, UN B.H._~___ 3F-12 At Total Depth 11. Field and Pool 1486' FNL, 3623' FEL, Sec.30, T12N, R9E, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 93' RKBI ADL 2564:~ ALK 2574 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. 15. Water Depth, if offshore I16' No. of Completions 1 2/06/85 1 2/10/85 1 2/1 2/85* N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MEM-TVD) 19. DirectionaISurvey 20. Depth where SSSV set 21. Thickness of Permafrost 7570 'MD ,6093 'TVD 7452'MD~6003'TVD YES E~X NO [] 1791 feet MD 1500' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR: FDC/CNL/GR/Cal: Cal.. GR. CET/GR/CCL. GCT. CET 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 Surf 115' 24" Conductor report not y,;t ,received. 9-5/8" 36.0# J-55 Surf 3292' 12-1/4" 925 sx PF "E" & 410 sx PF "C" 7" 26.0# . J-55 Surf 7540' 8-1/2" 150 sx Class G & 175 s; PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7246' - 7280' w/4 spf 3-1/2" 7209' 7038' & 7185' 7116' - 7146' w/12 spf 26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 7206' - 7208' 150 SX Class G 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OILGRAVITY-API (co'r) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ......... ~,~,~ ~ ~ ~ .,,~,~ ,,, ,~ Form 10-407 * NOTE: Tubing was run & well perforated 1/25/86. TEMP3/WC71 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 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 7115' 5746' N/A Base Kuparuk C 7147' 5771' Top Kuparuk A 7236' 5838' Base Kuparuk A 7339' 5917' 31. LIST OF ATTACHMENTS ........................ (t2r e aC~c~ r)r 32. I hereby~ert1'fy thattnetorego~ngis u co ect to the best of my knowledge Signed ~ //~~' ~J~(LA~I~, Title A_~_~nmi~-.~_ Fnn~n..r' Date ~'/2-~ 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 jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 AtlanticRichfieldCompany ~ Daily Well History-Initial Report IIIItlllcltOltl: Prepare snd submit the "Initial Rlq~ort" on the first Wednesday after · well is spudded or workover operations ere started. Dally work prior to sPudding shouid be summarized on the form giving inclusive dates only. _. Dlstdct J County or Perish I Alaska Field ILease or Unit I Kuparuk River Auth. or W.O. no, ~Title I AFE AK0502 Doyen 9 North Slope Borough IState Alaska ADL 25643 .. Drill Well no. 3F-12 AP1 50-029-21483 Operator ARCO Alaska, Inc. Spudded or W.O. begun IDate Spudded I Date and depth a~ of 8:0~ [2/07/85 thru 12/09/85, [2/[o/85 Complete record for each day reported 12/6/85 A.R.Co's W.I. IH°ur 1445 h~:s, IPflcr at'rue If e w'°' 56.24% 9-5/8" @ 3292' 3688', (3578'), Navi-Drl Wt. 8.5, PV 1, YP 2, PR 9.5, WL 24.4, $ol 1 Accept rig @ 1300 hfs, 12/6/85. ND diverter sys. Spud well @ 1445 hfs, 12/6/85. 16" @ 115~. Drl to 1291', Navi-Drl & sum to 3048', short trip, C&C, POE. RU & rm 83 ]~s, 9-5/8", 36~, J-55' BTC csg w/FC @ 3211', FS @ 3292'. Cmt w/925 ax PE "E" & 410 sx PF "C". Displ usin$ rig pmpe, bump plug. CIP @ 1235 hfs, 12/8/85. ND diverter. ND & cst BOPE. RIM, Cst cas to 2000 psi. DO FC, cmt, FS, drl to 3317'. Conduct formation tat to 12.5 ppg EMW, POE. RIH, Navi-Drl & surv 8~" hole to 3688'. 1405', 1.3°, N60.75W, 1405.0 TVD, 0.8 VS, 0.6N, 1.0W 1701', 9.5°, S76.25W, 1699.6 TVD, 24.4 VS, O.OS, 26.2W 2019', 19.9°, S70.25W, 2006.5 TVD, 105.4 VS, 21.1S, 104.9W 2648', 37.3°, S75.25W, 2555.5 TVD, 405.1VS, 99.8S, 395.8W 3270', 48.5°, S71.25W, 3020.1TVD, 816.1VS, 226.4S, 787.7W 3378', 49.5°, S71.25W, 3091.0 TVD, 897.5 VS, 252.6S, 864.9W 9-5/8" @ 3292' 6998', (3310'), Navi-Drl Wt. 9.8, PV 13, YP 6, PH 9.5, WL 6.0, Sol 9 Navi-Drl & surv 8½" hole to 6998'. 3630', 46.8°, S71.25W, 3262.6 TVD, 1081.9 VS, 311.9S, 1039.6W 4320', 47.2°, S70.25W, 3732.7 TVD, 1586.8 VS, 480.7S, 1515.7W 4950', 47.3°, S65.25W, 4156.0 TVD, 2052.9 VS, 664.1S, 1944.5W 5265', 47.4°, S65.25W, 4369.5 TVD, 2284.2 VS, 761.1S, 2154.9W 6007', 41.2°, S65.25W, 4902.7 TVD, 2798.8 VS, 974.9S, 2623.9W 6743', 40.3°, S64.25W, 5466.2 TVD, 3271.3 VS, 1172.9S, 3053.9W The above is correct Signature For f orm~reparatt~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillins Superintendent ARCO Oil and Gas Company ,a~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Rel~3rt" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be usac~ for reporting the entire operation if space is avaHal3le. District lCounty or Parish Alaska [ North Slope Borough Field ~Lease or Unit Kuparuk River I ADL 25643 Auth. or W,O. no. ~ Title AFE AK0502 I Drill API 50-029-21483 f Accounting State cost center code Alaska Doyen 9 no. 3F-12 Operator I A.R,Co. W.I. A_RCO Alaska, Inc. I 56.24% Spudded or W.O. begun Date Spudded 12/6/85 Date and depth as of 8:00 a.m. Complete record for each day reported Old TD Released rig 12/11/85 12/12/85 0500 hrs. I otal number of wells (active or inactive) on this est center prior to plugging an(~ bandonment of this well I our ~Prlor status If a W.O. 1445 hrs. Classifications (oil, gas, etc.) Oil Flowing Producing method 9-5/8" @ 3292' 7570', (572'), RIM Wt. 9.8+, PV 12, YP 8, PR 9.0, WL 5.9, So1 9 Navi-Drl & surv to 7570', short trip to 3292', C&C, POH. RU Schl, RIH, log DIL/SFL/SP/GR f/7571'-3295', cent w/GR to 1700'. Log FDC/CNL f/7380'-6900', 5500'-5100' & 4200'-3800', CAL f/7557'-3800', RD Schl. RIH to cond f/csg. 6992', 41.27, S64.25W, 5654.8 TVD, 3433.4 VS, 1243.6S, 3200.3W 7490', 39.4°, S64.25W, 6034.1TVD, 3755.1VS, 1383.8S, 3491.0W 7" @ 7540' 7452' PBTD, RR Wt. 9.8+, PV 12, YP 7, PH 9.0, WL 5.8, Sol 9 Fin RIH, C&C, 20 std short trip, C&C, POE. RU & rn 173 Jts + 2 mkr its, 7", 26#, J-55 BTC csg w/FS @ 7540', FC @ 7450'. Cmt w/150 sx C1 "G" per procedure. Bumped plug. ND BOPE, NU 7" pack-off & lower well head. Tst pack-off to 3000 psi. RR @ 0500 hfs, 12/12/85. New TD I PB Depth 7570' TD I 7452' PBTD Date Kind of rig 12/12/85 Rotary Type completion si_(~0.gle, dual, etc.) Single Official reservoir name(s) Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T,P, C,P, Water % GOR Gravity Allowable Effective date corrected The above is correct Signature [ Date ITitle I I For form ;reparation and di~tribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Well History - Initial Report - Daily Inltructiolll: Prepare and subnlit the "Initial Report" on the first Wednesday after a well is spudoed or worKover operations are startect. Daily work prior to SPudding shoulcl De summarizeD on the form giwng inclusive dates only. District Alaska Fiela Kuparuk River Auth. or W.O. no. AFE AK0502 Nordic 1 Operator ARCO Alaska, Inc. ICounty. par,sm or borougm North Slope Borough Lease or Unit APL 25643 ITifle Completion API 50-029-21483 IState Alaska IWell no. 3F-12 IARCO W.I. Prior status if a W.O. Spudded or W.O. begun Complete Date I [Hour /21/86 Oate and depth as of 8:00 a.m. 1/22/86 1/23/86 1/24/86 Complete record for each day reported 2000 hrs. 7" @ 7540' 7452' PBTD, RIH w/RAM 9.8 ppg NaC1/NaBr Accept .ri~ @ 2000 hrs, 1/21/86. NU & tst BOPE. RU Schl, RIH & perf w/4" gun, 4 SPF, 7206'-7208'. RIH & set BP @ 7260'. RIH w/Bkr RAM on 3½" tbg. 7" @ 7540' 7452' PBTD, TIH to cmt 9.8 ppg NaC1/NaBr Set sqz pkr @ 6950'. Est IR @ 3 BPM, 2400 psi. Batch mx 150 sx cmt. Perform hesitation sqz w/final press of 2500 psi. No leak-off. Inj 22 bbls cmt into formation, rev out, POH w/pkr. PU bit, TIH to 6470' & WOC. Rn CET log 7" @ 7540' 7452' PBTD, DO BP 9.8+ ppg NaC1/NaBr Drl cmt f/6995'-9258'. Tst sqz perfs w/2000 psi. f/7240'-7010'. TIH to DO BP. 56.24% The above is correct Signature For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate . Title Drilling Superintendent ARCO Oil and Gas Company .~' Daily Well History-Final Report Instructions: Prepare and suomH '.he "Final Report" on the hrst Wednesday after allowable has Peen assigned Or well ,S Plugged. APandoned. or Sold. "Final Rel3ort" should me su~r~ltte~ also when op~ations are suspended for an ,ndehnHe or appreciable length of hme On workovers when an official test ~s not required upon completion, repor~ completion and representative test ~ata m blocks prowded The "Fill&l Report" form may be used for reporting the entire ooerahon ,t space ~s ava,;ab,e Distract ICouniy or Pamsh Alaska I North Slope Borough Field Lease or Urn! Kuparuk River APL 25643 Auth. or W.O. no. ~ Title AFE AK0502 / Completion Nordic 1 API 50-029-21483 Operator ARCO Alaska, Inc. tAccountmg cost center code state Alaska Well no. 3F-12 Spudded or W.O. begun A,R,Co. W,I. 56.24% IDate 1/21/86 Complete Da~e and depth as of 8:00 a,m. 1/25/86 thru 1/26/86 :Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and I banclonment of tills well I our I Prior status if a W.O. I 2000 hrs. 7" @ 7540' 7452' PBTD, RR Diesel DO BP, push to PBTD. Chg over brine, POH. RU Schl, perf w/4" gun, 4 SPF, 90° phasing f/7246'-7280' & w/5" gun, 12 SPF, 120° phasing f/7116'-7146'. Make gage ring/JB rn. RIH w/WD pkr, set @ 7169' RD Schl. RU & rn 229 its, 3½", 9.3#, J-55 EUE 8RD tbg w/S~SV @ 1791', RRH Pkr @ 7038', WD pkr @ 7185', "D" Nipple @ 7201', TT @ 7209'. Set & tst pkr. Tst SSSV. NU & tst tree to 5000 psi. Displ well to diesel. Set BPV. RR @ 2100 hfs, 1/25/86. Old TD Releasec~ rig 2100 hrs. Classifications (o11, gas, etc.) 0il New TD PB Depth 7452 ' ?STP Date IKind of rig 1/25/86 I Rotary Type completion (single, dual, etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no, Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day ~ump size, SPM X length Choke size T,P. C,P. Water % GOR Gravity 'Allowable Effective date corrected The above is correct Signature Date ITitle For form preparation and dist~bution, see Procedures Manual, Sect[on 10, Drilling, Pages 86 and 87. Drilling Superintendent SUB-SURFACE DIRECTIONAL $URVEY r-~ UIDANCE ~ONTINUOUS r'~OOL Company Well Name , Field/Location ARCO ALASKA INCORPORATED 3F-12 (42'FSL, 136' FEL, S19, T12N, R9E) KUPARUK, NORTH SLOPE, ALASKA Job Reference No. 71176 Loac3ed By: G. SARBER Date 08-JAN- 1986 Computed By; MARILYN OGDEN $CT CIR~CTIDNAL SUqV=Y 3US T,,',4: R LISTrN2~ ~RC] 6L&SK~ Z~~. 3F-12 NORTH SLOP:.~L~SK~ SURV:Y ]~T=: ~ETHDDS O= CD~DUT&TID~ TDDL LDC~TIDN: T~NSENTZ&L- INTERP]L~TIDN: LINE&R VERTICAL S~CTZDN: tORIZ. OIST. ~VEq&G;] DE~i&FION PRDJ:'T~9 2~T3 'a T~qS:T 6ZI~UTq '3~ STUTM 6~ Oz~ 43 ARCO ~LAS~A, I~C. 3~-lZ KJPAR:JK N3RTH SL3:~E,AL~SKA C g ~PUT ~ T ,"Z. 3',1 O~TE: A!aska Oil & Gas Cons. uomi'n!~s,on l P,I T: ~ P 0 C l'~'~!l~ra~a, k J E S FOR TRUE SJB-SE~ MEASURED VERTICAL VERTICAL DEPTH DEPTq DEPTH O.OD 0.00 -93.00 100,00 100,00 ?,00 200,00 200,00 107,00 300.00 '300.00 207.00 ~O0.O0 ~00.00 307.00 $~0.00 500.00 ~07.00 $00,00 600,00 507,00 ?00.00 700,00 507,00 800.00 799,99 705,99 900.00 999.99 805.99 1000o00 999,99 905.99 1100.00 1099.99 1005,99 1200.90 1199,98 1105.98 1300,00 1299,35 1205,98 1400.00 1399.97 1305.97 1500,00 1499.86 la05,85 1500,00 1599,52 1505.52 1700.00 1898,56 1605,56 1800.00 1796.52 1703.62 1900.03 1893.21 1800.21 2000.00 1988,21 1895,21 ZlO0,O0 2081.$4 1988.64 2200,00 2173,39 2080.09 2300.00 2252,26 2159.26 2,00.00 23,9.11 2255.11 2500.00 2~33.39 2343.39 2800.00 ~ 3.94 2580.94 2900,00 Z?~2.3Z 2659,32 3200.00 28?7.90 3300.00 3037.20 2944.20 3~00.00 3102,11 3009,11 3500.00 3166'.96 3073.94 3500.00 3234. 17 3141.17 3700.00 3302.38 3~09.38 3800.-00 ~370.55 3Z77.65 3900.00 3~38.78 3345.78 COJRSE 3EVI~TI3~ AZIMUTH lEG ~IN DEG MI~ 19 31 22 15 31 11 33 51 36 5 37 49 37 52 39 18 41 53 44 19 47 15 49 13 49 39 48 ~7 46 59 S 69 7 w S 57 ; 4 S 68 52 w S 74 1~ 4 S 75 31 W S ?2 34 W S 71 57 W S 69 59 W S 70 ZZ W S 69 39 W S 69 51W S 73 5 ~ S 69 52 W S $9 32 W S 59 ~ W S 59 1D g S 68 55 W S 58 ~5 ~ 25-J'~N-B5 VERTICAL D05LEG RE'TAN SECTION SEVeRiTY N3RTH/ ~EET D~S/lO0 =~= 0.00 O.OZ 0.15 0.23 0.45 :).77 1.19 1.63 1.Sq. 1.54 0.70 -0.20 -0.68 -0.62 3.41 11.35 25.32 44.68 70.38 0.3i 3.15 0.05 0.10 0.18 0.30 0.49 101.48 137.08 177.50 22!.64 27! .78 325.0~+ 331.30 442.06 503.30 565.37 3ULAq CJDR SOUT~ EAST T 530.60 598.71 770.44 3q~5.27 921.32 997.a5 1071.46 1144.58 1217.66 1290.86 3 i q,i T ~5 S /W:ST T 0.05 i.I~ 'q 1.21 0.53 1.24 ',! 0.26 3.50 0.?9 'I 0.~2 0.2~ 0.35 :~ 0.53 2.75 0.24 N 0.54 2.47 1.39 ~ 5.0~ 3.4~ 1.D) '~ 13.1~ 3.05 1.58 5 25.55 3.75 6.~6 S 45.18 3.;7 13.5~ S 70.2~ 3.3~ 3.20 3.25 3.55 2.52 3.32 1.0~ 2.59 2.71 1 3.1~ 0.94 2.33 0.60 -9.1~ 3.37 9.33 9.33 W 10 !.75 4 13 '3.13 W 17 3.'01 1.05 ~,~ 3.42 '~, 32 9.07 5.90 W 5.60 W 50 4.09 ~ 55 23.17 S 9 35.37 S 13 52.28 S 17 55.57 S 21 7~.51 S 26 ~3.~1 S 31 10~.~3 S 36 121.97 S 42 '!4O.O0 S 48 150.8~ ~ 54 182,39 S 605,51 W 53 !35.17 S 669.5% W 70 231,09 S 736.81 W 77 Z55.$5 S 807.15 282.57 S 878.64 W 308.93 S 950.11 W 335.20 S 1019.33 W 361.13 S 1087.66 W 1i4 387,23 $ 1155,92 W 1gl ~13.71 S 122~.13 W 129 ,31~T. F::T 3..]5 ,3.22 O. 53 1.57 2.14 C- · 1 · 73 1.27 O. ~0 ~.54 9 · ) 9 b'. 5 · 30 !.J~ 2.53 7.73 7.J3 3.17 3.55 3.-)) 5.3'3 7.35 2.53 0.55 Z. 20 !.99 ~.07 3.31 '5.05 9.37 &llqiJTH S 73 11 4 S 72 53 ;~ S 72 35 ~ S 72 Z1 ~ S 71 59 ~ S 7! 47 ~ S 71 37 a 5 71 g 3 N 5 71 19 4 Cg~PUT~TI3q DATE: 25-J~N-~S P~,J~ Z A~SO ~LASKA, INC. 3:-12 KJPARJK NO~TH SLOOE,AL~SK~ D~T~ .}": S JR'VEl: KF. LLY ~USH~".~$. ~LZ¢'"TZ]"J: ~3.J~'~. F" INT~RPOL&TFD VALJES FOR EVEN 100 FEET O: ME~SURE3 2EPTH TRU; SJB-SE~ MEASURED VERTICIL V:RTI'AL ]=PTi DEPTH DEmFH COJRSE V:RTICAL DOG~ EG ]EVI&TI]I AZIMUTH SECTION SEV:RiTY 2;G ~tN DEG MIN ~EET DES/lO0 ~O00.OO 3505.55 3~13.65 4100.00 3574.71 3~81.71 4200,09 36~2,88 3549.88 4300.00 3710.96 3617.96 4~OO.OD 3778.74 3685.74 4500.00 3845.37 3753.07 4500.00 3912.53 3819.63 4700'00 3979.36 3885.36 4800,00 4047.19 395~.19 4~D0,33 4115,10 ~022.10 47 13 S 68 38 W I36q.29 0.23 47 Z S 5~ 28 W 1437.56 0.0~ 47 1 S 5~ 25 W 1510,72 0,15 47 11 S 58 15 W 1583.96 0.28 47 30 S 58 5 '~ 1557.49 0.~7 47 54 S 55 25 W 1731.40 2,83 48 25 S 5~ 34 W 1805.83 3.42 47 34 S 63 1T W 1880.11 1.67 47 14 S 52 38 W 1953.19 3.03 47 18 S 52 44 W Z025.19 0.33 5DDO.OD ~182.78 ~08~.78 5100.00 ~250.28 ~157.23 5Z00.00 ~318.02 ~225.02 5300.00 ~385,58 ¢292,58 5~00.00 ~454.79 ~351.7-~ 5500.09 ~525.3~ 4432.3~ 5500.00 ~596.~6 ~503.45 5700.03 ~668.58 ~575.58 5800.00 ~741.52 ~54B.52 5900.00 ~815.21 ~722.21 47 29 S 52 45 W Z099.42 3.13 47 28 S 52 50 W 2172.80 47 !3 S 62 45- W 2245.98 0.2~ 47 11 S 6Z 48 W 2319,21 1,5~ 45 25 S 53 49 W 2391.15 44 55 S 63 55 W 2461.77 0.3~ 44 13 S 53 53 ~ 2531.82 43 29 S 53 49 W !600.84 3.72 42 50 S 53 ~8 W Z559,00 0.77 42 14 S 63 4~ W 2736,34 0,5~ 6D50.OO ~889.75 ~795.75 6100.00 %965.17 4872.17 6200.00 5041.25 ~9~8.25 6300.00 5118,)8 5025,08 6400.00 5195.55 5102.55 6500.00 5274.13 5181.13 6500.00 5.353.27 5260.27 5700.00 5430~81 5337.81 6800,00 ~5Q?.~12 5~14.12 41 23 S 63 33 W Z802.75 0.73 40 ~4 S 63 18 W 2858.12 3.49 40 9 S 63 1~ W Z932,73 0,53 39 31 S 63 1~ ~ 2995,45 0,43 38 $2 S 52 23 W 305~,39 2,40 37 50 5 60 17 W 3120,67 ~,77 38 5 $ 50 2 W 3181,13 1,65 40 9 5 50 32 W 3243,55 1,62 39 54 $ 60 35 W 3307,54 $,87 40 13 S 61 ~ ~ 3370,87 2,34 41 8 S 62 43 W 3435,94 0,97 40 ~2 5 52 51 W ~501,10 0,35 40 39 $ 62 45 W 3565,85 0,3~ 40 35 S 52 35 W 3630.65 39 59 S 62 35 W ~69~.~6 39 59 S 62 36 W 3758.76 39 59 S 6! 35 W 3803.49 RE'TAN NORTH/ 3JLAR C3']~OIN&TE~ ~]~£Z. S,]dTH EAST/W:ST 3E~&RTJq~ ~'I~UTH 3=3 'qlN 440.~0 S 1292.59 ~ 1365.55 $67.19 S 1~63.7:~ W 1~35.75 521.05 S 1495.~2 W 1555.~1 54~.35 S 1555.19 W 155~.47 575.46 S !633.~7 N 1732.39 $07.3~ S 1701.25 W 1305.$3 540.~J S 1763.25 W 1~80,.35 57~.00 S 1833.50 W 1~53.55 737,79 S 139,5.;~2 W Z325.41 7~1.3~ S 1964.~.8 W 239).54 775.39 S 2029.~1 W 2172.95 908,58 S 2095.35 W 22~5.~9 342,~5 S 2160,7~ W 2319,21 374.~3 S 2225,34 W 2391.15 906,06 S 22.~9,01 W 2~61.31 936.'9~ S 2352.14 W 2531.)3 967.51 S 241~.31 W 250J.95 ~97.59 S 2475.71 W 255).1~ 1327.56 S 2535.34 W 2735.5) S 5.~ S 5~ > 5 i) 24 S 53 15 S ,5 ! 9 S 5 ~ S 57 5~ 1357. I 3.-36. 1115. 1144. 1173. 1~_02. 1233. 1254. 12')6. 1327. 1358. l~+lB. 1~77. 1507, 152'3. 17 S 25'95.0~ W 2~03.09 53 S Z654.7~ W 7~ S 2712.75 W 2~33.25 03 5 2825.3~ W 3053. 1 3 98 S 2880,47 W 3121.5 3 39 S 2933,51 W 3152,25 83 .S 2988,26 ~ 324.$. ~2 ~2 S 3044,63 W 330).15 ~;3 S 3100,34 W 3372, ~ S 67 50 S 57 ~4 S 57 3~ ~ 67 27 ~ ~7 19 S 67 11 5 5 7 .3 S 5'3 56 S 65 43 ~5 S 3158.25 W 3~,33.32 35 S 3;~i5.56 ~ 3503.3'~ 08 S 3277+.46 W 3368.33 30 S 3332.33 W 3533.3~ 74 S 3389.66 W 3597.77 31 S 3445.72 W 3751.3'~ S1 S 348.3,65 W 3305. 73 3 35 43 S 55 3'9 S 55 35 3 55 30 S 53 22 S 55 /_ COMPUTATISN DATE: 25-J~N-85 ARCO ALASKA~ I~C. 3=-12 KUPARUK N]RTH SLOPE,ALaSKA INTORPOL~TED VALUES FOR EVEN 1003 FEET TRU5 SJ~-SS& ME~SUREO.VERTI=~L VERTICAL 2EPTH OEPT5 DEPTH CSJRSE V=RTIC&L DOGLEG ]EVI~TID~ ~ZIMj'TH SECTION SEV:RITY 2EG MIN DEG MI~ FEET 9;8/103 0.00 0.00 -93.00 1000.00 999.99 2~O0.OO 1988,21 199~.21 3000.00 2828.36 2735.06 %000.00 3505.55 3413.65 5000.00 %182.78 ~D89.78 60DO.OO ~8~9.75 ~795.75 ?000.00 5559.55 5555.55 7570,00 5093.~$ 0 0 N 0 O E 0.00 0.00 0 32 N ~0 32 E 0.70 0.05 19 31 S 6g ? W 101.~8 3.33 ~? 13 S 68 3B W 136~.29 3.23 47 29 S 82 45 W 2099.42 0.13 ~1 !3 S 53 30 W 2802.75 O.7a 41 8 S 62 ~3 W ~&35.9~ o.gT 39 59 S $2 ~35 W 3~03.49 0.03 ]AT~: g= SJRVEY: qELLY 5dSdI"~'~ :L'-TAT[3'.~: ,=T E] D:PT ~CTANSiJLAR CD NgqT~/S3UT~ ~A 0.30 N 1.19 W 23.17 S 9 1~2.39 S 60 T41.33 S 196 1957.!7 S 259 1355.~5 S 315 152~:~.01 S 3~ 3RgI'~AT~: S ST/'~EST = E T 0.00 5.51 2.5-~ 4.25 $.0~ 3.25 5.6~~ ~39ZZ. 3IST. FEET 0.30 1. 7:) i32.53 532.53 1365.55 g 5 O .3.0 '3 3~33 · 32 3 ~ '25. 73 ARCO ~.LAS~,A, T~IC. 3=-12 KJPa. RLIK N3RTH SL3F~E, ALD, SK~ '4E~SU DEPTH 0'.00 :33.00 193.00 2-33.00 393.00 493.00 593.03 $93.00 T93.01 893.31 9~3.0! 1003.01 1193.0Z 1293.0Z 1393.02 1493.13 1593,4¢ 1694.37 1796.7_9 18)9.78 2005.09 2112.25 2222.18 2334.9T 2451.70 ZE?Z.EZ 2697.45 2824.1'0 2953.23 3088.50 3232.82 3385 3539..~3 3686.25 3832.80 3979.8'9 4126.85 4Z73.57 ~,Zl~l~ 4570.41 TRUE RED VERTI'~L DEPTq 0.00 93.00 193.00 293.00 393.00 493.00 593.00 693.00 793.00 893.00 993.00 1093.00 1193.00 1293.00 1393.00 1493.00 1593.00 1693.00 1793.00 1893.00 1993.00 Z093.00 2193.00 2293,00 Z393.00 2493.00 2593.00 Z693.00 279 3.00 2893 · 00 3293'. O0 3393.00 3493.00 3593.D0 3693.00 3793.00 3893.00 COMPUT&TIgN DATE: 25-J~N-B5 ZNTERDOL~TED VALJ:S FOR ~VEq 100 FEET OF SJB-SEA COJRSE VSRTIC~L gO$LEG V:RTI'~L ]EVIqTIDN AZIMJTq SECTION SEVeRiTY DEPTH DEG MIN DEG MI~ F~T DES/lOg -93.00 ].00 100.00 203.00 300.00 ~03.00 500.00 500.00 700.00 803.03 900.00 1000.00 llOD,O0 1202,00 1300.00 1403,00 1500,00 1503.00. 1700.00 1803.00 1900.00 2000.00 2100.00 2200,00 2300.03 2400.00 2503.00 2500,00 2TOD,O0 2800.00 2900.00 3003.00 3100.00 3200.00 3300.00 3400.00 3503.00 3600.00 3700.00 3800.00 0 0 0 7 0 10 0 11 0 12 0 la 0 16 0 15 O. 8 0 Z1 0 31 0 0 ZO 0 13 1 27 3 !7 5 ¢5 9 21 12 59 16 19 39 22 39 26 5 29 32 36 35 28 37 37 38 60 52 43 58 48 7 49 37 47 57 47 0 47 1 4.7 15 47 4.7 8 ~7 35 4.8 22 N 0 9 E 0.00 O.OD S 75 D W 0.00 0.35 N 34 1 W 0.14 0.15 ~ ~5 19 ~ 0.22 3.07 N 67 7 W 0.~3 3,05 N ~2 23 W 0,7~ 3.1~ N ~8 41 W 1.lb 0.03 N 75 27 W 1.51 0,20 N 35 O W 1.83 0.28 N 73 35 E 1.58 0.66 N 39 33 : 0.75 S 76 1~ ~ -0.15 0.73 S 35 47 = -0.67 S 9 37 W -0.64 0.35 N 78 57 W 0.26 Z.53 N 80 3 W 3.82 2.55 S 82'38 W 11.19 3.28 S 75 17 W 24.38 3.05 S 7~ ~3 W 43.87 3.7~ S 7~ 25 W 70.32 3.57 S 5B 52 w 103.21 3.27 S 57 5 N 141.5T 3.35 S 59 58 W !87.26 3.63 S 75 39 W 23~.19 3.71 S 75 46 N 293.34 2.72 S 75 43 W 365.93 2.33 S 72 32 W 440.50 1.07 S 70 58 ~ 518.03 2,85 S 70 17 W 599,67 2.51 S 59 4~ ~ 590.71 3.09 S 69 58 fl 794.70 2,39 S 69 5% W 910,61 3,31 S 69 13 ~ 1027,03 3,13 S 69 11 g 113~.53 9.10 S 68 51 W 1241.66 9.18 S 6~ ~9 W 1349.52 0.15 S 68 27 W 1~57.21 0.10 S 5~ 19 W 156~.58 3.35 S 67 58 W 1573.08 0.55 S 54 50 W 1783.79 3.83 / = F .3U3-S-a O~PT~ RE~T&NSULCR C9']R.]: NJ~ T= S N2RT4/SDUTq E~ST/W-ST olir. =::T :~_.-2T F: :T 0.33 N O.O0 = 0.00 O.D$ S O.OZ ~ 3.96 O.O~ '4 3, 1-3 W 0._)0 0.3~ q 0.37 ,.~ 0.30 0.53 q 0.65 W 3. 33 0.5~ N 1.34 W 1.21 0.55 '4 1.30 W 1.5~+ 3.59 N 1.9~ W Z.11 I.~5 'q 2.11 W 2,36 1.13 q 1.23 W 1.74 1.Z6 W 0.33 W 1.30 O.'.q3 N 3.4,0 E 0.3~ q 0.5~ E ,3.53 0.20 N 0.35 W O.~l 1.33 q 4.61 W 4. 30 1.1~ q 12.45 W 12.52 1.33 S 23.55 '~/ 25.58 6.54 S 4'~.50 W 4~.~ 13.56 S 70.18 N 71.~3 23.31 S 101.4~ W iO&.Z4 38.56 S 136. ~3 ,~ 142.33 35 A9 S 17~,27 W 1~7 70.5;3 S ZZ'3.O~ W 100.~3 S 353.59 ,-i 357.5~ 121.50 S 425.~1 ~'~ !4~.51 5 499.62 W 520.12 172.52 5 576.35 W Z03.3'8 S 662.03 W 239.~3 S 759,60 W 776.~4 278.~9 S 868.58 W 912.2~ 319.36 S 977.80 W 102;3.53 357.51 ~ 1078.~6 ~ 1136.~1 395.93 $ 1178.31 W 1£43.05 ~35.02 S 1278.~3 N 1350.:30 ~74.~0 S 1379.05 W 1~53.3'3 313.8.~ S 147~.~1 W 1553.55 554.1~ 5 157~.66 W 1574.05 5'3~.$0 5 16~1.25 W 1794.57 ~ ZT'4'JT,4 CDMPUT~TIDN ARCO ALASKA, I~C. 3:-12 KUPARUK NDRTH T V~E6SURED VER 3EPTq D 4720.15 39 4857.¢~ 40 5015.13 41 5153,05 ~2 5310.83 ~3 5454.24 44 5595.17 ;5 57)3.59 ~6 5559.9~ ~7 60D4.33 ~8 6136.57 49 6257.45 50 6396.72 51 6523.87 52 6550.75 53 6731.$9 54 6911.$7 55 7044.35 56 7176.25 57 ?308.08 58 7438.83 59 7559,40 50 7570,00 50 INT'RPOLATED VALUES F]R RJ~ SD3-SE~ TIC~L VERTICAL EPTq 3EPTH C2JRSE DEVI~TIDq AZIMUTq 3:G lin DEG 93.00 390D,00 93.00 4000.00 93.00 ~100.00 93.00 ~ZO0.O0 93.00 ~303.00 93.00 ~00.00 93.00 ~500.00 93.30 ~503.00 93.00 4700,00 93.00 4800.00 47 22 S 62 59 W 47 30 S 52 47 W ~7 21 S 62 ~8 W 47 5 S 62 50 W 45 6 S 53 55 W 44 16 S 63 53 W 43 16 S 53 ~9 W 42 Z3 S 63 45 W 41 21 ~ 53 29 4 93.00 4900.00 93.00 5000.00 93.00 5103.00 93.00 5200.00 93.00 5300.00 93.00 5400.00 93.00 5509.00 93.00 5600.00 93°00 57DD.O0 93.00 580D.00 40 32 S 63 15 W 39 :+1 S 53 17 W 38 ~4 S 52 32 4 37 ~0 S 60 13 W 39 11 S 50 4 W ~0 3 S 50 41 W 40 23 S 51 Z~ ~ 40 56 S 62 49 W 40 37 S 62 4~ W 40 34 S 62 35 'J 93.00 5903.00 93.00 5000.00 93.46 5000.46 39 5g S 52 35 w 39 59 S 62 35 W 39 59 S 52 35 ~ gATE: 25-J~N-~5 =VEN 100 FE:T O: VERTICAL DOS' EG S=CTZON SEVERITY FEET DEG/IOO 1894.90 1.12 ZOOZ.41 3.28 !110.51 O.1Z 2218.93 3.18 2327.15 1.97 2429.51 ~.41 252~.46 0.91 2523.82 3.4~ 2715.15 O.~ 2~05.59 0.77 Z891.90 ~.58 2975.81 0.53 3057.3a Z.Z7 3135.13 0.61 3212.34 2.75 3295.84 D.85 3378.53 2.17 3464.94 3.57 3550.47 0.42 3635.87 3.28 3719,70 0.03 3803.10 3.03 3903.49 0.00 ]~T: DF SJRV:Y: ,) SJ]-S~A O~TH RE"T&qSULaR COOROIqATJS H]IlZ. NOqTH/SOUTH E4ST/~:ST gIST. =E~T :EET =::T 547.11 S 1781,51 W 1995.~0 596.74 S 1377.55 W 2302.57 146.4~ S 197w,20 W 211~.62 796.25 S 2071.17 ~45.11 S Z167.~ W 2327.15 3~1,~5 S 225~.~3 W 2~2~.54 ~35.50 S 2349.1i W 2523.53 ~77.$9 $ 2~35.01 W ZSZ3. ~6 1~13.51 S 2513.19 W 2716.3~ 1959.~4 5 259~.55 W 2~5.~3 1097.32 S 2675.12 W 2~92.35 1135.25 S 2751.40 W 2~75.~3 1172.10 3 232~.54 W 3353.0'3 1210.25 S 2393.16 W 3135.09 1!49.19 S 2960.35 W 3213.5~ 1290.52 S 3034.33 W 3297.42 133!.p~ b 3107.13 W 1371.76 S ~16~.20 W 3467.11 1411.20 S 3260.?0 W 1450.a2 S )337,C0 W 353~.59 1~89.13 S 3411.8~ N 372!.70 1527.~3 S 3485.32 W 330A.40 1528.~! S 3436.55 W 3~05.7~ D':3 ~:~SO ~.L~SK~., INC. 3:-12 KJPARU~ NINTH SLg~E,/1L~SK~1 COMPU?~TI3N INTE~POL~TED VALJE$ FOR M~RK=R TOP KUP~.RUK ' ~SE KUP~RUK C TOP KUP6RUK ~ BASE KUP~RUK A DBTD TD (F~ULT:O T2P) ~E~SJRED DEPTH BELOW KB 7115.00 7147.00 7235.g0 7~52.90 7570.D0 DATE: 25-J~N-BS ~HOS~N H]RIZ]NS ]RI3IN: TVD KB 5770.77 5838.30 5916.50 6003.05 5093.¢6 SJB-S=~ 5553.43 5577.77 5745.30 5]23.50 5910.05 5300.~5 3-1TE ]c SJRVe'f: 136 ' .~ JR F,~ 3~ _]C ~T EeL, S:C 1~, 1'12 RECTa, N3U' A2. ~,"3 · ',i] R TH/S 3UT 4 1192.al 1402.3Z 1~5~.67 1522.01 ]q]ll~T{S E~ST/~4:ST 3243,73 ~Z95.3Z , 333~.35 3~19.33:4 ~636.65 W ~T ARCO ALASKA~ I4C. 3F-12 N]RTH SLg~E~AL~SK~ CD~'PU?ATI 3Y D~T=: TOP BASE TOP BASE PBTD TO MARKER KUP~RJK ' KU~ARUK C KUP~RUK & KUPARUK A CF6JLT~D TDP) MEASJRED DE~TH B=LDW KB 7115.00 7147.00 7236.00 733g.00 7452.00 7570.00 25-J~N-B5 FROM j~TE Dc SJRVEY: KELLY BJSqING ELEV~TZ3N: ~NGIq~ER: 3. 3RI314= ~Z' :SL, TVD KB SOS-SS& 5746.48 5770.77 5838.30 5916.50 6003.05 5093.46 5553.~8 c577.77 57~5.3D 5~23.50 5~10.35 5000.¢6 135 ' ;~:--C NO S JR SEC T~N ~Trt 392 :~'6 .3C&TiDN ~T GUL~R COORDINATES /SDUTq 6~ST/W~ST .~1 S 3225.2~ tv .31 S 32~3.7~ .~ S 32~5.32 .57 S 335,~.~5 ~ .12 $ 3~1~.33 J .01 S 3~6.55 J =T FINAL MEASDRE3 DEPTH 7~70.00 W:LL LOCATI3N TRUE VERTICAL 3E~TH $093,~6 TO: SJB-SE& VERTICAL DEPTH 5900.~5 HORIZONTAL DEPARTURE DISTANCE AZIMJTH FEET 3EG MZN 3896.78 S $6 20 W SCHLUMBERGER O I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL ~F- 12 FIELD KUPARUK COUNTRY USA RUN ONE DATE LOOOED REFERENCE 000071176 WELL- 3F-12 (42' FSL, 136' FEL, S19, T12N, R9E VERTICAL PROJECT ION -10130 O0 101313 213013 ~ 4000 g48. PROJECTION ON VERTICAL PLANE 248. - 68. SCALED IN VERI'ICAL OEPI'HS HORIZ SCALE = l/1000 IN/FT O00E O00Z O00t 0 O00I- 000~- O00E- 000~- O00S- 000~- H£nOs 000~- 000I- 000I NOIZD~IFO%tJ 7VZNOZIY ~ · q6%I ~N~' )6IS "I.~I ,9gI '"IS& ,ge/ Z I-~[E 77319 Suggeeted fozm to be An.erred An each "Retire" well foJder to ehec]~ for timely compliance with our regulations. ' Report~ and Hater/al~ to be received 0 Required Date Received CompletiOn Report ~/ell' Iltetory /-/I- gg Remarks Snmplee Hud Log "'Core Ch/p~ Cb£~'Descrtption Registered Survey Plat ARCO Alaska, Inc.~ {~ Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 14, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: State Reports Dear Mr. Chatterton: Enclosed are the December monthly reports for the following wells: 1A-7 2H-6 3A-13 3F-12 3J-11 4-29 1A-13 2H-7 3A-14 3F-13 3J-12 16-15 1A-14 2H-8 3A-15 3'F-14 4-23 16-19 1H-4 2H-9 3A-16 3F-15 4-24 16-20 1H-8 2X-8 3F-11 3J-10 4-27 L2-21 L2-29 L3-5 L3-19 If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU13/L05 Enclosures RECEIVED JAN 1 1986 Oil & Gas Cons. Uommission ARCO Al~.~ska, Inc, i'.,: ~ Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA/'""' ALASKA [ .~ AND GAS CONSERVATION Cd..MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well ~( Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-273 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21483 4. Location of Well at surface 42' FSL, 135' FEL, Sec.19, T12N, R9E, UM 5. Elevation in feet (indicate KB, DF, etc.) 93 ' RKB 6. Lease Designation and Serial No. ADL 25643 ALK 2574 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3F-12 1 1. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of December , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well t~ 1445 hfs, 12/06/85. Drld 12-1/4" hole to 3307'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7570'TD (12/10/85), Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7452'. Secured well & RR @ 0500 hrs, 12/12/85. 13. Casing or liner ru.n and quantities of cement, results of pressure tests , 16", 62.5#/ft, H-40, weld conductor set ~ 115'. Conductor report not yet received. 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 3292'. Cmtd w/925 sx PF "E" & 410 sx PF "C". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7540'. Cmtd w/150 sx Class "G". 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/7565' - 3295' FDC/CNL/GR/Cal f/7380' - 6900', 5500' - 5100', & 4200' - 3800" Cal f/7557' - 3800' GR f/7530' - 1700' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN ! 4 1986 Alaska Oil & t~as Cons. Commlaa~n Anchorao~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE-~Report ¢ this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 TEMP3/MR07 Rev. 7-1-80 Submit in duplicate ARCO Alaska, Inc. ~' . Post Office !~ ..~0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 Transmitted herewith are the following items. return one signed copy of this transmittal. DATE 12-31-85 TRANSMITTAL # 5495 Please acknowledge receipt and Open Hole LIS Tapes Plus 2H-7 12-18-85 Run #1 2H-8 12-tl-85 Run #1 '--- 3A-15 12-17-85 Run #1 ~ 3B-7 05-25-85 Run #1 ~" 3F-12 12-11-85 Run #1 3J-11 12-20-85 Run #1 Listing/ schl/ One of each · El D {' / Alaska Oil & Gas Cons. Commission ~ Anchorage Receipt Acknowledged: STATE OF AK. Date: ARCO Ala,kl. Inc. il · Subl~climry of Allll~tlcRicllflelCCc,~lny MEMORAN rUM ALASKA OIL f~,.~, GAS CONSERVATION C. ~at~erton DATE: Cha~r4Yam-~ FI t~ NO.: Lonnie C. Smith // TELEPHONE NO.: Co--is s ioner TH RU- FROM: Bobby D. Foster ?~' Petroleum Inspector f Alaska SUBJECT: December 10, 1985 D.BDF.25 BOP Test ARCO - K.R.U. - 3F-12 Permit ~85-273 Kuparuk River Field Sunday, December 8, 1985: The BOP test began at 4.-00 PM and was C°nc%uded at "5:00 PM. ' "As the attached BOP test report shows, there were no failures. In summary, I witnessed the BOP test on ARCO's 3F-12. Attachment .)-001 A ( Rev 10:84) ' o&G #4 5/84- STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator /~/~~ ' -- dF-- ... Location: Sec /~ T~~~,M ~ Drilling. Contractor.L)~,~ Rig #~ Location, General~Well Sign~ General Housekeeping ~/~'Rig ~ Reserve Pit Mud Systems Trip Tank Pit Gauge Flow Monitor Gas Detectors Visual Audio BOPE Stack Annular Preventer Pipe Rams. - Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure Permit# · Representative ~-~ ACCUMULATOR SYST~ Full Charge Pressure ~~ psig Pressure After Closure /~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: ...... Controls: Master ~ ~' Remote~.~ Blinds switch cover Kelly and Floor Safety Valves '" Upper Kelly / .. Lower Kelly / Ball Type / Inside BOP / Test Pressure Test Pressure Test Pressure TeSt Pressure Choke Manifold ~4~_z~ Test Pressure No. Valves /~' No. flanges ~ Adjustable Chokes ~ Hydrauically operated choke Test Time / 'hrs. min~__s &c. "' min~_s e c. , Repair or Replacement of failed equipment to be made within Commission office notified. Remarks: "day~ and Inspector/ Distribution orig. - AO&GCC cc - Operator' cc - Supervisor Inspect~~ ~0 ~~ .~? November 12, 1985 Mr. Jeffrey B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3F-12 ARCO Alaska, Inc. Permit No. 85-273 Sur. Loc. 42'FSL, 135'FEL, Sec.19, T12N, R9E, UM. Btmhole Loc. 1394'FNL, 1010'F%~L, Sec.30, T12N, R9E, UM. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. Very trulY~.~yqurs, C. V. Chatterton Chairman of Alaska Oil and Gas Conservation Con~nission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, 'Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARC~) Alaska, Inc. ;' Post Office E~. .00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 5, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 3F-12 Dear Mr. Chatterton: Enclosed a re: An application for Permit to Drill Kuparuk 3F-12, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o A proximity plot Diagram and description of the surface hole diverter system Diagram and description of the BOP equipment We estimate spudding this well on December 3, 1985. If you have any questions, please call me at 263-4970. Sincerely, Regional Drilling Engineer JBK/LWK/tw PD/L188 Enclosures RECEIVED Alaska Oil & Gas Cons. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ALASKAi~., STATE OF ALASKA ~ L AND GAS CONSERVATION C MMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~X REDRILL [] DEEPEN [] 1 b. Type of well EXPLORATORY [_~ DEVELOPMENT OIL ~--~X DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L_~ SINGLE ZONE ~ MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address Cb'/V£ P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 42' FSL, 135' FEL, Sec.19, T12N, RgE, UN At top of proposed producing interval 1296' FNL, 1261' FWL, Sec.30, T12N, RgE, UM At total depth 1394' FNL, 1010' FWL, Sec.30, T12N, RgE, UM 5. Elevation in feet (indicate KB, DF etc.) RKB 93', PAD 56' 6. Lease designation and serial no. ADL 25643 ALK 2574 9. Unit or lease name Kuparuk River Unit 10. Well number 3F-12 11. Field and pool Kuparuk River Field 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 3F-11well 25' ~ surface feet 16. Proposed depth (MD & TVD) 7638' MD, 6096' TV• 18. Approximate spud date 1 2/03/85 14. Distance to nearest property or lease line miles 42' ~ surface feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 44 o I (see 20 AAC 25.035 (c) (2) Proposed Casing, Liner and Cementing Program 19. If deviated (see 20 AAC 25.050) 2F,71~ I<ICK OFF POINT 1300 feet. 21 psig@ _ROOF. Surface psig@_ 595A. ft. TD (TVD) SIZE '-~-g~;--1 Casing ~-/~'ii--'- ~ 16" __~-~- 1~_] 9-5/8" Weight 62.5# 36.0# 26.0# CASING AND LINER '-- --G-rra~' Cou OI in--~']---'Length - H-40 J I~eldI 80" SETTING DEPTH MD TOP TVD 35' I 35' I 35' I 35' 34 I 34' MD BOTTOM TVD 115~ 115' 33231 3023' 1 7638'1 6096' ----------t QUANTITY OF CEMENT (include stage data) 200 cf 860 sx PF "E" & 410 sx PF "C" 300 sx Class "G" neat 22. [:.)~sc.~ ibc proposed program: ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7638' MD (6096' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2670 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluid's will be left in uncemented annuli through the permafrost interval. 3F-12 will be 25' away from 3F-11 at the surface. There are no closer wellbores anywhere downhole. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. (continued on attached sheet) .... :.:;!'."iil "i"imie~:~v ce, tify that the foregoing is true and correct to the best of my knowledge ~.hI; SS "~; ~e~o ~ for Commission use /' U / '- Regional Dril_]ing Engineer DATE CONDITIONS OF APPROVAL Directional Survey required APl number ¢¥ES •NO 50- SEE COVER LETTER FOR OTHER REQUIREMENTS required Mud log required ,~NO OYES i,[~,',-~'6-e~- ................................ Approval date ,.4~ ~ ( L~K ) PD/PD 188 ..,80 ,COMMISSIONER DATE November 12, 1985 by order of the Commission Submit in triplicate PERMIT TO DRILL 3F-12 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 200 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. .................................................................. ~ : ................................ ~ ......... ~ ........ ~ ....................... ~ ................. r .................. .: .................... , ....................... ~ ............................. : ..........................~ ........................ ,.'BOO ]~EE~O_~ .................. . ....... . ................................. ~ .... ~ ................... ~.. . :_~ ............. ~ E--PER. I~FROST--~,' -VD=4.$23--TiHD=t.~2.4_DEP=~_3.- .... : ~. , . ,, . . . ...... 9 .......... ~ ....................... ':' .................................................. ~ ............... ~ ................... = ............. -~ ............. -,- ..... ~ ........................... ~ ........ -~- ............. ; .................. ............................... ~ ~ l .................. , ................... [:.,-.., ................... 4-------~ ....... , ......... ~ .............. : ..................... -; .... ~- ..................... - ~ ............... ' L i : ; , ~ ; r ? .... ..... ' ' ~ .... ~ ..... J ................................ I ........... F ................ : .................................... !- .............. ] .:'..]":..... ::]":' ..~ ....................... ~-' ~ ' ~ ......... 2? ~R ,--.100..,FT ................... ~ ...................................... : ...................................................... ! 19::J3EP=~.IB:iL ....... ::~..:.-....,.:-:-.] ....... :.-]]£: .... : ....... ,, .......... T ............ ....... ~OC ...... 5TVD=2641* -TMD=2786..-DEP=5501 ......... : ............................ : ....................................... ~ ......... ~ ..................... , .............. ~ ...... ....... -K--t 2 ........ TVD=2823-..TMD=,30.42...!-DEP=7:29 ..... ½ ................... : ................ ' ........ ~ .................................. ; ................... -"-: ........ , ..................................................... ~ ............. ~ ........................ ~ ................ _+_ ......... ..... TV D~30'2:3-'~THD= 3'323-"DEP=926 ..... : .......... I'-: ......... :~-" ......... ' .................. ~'- ....... : ................. ~: , ~ . ............................... T ................................................ ~ ................................................................ . ................................................. t .............. ....... ~VD~;4.443 T'HD=531'7" DEP § ........ ] :] ' ' L , , ..................................................... . ~ ..................... , .......~ ............... . .... ~ ........... . ....... ~ ............. DE:P.=3582.. ......... i " .................................. i .................................. ~"-: ..... t"'='? ............ ~----: ............ ~ ............. · ~ ' ':'" ;;' ' -- .... ~, ......... ? ....... : ............ i .................. ! ....... -fi- ....... ..... r i ...... = ........ )' ""-': ....... ~ .................. , ..... ' .....": .... ~ ...... '-I .......... :. -"'" '---T~'-~--~ .......................... -~ ...... '-~'--;- ........................... ~ ..... ................. , .................................................. ~ ................ _L..~_ .......... ._..~ ..................... ! ............. : ..... ~__ _ . ~ . . , ~ ~ , .. , . ~ .... ......... ~ ............... ~ ................................. : ................. ; ......................... ~.....: .................................. ! .............................................. ~ ................... ~ ......................... · .............. : .....~ ; ......... ~ ..... ~ ........................................... ~ ............................ ~ ............... .PI~OPO ;j ! -'l i ii I KUP~RUK IR I VER UNIT 20" .DI VF__.~TER SCHEMATIC DE S CR I PT ! ON i i. 16' C~CTOR. 2. TANI<O STARTER HEAD. 3. TANKO SAVER SUB. 4. TANKO LOWER QUICK-C~CT ASSY. 5. TANI,(O UPPER QU ! CK-C~CT ASSY. 6. 2.0' 20C~ PSI DRILLING SPOOL W/I0' CXJTLETS. ?. I0' HCR BALL VALVES W/lO' ./' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20" 2000 PSI Ah, I'~LAR PREVENTER° 7 6 7 MA:[ NTENANCE & OPERATI ON i i_i I. UP-oN INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVES " HAVE OPENED PROPERLY. 2. CLOSE ANI'~LAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 1 2 HOURS. CLOSE ANI'~LAR PREVENTER IN THE EVENT 'THAT AN Ih,FLUX OF WELLBORE · FLUIDS OR GAS IS DETECTED. IF NECESSARY, NtANMALLY OVERRIDE AhD CLOSE APPROI:::~ ! ATE VALVE TO ACHIEVE DO~IN/WlNO DIVERSION, DO NOT SHUT IN ~LL UNDER ANY CIRCUMSTANCES. 6 .. ~' DIAGRAM #1 1~-5/8~ 5000 PSI RSRRA BOP ~TAQ< // I. 16' - 2000 PSI TAN<CO STARTING ~F_AD 2. I1' - 3K)O0 PSI CASING 3. I1' - 3000 PSI X 13--5/8' - 5000 PSI S~ACE~ SPOCL 4. 13-5/8' - 5000 PSI PIPE P.~ 5. 13-5/8' - 5000 PSI DRILLING SPOCL W/CHO~ KILL LIFES 6. 13-5/8' - 5000 PSI DOU~ RAM W/PIPE ?. 13-5/8' - 5000 PSI At~ ' ACO. t,/UL. ATOR CAPACITY TEST 1. C~C~( A~ FILL ACCLI~T~R RESERVOIR TO F~ LEVEL WI~ ~IC ~UID. 2. ~ ~T A~T~ ~~ IS ~ ~I WI~ ~ TI~, ~ ~ ~ ~ITS SIXThlY 4. ~~ ~ ~ ~T. ~ A~~ L~ LIMIT IS 45 ~~ ~I~ TI~ ~ I~ ~I ~I~ 5 4 r _ 13-5/8" BOP STACK TEST I. FILL BOP STACK AAD ~ MANIFOLD WITH ARCTIC DIESEL. 2. Q-ECl< THAT ALL LOCK D(~ S~ IN Y~_L.FF_AD ARE FULLY RETRACTED. SE. AT TEST PLUG IN WE].L.~ WITH RtJ~ING JT ~ RUN IN LO(~ SCREW. LIFE VALVES ADJACENT TO BOP STAQ<, ALL OTHER PRESSURE UP TO 2.50~.~ ~ FOR I0 MIN. IN- CREASE PRESSURE T~ 3,..O~__~I.-)Ah~) HOLD FCR I0 MIN. BL~D PRES,~ TO OPEN Ah~ PREVENTER A~ MA~IJAL KILL AhD CHCKE .LIFE VALVES. CLOSE TOP PIPE RA~ AhD HCR VALVES CN KILL AhD CHCKE L~ TEST TO 250 PSI ~._O00~.P,~.-A'S IN STEP 4. CONTI~ TESTING ALL-'~L~ES, LIFES, AhD CHCKES WITH A 250 PSI L(:~ AAD 5000 PSI HIGH. TEST AS IN STEP 4. DO h~3T Pi~~ TE~T ANY NOT A FULL CLOSING POSITIVE SEAL CHOK~. CN_Y FI~ION TEST CHCKE$ THAT DO NOT FLLLY CLOSE. OPEN TOP PIPE RAMS AAD CLOSE BOTTO~ PIPE RAMS. TEST BOTTCM PIPE RAMS TO 250 PSI AN~ 3O3O PSI. OPEN BOTTCI~ PIPE RAMS, t~ACK OUT RUANING j'r AND CLOSE BLIAD R/~ ANO TEST TO 250 PSI AAi3 3000 "PSI'. ..OPEN BLIND RA~S AND RETRIEVE, TEST',PLU~. ~U<E. SUR~ '~ANIFQ_D AND LIFES ARE FULL CF NON-FF~F_EZING FLUID. SET ALL VALVES IN DRILLING POSITION. '12'. TEST STA~IPE VALVES, KELLY, KELLY COCKS, DRILL PIPE SAFETY VALVE, ~ INSIDE BOP TO 250 PSI A~D '5000 PSI. RECCRD TEST IN'=ORIV~TION ON BLONOUT PI~'VENTE~ TES FORM, SIGN, A~ SE. ND TO DRILLING SUPERVISOR. PERF(~ COV~ETE BCPE TEST AFTER NIPPLING UP WEEKLY THEREAFTER F~ICNALLY Ct:~'I'E BCPE DAIL I~Y 15,, I@ ARCO Alaska, Inc~' Post Office~. ,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 21, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commi s s i on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Conductor As-Built Wel 1 s 1-16 Dear Mr. Chatterton: Location Plat - 3F Pad Enclosed is an as-built you have any questions, location plat for the subject wells. please call me at 263-4944. Sincerely,. Gruber Associate Engineer JG/tw GRUll/L22 Enclosure If RECEIVED OCT e Alaska 0ii & Gas Cons. Commission ARCO Alaska, Inc. is a Subsi'diary of AtlanticRichfieldCompany NOTES I. COORDINATES ARE A.S.R, ZONE 4. 2. SECTION LINE DISTANCES ARE TRUE. 3. HORIZONTAL AND VERTICAL POSITIONS ARE BASED ON MONUMENTS SF-MIDDLE & SF-EAST PER L.H.D. 8 ASSOC. 4.0. G. ELEVATIONS INTERPOLATED FROM S/C DWG. NO. CED- RlXX-30$O I HEREBY'CERTIFY THAT I Alt PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SUIIYEYINQ'I'N THE .STATE OF ALASKA, THAT THIS PLAT REPIIE~ENT8 A SURVEY IlXDE UNDER MY DIRECT ~4N)ERVI~ION AND THAT CONDUCTORS I THRU · ARE .CORRECT AS OF SEPTEMBER 19,19BS AND.COMI)UCTORI'S THRU 1· ARE CORRECT AS OF SEPTEMBER 2S, leeS. CONDUCTORS THRU 8 LOCATED IN PROTRACTE[ SEC. 29, T. 12 N.,R.9 E., U. MER. CONDUCTORS cj THRU 16 LOCATED IN pROTRACTED SEC. ICj, T. 12 N, R.9 E., U. MER. AS B~~ T CONDUCTORS I-e IN SECTION 1- Y=b,985,734.98 LAT=70°22 , 20. 0858,, X= 508,662 89 FNL, 162 2- Y=5,985,745 X= 508,638 78 FNL, 139 3- Y=5,985,754 X= 508,616 69 FNL, 116 4- Y=5,985,764 .35 LONG=149°55,46.549'' FWL, 52 O.G., 56.1 PAD- .lO LAT=70°22,20.1856,, .99 LONG=149°55,47.233,, FWL, 52 O.G., 56.3 PAD .79 LAT=7OO22 20.2812" .29 LONG=149°55'47.896,, FWL, 52 O.G. 56.3 PAD .77 LAT=70°22 20.3796" X= 508,593.66 59 FNL, 93 FWL, 5- Y=5,985,774.87 X= 508,570.43 49 FNL, 70 FWL, 6- Y=5,985,784.84 X= 508,547.58 39 FNL, 48 FWL, 7- Y=5,985,794.93 X= 508,524.44 28 FNL, 24 FWL, 8- Y=5,985,804.81 X= 508,501.41 LONG=149°55'48.558', 52 O.G. 56.2 PAD LAT=70°22 20.4792" LONG=149°55'49.237 52 O'.G. 56.2 PAD LAT=70°22 20.5776" LONG=149°55'49.906'' 52 O.G. 56.1 PAD LAT=70°22 20.6771" LONG.149°55'50.582'' 52 O.G.,55.9 PAD LAT=70°22 20.7744" LONG=149°55'51.256'' 18 FNL, 1FWL, 52 0.G.,55.9 PAD 9ASy~I~TCONDUCTORS5 9-161N SECTIgN 19 - = ,985,834.85 LAT=70o22'21.O?08'~ X= 508,432.81 LONG=149°55'53.26~'' 12 FSL, 67 FEL, 10- Y=5,985,844.70 X= 508,410.73 21'FSL, 89 FEL, 11- Y=5,985,855.14' X= 508,387.41 32 FSL, 112 FEL, 12- Y=5,985,865.19 'X= 508,364.O5 42 13- Y= X= 52 14- Y= X= 51.20.G. LAT=70°22 LONG=149°5 51.20.G., LAT=70°22 LONG=149°5 51.20.G LAT=70°22 LONG=149°5 FSL,136 FEL,51.1 O.G.56 5,985,874.97 LAT=70°22 508,341.36 LONG=149°5 FSL, 158 FEL,51.10.G. 5,985,885.08 . 508,318.27 56.1 PAD 21.1678" 5'53.908" 56.2 PAD 21.2708" 5'54.590" , 56.3 PAD 21.3699" 5'55.273" .2 PAD 21.4663" 5'55.937" 56.3 PAD LAT=70°22 21.5660" LONG=149°55'56.612'' 62 FSL, 181 FEL, 51.1 O.G.,56.3 PAD · 15- Y=5,985,894.96 LAT=70°22 21.6635" EiYED _ f;508,295.72 LONG=149°55'57.271'' FSL, 204 FEL, 510.G. 56.1 PAD ~5~'~ 16- Y=5,985,904.95 LAT=70°22, 21. 7619,, l~ X= 508,272.74 LONG=149°55'57.943,, ' C ~- .... 2~.~82 FSL, 227 FEL~ 510.G. 56 P~ ;;~;"~' :~. f~ '~ .. ARCO Alalka, I1~. ',' DRILL SITE~ F CONDUCTOR AS BUILT LOCATIOI~ · 1151;11,, Data: Octo,, 11,19S5 Sea,:' N.~S. ,-,,,,.,,, ~m mm., Dra~ed by: Sydney2 'Dwi. Ne. Nil[ 85'26 I CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee (2) Loc thru 8) . · . 2. 3. 4. 5. 6. 7. 8. (3) Admin (/.~x" //-7--/f 9. (? thru 1~2),, ,- 10. (10 and 12)/ 12. (13 thru 21) (22 thru 26) 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Company Lease & Well No. YES NO · Is the permit fee attached .......................................... Is well to be located in a defined pool ............................ Is well located proper distance from property lin~ Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ............ Is well to be deviated and is wellbore plat ~ncluded ........... i'i'' ~ Is operator the only affected party ......................... Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... , Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~ Are necessary diagrams of diverter and BOP equipment attached . ...... ~ Does BOPE have sufficient pressure rating - Test to ~O~ psig .. ~ __ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S.gas probable ................................. Additional requirements ............................................. REMARKS Additional Remarks: O ~Z ~0 Geo logy: EngiDeer ins: LCS WVA~ MTM ~' HJH -. rev: 03/13/85 X6.011 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of.the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIXi .. No special'effort has been made to chronologically ~. .. organize this category of information. bis TAPE VERIFICATION blST!NG .~,i,~ 0 8 - Gas Cons. Anchorage LVP OiO,H02 VERIFICATION IJISTING PAGE i ~E66 SITE DA?A AND'?A~bE$ ARE NOT INCbUOED IN ~HI$ ~IST!NG WAV~FORM$ AND f'AST CHANNE6 DATA ARE NOT INC6UDED IN THIS LVP 010,H02 VERIFICATION BISTING PAGE 2 DATE t85/12/18 ORIGIN ~ REEL NAME ~135894 CONTINUATION ~ ~0~ PREVIOUS REEL I COM.ENT$ ILIBRARY TAPE *~ TAPE HEADER SERVICE NAME IEDIT DATE ORIGIN ~FS1A TAPE NAME CONTINUATION # ~01 PRE¥IOU$ TAPE COMMENTS ~IBRARY TAPE ** FILE HEADER ** FILE NAME )EDIT ,001 SERVICE NAME ) VERSION # ~ DATE m MAXYMUM LENGTH I 1024 FI~E_TYPE I PREVIOUS FILE ~ * SCHLUMBERGER · ~ AbASKA COMPUTING CEN~ER * ************************************************************************************ COMPANY = ARCO ALASKA INC WEbL = 3F-12 F!EbD ~ KUPARUK COUNTY = NORTH SLOPE BOROUGH STATE = A~ASKA RECEIVED JAN 0 8 !986 Alaska Oii & G~.~ Oon~, Oommi~mon Anchorige bVP 010,H02 VERIFICATION LISTING PAGE jOB NUHBER AT ACC: 71076 RUN #ONE DATE 50GGEDI II-DEC-B5 bOP: C, ~IbKIE CASING - 9.625" g 36,00' ' BlT SIZE - 8,5" TO 7570,'0' ~YPE FbUID -" DENSITY = 9.! b~/G RM ~: 4.06 ~ 62.0 DF VISCOSITY m 42, P~ = 9, R~C _ 4't~ 60'0 DF 3, FbUID [,OSS = 5,8 C3 !4~ DF MATRIX SANDSTONE SCHbUMBERGEP bOGS INCbUDED WITH THIS MAGNETIC TAPEI ~ DUA5 INDUCTION bATERSOG (DIS) · FORMATION DENSITY COMPEN&ATED bOG: CFDN) · COMPENSATED NEUTRON bOG CFDN) * LVP 010,H02 VERIFICATION LISTING ~AGE 4 ** DATA FORMAT RECORD ENTRY BLOCKS TYPE SIZE 2 4 8 4 16 1 0 REPR CODE 66: 66 73: 65 66 66 DATUM SPECIFICATION BLOCKS ENTRY 0 1 ,lIN60 1 0 MNEM SERVICE SERVICE UNIT AP! AP1 AP1 AP~ FILE' SIZE SPL: REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NO. ' - CODE (OCTAL) 0 ' .44 I 68 00000000000000 68 00000000000000 SFLU OIL ILO IbM SP DIG GR GR FDN CALl FDN RHOB FDN DRHO FDN NRAT FDN RNRA FDN NPHI FDN NCNb FON FCNL FDN GR CAS F? 00 000 O0 OHMM O0 220 01 0HM~ 00 120 46 0 OHMM O0 120 44 0 ~V 00 0 0 GAPI O0 ]IO0 ~I 0 GAPI O0 310 OJ 0 IN 00 280 01 0 G/C3 O0 350 02 0 G/C3 00 356 01 0 DO 420 0! 0 0o 000 00 0 PU 00 890 00 0 CPS 00 330 31 0 CPS O0 330 3O 0 GAP! 00 310 01 0 0 0 0 O 0 0 0 0 0 0 0 0 0 O 0 : 4 !68~ O00OOOOOOOOO00 ~ ,~. oooooooooooooo ~ I~ oooooooooooooo 00000000000000 68 00000000000000 I ~ oooooooooooooo , ~0 oooooooooooooo , ~, oooooooooooooo I ~ oooooooooooooo oooooooooooooo I ~ oooooooooooooo oooooooooooooo DATA DEPT 7379,0000 $FbU 3,7,12 IbD SP -1~.2607 GR 10~,~898 GR RHOB ,9756 DRHU ',:i 025 NRAT NPH! 39.5996 NCNb 207 . 000 FCNL DEPT 7300.0000 SFLU 3.~030 SP -15,5449 GR 104.2773 GR RHOB 2,4006 DRHO 0,0186 NRAT= NPHI 39.5508 NCNb 2095,5000 FCNL DEPT 7200.0000 ,SFbU 4 o5710 lbD SP -19.5107 GR' 95:~,648 GR RHOR 2,3967 DRHO 0'0151 NRAT 0'8125 ~R 104,2773- CALl 3,299i RNRA 590,8,129 OR 4,64 8 CALl 95;96144 !bN 3~1506 RNRA 5020 . 3'$764 ~-999,2500 4,2976 8,4963 3'5452 -999,2500 4,8953 8'6426 3,4788 RECEIVED JAN 0 8 1986 Alaska 0ii & Gas Cons. Commission Anchorage e e,e,. e · e, e e e m e,e. e e e e e,e e,,e e e'e e e e e' · · e e e 4 e EVP SP RHOB NPHI DEPT SP RHOB NPH! DEPT SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP NPHI SP NPHI DEPT SP RHOB NPHI DEPT RHOB NPHI DEPT SP RHOB NPHI DEPT SP NPHI DEPT SP RHOB NPHI OlO,H02 VERIFICATION 3900,0000 SFbU -30,4326 GR 2,2737 DRHO 44,8242 NCNb DRHO oooo DRHO -999:2500 NCNb 3600,0000 SFbU -33,1445 GR -999,2500 DRHO -999,2500 NCNb i.~oi,oooo sF~,u 3 ,2920 GR 99 ,2500 DRHO 999,2500 NCNb 3400,0000 SFbU -999 500 DRHQ -999' 2500 NCND 3300,0000 SFLU '999,2500 HO -999,2500 NCNb 3200,0000 &FbU -999,2500 GR -999,2500 DRHO '999,2500 NCN[, 100,0000 SFbU 999,2500 GR .999,2500 DRHO -999,2500 NCNB 000,0000 SFbU ~999.2500 GR -999,2500 DRHU '999.2500 NCN{, 2900.0000 SFLU -999,2500 GR -999,~500 DRHO '999,2500 NCNb LISTING. 3,2405 102'6523 0,0454 1834,6875 :o oo 182 6875 3,6370 93,7773 -999,250O -999~2500 3,6370 95,6523 -999,2500 -999,2500 5,4070 -999,2500 01 -999,2 O0 '999,2~00 6,5867 *'999 '999 ; 500 '999 O0 -999,2500 .'999,2500 i9999~1''2500 · 999,2500 '999,2 -999 22500 -999:500 -999,.2500 -999,2500 -999:~500 -999 500 GR NRAT GR NRAT FCNL GR NRAT FCNb NRAT FCN5 NRAT NRA~ FCNE XbD NRAT FCNb XbD GR NRAT FCNb GR NRAY FCNb XGbD R NRAt FCNb GR NRAT FCNb 2,9592 Xb~ t02,6523 CAbI '3,6350 RNRA 460* 3906 GR 101 . :"999 '9'99 -999 1523 5432: 9906 5:0:0 500 2500 RNRA RNRA GR . 3*9534 lb~ .999,2500 CAbI ~999,~2500 RNRA 999,2500 GR 5'5o85 ~b. "999e2500 CAG~ ~999'2500 RNRA °999.2500 GR' 5,5945 IbM '999'2500 CAbI :999,2500 RNRA: "999'2500 i999,2500 CAbZ :99g,2500 RNRA 999,2500 GR -999~2::500 '999;2500 -999-2500 "999'2500 '999,2500 "999,~500 ~999,2500 ~999,2S00 :999:.25~00 :999,2500 -ii999'2509 .999'2500 :999,2500 -999'2500 NRA CAGZ RNRA GR CAb! RNRA CA:b~ RNRA GR 3,2659 9,~72'3 3;9846 '999,:2500 ,~6780 *-3066 3'8010 -999,2500 . 4'12i8 :-999~2500 '999,2500 -999':2500 . ¢,0320 999,2500 '999~'2500 -999~2500 . 5'5242 999~2500 :999,2500 -,.999,2500 5,7078 -999'2500 -999;2500 13~8066 106,9023 '999,2500 -999'2500 "999,2500 67,5273 :999,2500 999,2500 -999,2500 -999~2500 -999,2500 53,2930 -999,2500 -999'2500 '999~2500 41,1992 RECEIVED JAN 0 8 1986 Alaska 0ti & Gas Cram, OommJ~mOn Anchora~ bVP OIO,N02 VERIFICATION blSTING PAGE 9 OEPT 2800,0000 SFLo Sp -999,2500 GR RHOB -999.2500 ORHO NPHI -999,2500 NCNb DgPT SP RHOB 2700,0000 SFbU -999,2500 GR -999,2500 DRHO -999,2500 NCNb D£PT 2600,0000 SrbU RHOB -999 0 DRHO NPH! -999.2. 0 NCNb DEP? SP RHOB NPHI DEPT SP RHOB NPHI SP RHOB NPHI DEPT SP RHOB NPHI DEPT SP RHOR NPH! DEPT SP RHOB NPHI DBPT SP RHOB NPH! OEPT SP RHOB 2500 0000 SFbU -999:2b00 GR '999,2500 DRHO -999,2500 NCNb ~400,0000 SFbU 999.2500 GR 999,2500 DRHO :999.2500 NCNb 9 ,,2500 GR ,2500 NCNb 200 0000 6FbO 999:2500 GR 99~99,2500 ORHO ,2500 NCNb 2100,0000 SFbU -999,2500 GR -999,2500 ORHO -999,2500 NCNb 2000,0000 SFbU -999,2500 GR -99~,~500 DRHO -99 , 500 NCNb !900.0000 SFbU 500 GR '999'~500 -999, DRHO -999,2500 NCNb 80~,0000 SFbU ~99 ,2500 GR -999,2500 DRHO '999,2500 '999'-2500 GR -999,2500 NRAT -999,2500 FCNL '999,2500 ILO .-999,2500 GR -999,2500 NRAT "999,2500 FCNb -999,2500 -999,2500 GR -999,2500 NRAT =999,2500 FCN5 :999,2500 ZED .999,2500 GR '999,2500 NRAT -999,2500 FCNb "999,'25~00 IbD '999,25 GR '99999,,-R500 NRA? ' 9,'2500 FCNb '999,2500 !bD -999,2500 GR -999 500 FCNb -999 : 0 GR '"999 500 NRAT: · ,999,.500 FCNb -999,2500 lbo :999,R500 GR 999'..2500 NRAT -999,2500 FCNb -999,22~000 IbD: -999, 0 GR '.999, CNb -999,.2500 lED "999,2500 GR '999,2500 NRA? ~999,2500 FCNb -999,2500 GR -999,2500 NRA? ~999,2500 IbM ..999;2500 CAb! :999~2500 R~RA :999,2500 GR '999'2500 -999;2500 RNRA '999:;2500 GR '999,~500 IbM '999,~500 C~bZ "99:9~5:00 :RNRA -999;~500 OR .999'2500 -99'9i2500 CAbI -999,2500 RNRA '999,2500 GR -999~500 -9991.2500 -999~2500 RNRA -9992500 -999~5oo "999~.2500 -999~2500 "999i~2500 -999;2500 "999'2500 "999,2500 GR :999'2500 ~999,2500 RNRA ,~999'2500 GR :999'2500 IbM :999;2500 -:99::~500: CAbZ -999.2500 R~RA -999~2500 OR -999~500 -999,2500 RNRA 999,2500 999,2500 -999~500 32,1055 -999'2500 '999-2500 -999'2500 57,4805 "999,2500 -999~2500 46;4i80 -999,2500 "999,2500 "999';250O '43'26t7 '999,:~500 -999'2500 "999,2500 25,55~8 :999,2500 999~9500 -999,2500 24,3799 1999,2500 39,~367 -999'2500 -999:.~500 "999.2500 "999,2500 36'6055 ~999.2500 ~-999.~500 ~999'2500 34~94:92 -999,2509 "999'2500 bVP 010,H02 VERIFICATION LISTING PAGE 10 -999,2500 NCNb '999,2500 FCN6 DEPT 1700.0000 5FLU -999,2500 IbD ,SP -999~2500 GR -999,2500 GR RHOB -999.2500 ORHO -999..2500 NRAT NPHI -999.2500 NCNb -999'2500 FCNb DEPT 1642.0000 SFLO -999.2500 st, .~,~soo e, .~.~_soo ..o. .9~9.~soo D..o .~9~,~soo NPttI-999,2500 NCNb '999,2500 **FIbE TRAIbER FI6E NAME :EDIT ,00! SERVICE NAME VERSION # DATE ! ~AXIMUN LENGTH : 1024 FILE TYPE : NEXT FILE NAME '999'2500 GR '-999.2500 IbM !-999'2500 CAb! '999'2500 RNRA -999~2S00 GR ~999.,2500 IbM -999~2500 CAEI ~999~2500 RNRA .999'~500 GR 36,7617 ~999'2500 ~999'2500 '999,2500 :26,4580 ~999.2500 ,~999,2500 ~999,2500 28.66I! ** TAPE TRAIbER SERVICE NAME :EDIT DATE ~85/!2/1B ORIGIN :FS1A TAPE NAME CONTINUATION # NEXT TAPE NAME COMMENTS ~bIBRARY TAP~ SERVICE NAME :EDIT DATE :85/12/18 ORIGIN : REEL NAME 1135894 CONTINUATION # :01 NEXT REEL NANE ~ COMNENT$ ~LIBRARY TAPE
