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Home My WebLink About188-009MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, July 24, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3H-18 KUPARUK RIV UNIT 3H-18 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/24/2025 3H-18 50-103-20095-00-00 188-009-0 W SPT 5831 1880090 1500 2750 2750 2750 2745 310 420 420 420 4YRTST P Austin McLeod 6/1/2025 MITIA. 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 3H-18 Inspection Date: Tubing OA Packer Depth 825 2015 1990 1980IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250602191822 BBL Pumped:1.5 BBL Returned:1.3 Thursday, July 24, 2025 Page 1 of 1            188-009 T38928 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.06.13 08:43:56 -08'00' MEMORANDUM TO: Jim Regg -F / P.L Supervisor`Itll? FROM: Brian Bixby Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, June 8, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3H-18 KUPARUK RIV UNIT 3H-18 Src: Inspector Reviewed By.:.-€zn P.I. sup" u NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 311-18 API Well Number 50-103-20095-00-00 Inspector Name: Brian Bixby Permit Number: 188-009-0 Inspection Date: 6/1/2021 Insp Num: mi[BDB210602041232 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3x-18 Type Inj w TVD 5831 - Tubing 2775 2774 2773 2774 PTD 1880090 " Type Test SPT -Test psi 1500 - IA 770 1820 1790 1785 - BBL Pumped: 1 1.9 BBL Returned: 1.5 OA 300 440 440' 440 Interval 4YRTST PIF P Notes: Tuesday, June 8, 2021 Page I of I Originated: Schlumberger PTS- PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax Delivered to: --,41/ AOGCC v vi ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision -, 333 W. 7th Ave, Suite 100 >, Anchorage, AK 99501 188009 7TTRANSMITTAL DATE RANSMITTAL# 1 VVELLNAME 26-10 API # 50.029-21084.00MAIM ORDER H-00034 FIELD NAME KUPARUK RIVER DESCRIPTIONDELIVERABLE WL DESCRIPTION r. Color r• Prints CD's 1HTELOGGED -108 1H-105 1J-756 to -04A 50-029-23608-00 50-029-20727-01 50-029-23311-00 50-029-20621-00 E540-00064 E540-00065 EAI8-00008 E540-00068 KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER KUPARUK RIVER WL WL Memory WL IPROF IPROF (PROF IPROF Caliper FINAL FIELD1 FINAL FIELDU29-MarAg FINAL FIELD1 FINAL FIELD1 FINAL FIELD1 1 31-1-18 50-103-20095-00 EBLV-00002 KUPARUK RIVER WL IPROF FINAL FIELD 6 -Apr -19 1 2K-26 50.103.20126-00 EBLN-00004 KUPARUK RIVER WL Caliper FINAL FIELD 8 -Apr -19 1 --EB-00,-SI00 10-06 50.029-21224-00 KUPARUK RIVER WL PPROF FINAL FIELD 10 -Apr -19 1 n 8 Print Name Signature Please return via courier or sign/scan and email a copy Date and OPAL Schlumberger -Private A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECOVE® APR 0 2 2019 1. Operations Abandon El Plug Perforations __/ Fracture Stimulate Pull Tubing rpr�� Li Ae Performed: Suspend ❑ Perforate l� V'rt' Other Stimulate ❑ Alter Casing ❑ Chan o ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Added perfs ❑' 2. Operator ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ Stratigraphic ❑ Service Q 188-009 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20095-00 7. Property Designation (Lease Number): e. Well Name and Number: ADL25531, ADL25532 KRU 3H-18 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,293 feet Plugs measured None feet true vertical 6,187 feet Junk measured 9902 feet Effective Depth measured 10,083 feet Packer measured 9592 feet true vertical 6,086 feet true vertical 5831 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79 16 115 115 Surface 4,134 9.625 4,169 2966 Intermediate Production 10,130 7 10,165 6130 Liner Perforation depth Measured depth 9755-9768, 9790-9860, 9878-9899, 9900-9920 feet True Vertical depth 5915-5922, 5933-5970, 5979-5990, 5991-6001 feet Tubing (size, grade, measured and true vertical depth) 3.5 1-80 9662' MD 5868' TVD Packers and SSSV (type, measured and true vertical depth) BAKER FHL PACKER 9592' MD 5831' TVD NO SSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl I Casing Pressure I Tubing Pressure Prior to well operation: 5680 1900 12750 1 Subsequent to operation: 16150 igoo 12685 14. Attachments (required per 20 AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations 10, Exploratory ❑ Development ❑ Service Q Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG D GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: A Authorized Name: Lynn Aleshim Contact Name: Lynn Aleshire Authorized Title: Petroleum Engineer Contact Email: lynn.aleshire@cop.com Authorized Signature: Dat 4/1/2019 Contact Phone: 907-265-6525 k rL 4-/3/19 Form 10-404 Revised 4/2017 dM Lf 111 RBDMS PR 0 2 Y019 Submit Original Only ConocoPhillips Alaska, Inc. 700 G St. Anchorage, AK 99501-3448 April 1, 2019 AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 333 W. 7th Ave., Ste. 100 Anchorage, AK 99501 Dear Commissioner, Enclosed is a 10-404 Report of Sundry Well Operations for D Sand perforations added to Kuparuk River Unit Well 3H-18 (PTD# 188-009) If you have any questions regarding this matter, please contact me at 907-265-6525. Sincerely, Lynn Aleshire Staff Petroleum Engineer ConocoPhillips Alaska, Inc. Attachments: Sundry Report Description of Work Completed 3H-18 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary CBL of 5/5/88. KUP INJ WELLNAME 311-18 WELLBORE 3H-18 C'_____PhillIps Well Attributes Max Angle&MD TD lA 1VC.Vrtt Tele rome Wellbore avvuWl Wetmore Status ncl l`I mo mrce ACIaM ^nne) irJB5lkl.11i:. NIIPARIIN RIVFR UNIT Sn1niJMOGM INI n 1 '1P 11 10- est WO: aK-fa.avemaemmAM Last Tag vereNxMnmecfxwal Annoriom IDepM IN(el End DaleWand" Gat MW BY Last Tag: ELM 9,9010 2/82019 3H-18 Lama, Last Rev Reason _........................._....._......... IKNGER:%0 Annob EM Dow WeIIWre Gs[Mod ay ROY Reason: Tag, Add Pelts ledoems, lom-'d jusearg Casing Strings Gsmp wmnphron oollnl ID(in) TopmKB) se captalrMs) sn Gpm lrvol... wvL=a(L.Gra1a mpmrem CONDUCTOR 1fi 1506 ME 1150 115.0 62.50 H-00 WELDED Gsinp pe¢rlpLbn OD lin) lu int llumnel Set pepM I11K6) get corm (Tom WULen (1...GMe TOPTllreed SURFACE 9518 892 350 4,168.5 2,966.3 3609 J-55 BTC Casi,p GsctlgW, OU OUT ID (int rcomman am OepO Me) Ser Perm TOOI_.WULen g...G,ede TopIDroad CONWCTgt%61150 , MIMV 15 PRODUCTION 7 628 35.0 10,1654 6,130.1 26.00 J45 BTC Tubing Strings .-1 3Zood'.o.8 iuCln9 DescdOxon sGlnp Me,. lD tial Tap 11MON set tiepin (n.. set oepm 1ND11-. w<(IEdll GrNe iop Connetlion TUBING GAS 3112 2.99 35.0 9,589) 58302 9.50 L80 EUE INJECTION Completion Details TopIND) TOPm=I Nominal To (WO) Ins o 1'1 Item Dee com meal SUREACE;M"Idds dv PMM-seemv.mL fMlvx cINI x.61009.4616, 1.Rode. 35.0 35.0 003 HANGER Tubing Hanger ClW Gena 2900 9,466.6 5166.5 5878 NJ amco GGLM with Vinstalletl NN126131 1 VCS 2820 SNk19394-10 9,5243 5,Rr4 58.87 NIPPLE 2.813" X nipple SN43893447 2.813 m�; s.4e9e 9S73J 5,8219 58.91 LOCATOR Baker tocamr 3000 9,574.5 5,822.4 58.91 SEAL ASSY Baker 80- olded seat Assembly 1178OAL 117 + 311110 3.42' for space out) Tobir,D armadon SnIng Ma... ID pal Top(RI(BI sat DepA(B..aN OepM(TOO (....pladl Gnde rslbn Irate- TUBING 3 v2 2.99 9,9].9 9,6630 5,8M 0 9.30 J-55 EUE8aIA dMOD a.mmr Fund -11 a N., a- Completion Details ....ae,5P.9.fvf YAl9 Top IND) Topinnl Namand NIPPLE;9.M3 Top Me) Wa) fl IMM Dee Cpn to (an) 9,5779 5,824.1 58.92 PBR BAKER PBE 4.000 9.591.6 5,831.2 58.93 PACKER BAKER FHL PACKER 2.992 9,628.4 5,850.1 58.98 NIPPLE CAMEO DNIPPLE NO GO 2]50 9,652.1 5,8615 59.03 BOS BROWN SHEAR OUT SUB 3000 LOcnTOR, sau Other In Hole (Nireline retrievable plugs, valvas, pumps, fish, eft.) Tapgo) Top In=I Top InK61 Imlal CI Dez coin Run oat= ID In)) EEAL nssv: e,nas 9.902.0 5,991.8 I 5831 FISH1112"DMY Empty Pocket', Roppetl In RaUoe 812311989 It B,UEF. Perforations & Slots abm PACMER: 8,5918 Top(ND) Btm (NOI pDene No. Topomm I(RKB) Milan INKS) UnkM Zone Del. 1 T. Cqn 9155.0 9.788.0 5.915)922o UNIT D, 3H-18 60 APERF 3rg phasing Y HES Big NIPPLE', 9,629.4 Hinal 9,790.0 9,880.0 5,933.4 5,9698 C-4,31-1-18 1 120 (PERF 60° phasing. 2 LAW ENOJet 9,878.0 9,899,0 5,979.2 5,990.2 A-1, 3H-18 1 40 IPERF 0°phasing.2118"Ener Jet sonfliedi 9,900.0 9,920.0 5.990.8 6,001.3 A-1,311-18 51111 40 PERE 120° phasing, 4In" Ultra Pack Mandrel Inserts at .p H Tap(KKB) Toa(,D) INKS) Make I Meda 00 on) U, varve Type - Type Panaira (a) TRORan (pan Run DeM Lem 11 9,466.6 5,]611.5 Camco KBMG 1 INJ DV INT 0.000 UO 12212018 Notes: General & Safety APERF; 9, M,HE,itl0� End Dale norma on 711912005NOTE: WAIVEREO WELL Tx ACOMMUNICATION 922010 NOTE View Schematic wl Alaske Schematic9.0 1182018 NOTE: View Schematic wl Aleska SCMmape 100 IPERF, 9.iW.09,M0� IPERF; 99]a.D9EBBp� F19K.'so0 IFERF;9900".9eaa0- 1.U.TKN, soc-lo li MEMORANDUM TO: Jim Regg P.I. Supervisor (��`�'.1 I �_ l ` FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, January 24, 2019 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA, INC. 3H -I8 KUPARUK RIV UNIT 3H-18 Ste: Inspector Reviewed By: P.I. Supry J P— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 31-1-18 API Well Number 50-103-20095-00-00 Inspector Name: Bob Noble Permit Number: 188-009-0 Inspection Date: 1/172019 Insp Num: mitRCN190117162249 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3H -Is Type Inj w TVD ss1 Tubing', 2300 2300 2300 " 00 PTD 1880090 Type Test sOT Test psi 1500 ]A1160 3000 2960 - 2950 BBL Pumped: 1 9 BBL Returned: 1 8 OA 400 600 - 600 600 Interval iNn A1- P/F 1, — Notes: Thursday, January 24, 2019 Page 1 of I WELL LOG TRANSMITTAL 0905432221 To: Alaska Oil and Gas Conservation Comm. Atm.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforation Record: 3H-18 Run Date: 2/8/2019 1030' 9 30 37 2 February 13, 2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS—ANC@halliburton.com 3H-18 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20095-00 RECEIVED FEB 19 2019 a®GCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS—ANC@halliburton.com Date: M1420 L I Signed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 19 T'�V" : JAN 16 201.9 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing 2] Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑v Re-enter Susp Well ❑ Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: ConocoPhilllps Alaska, Inc. Development ❑ Exploratory ❑ Stratigraphic❑ Service ❑ 188-009 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 50-103-20095-00 7. Property Designation (Lease Number): 8. Well Name and Number: KRU 3H-18 ADL25531, ADL 25532 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,293 feet Plugs measured None feet true vertical 6,197 feet Junk measured 9902 feet Effective Depth measured 10,083 feet Packer measured 9,592 feet true vertical 6,086 feet true vertical 5,831 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 115' MD 115 TVD SURFACE 4,134 feet 9 5/8 " 4,169' MD 2966 TVD PRODUCTION 10,130 feet 7 10,165' MD 6130 TVD Perforation depth: Measured depth: 9790-9860. 9878-9899M 9900-9920 feet True Vertical depth: 5933-5970. 5979-5990. 5991-6001 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 9,662' MD 5,868' TVD Packers and SSSV (type, measured and true vertical depth) PACKER = BAKER FHL PACKER 9,592' MD 5,831' TVD SSSV =NONE 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA 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 1270 1 0 Subsequent to operation: - - 4000 1160 1 2760 14. Attachments (required per 20 AAc 25070, 25,071. s 25,283) 15. Well Class after work: Daily Report of Well Operations 121 Exploratory ❑ Development ❑ Service 0 Stratigmphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 318-460 Contact Name: Kyle Hampton Authorized Name: Kyle Hampton Contact Email: Kyle. Hampton@Cop.Com Authorized Title: Sr. Wells En neer 1 l ;D 1 Contact Phone: (907) 263-4627 Authorized Signature: Date: Form 10-404 Revised 4/2017 1 VTL 0151 i9 ' 9 rcBDMSS)(—tAN 2 2 2019 114 Submit Original Only ConocoPhillips Alaska, InC. KUP INJ RIVER UNIT NONE WELLNAME 3H-18 WELLBORE 3H-18 ast WO'. 3N-I&1/IJA10Na:ILPM Last Tag Varh'tl vlanetic ged i) Anodnan Capthplugg End Dee Welllwre Last. By LEsl Tag: RKB 13' of Fill) 12]222 1 3H-10 1zendgdurj _....... Last Rev Reason NPNGER, 35.p Annoption End Date Mduora /eat Mod Oy Rev Reason: Set DV & Updated Tag Deptb 12/21/2018 31416 zem6aej Casing Strings crime Descriptnn OD pnl Ind ToP lnRel se, cevtn lnNel Set DePN /TVD)... W1Mn p._OrWe Tov thread job CONDUCTOR 16 15.0fi 36.0 1150 115.0 6250 H-40 WELDED Casing Descnpnon OD(in) ID pn) TOP 111KB1 Bet Depm andid Set Dedh(IVD1... WBLen 11... Brade Tai ih3m 0M8 SURFACE 8.92 3513 4,168.5 2,986.] 3690 1-55 BTC Caamg DexdgonOD tint ID (in) TOP Last see Depth lnKBl Sd dead TV01-, Grade Tap]bead 0011... PRODUCTION 7 626 35.0 10,1654 6,130,1 Road 155 BTC CONDUCTOR: 39.M1, taB Tubing Strings MrWa FW-DiM:Mdo zsaon lanrzDla .....,"',"nod", TUGm9 loo-dpnan Biro. Ma... TUBING GAS 3l/2 ID(inl 2.99 Top lnl(BI 35.0 BetDepih lX.. 9589) 3et Deplh nand (.. 5,830.2 (ANSI 9.30 Grade L80 Top Co--d— nection EUE INJECTION Completion Details Top ONE) reptnd Nominal Top MS) (MBI 0 ...as Com 10 and 350 35.0 0.03 HANGER Tubing Hanger ON CEO 2.900 suRFAOE: Ew,leas Amnm Fllea.srwrxrtn� 9486.6 5788.5 56]6 INJ amco vat nista fled # -0 _ CS 2.820 SN419394AI) 1x CRWt3? E.�3De.cee.6; 1.7we 7524.3 5,786.6 50.87 NIPPLE 2.813"%nipple SN#3893447 2.813 9,573.7 50219 50.91 LOCATOR Baker loodw 3.000 9.574.5 5,622.4 50.91 TEAL ASSY Be" 8620 BH- MDitletl seal Assembly 7 ' AL ( + 3000 IW: B,NAB 3.42' herspace out) tlrEinq Descnl,lian Bpina Ma... ID(in) Top IN(B) Sd DepM (n. 9N CepM jND1 (... WIIIMI) Gratle Top CannecUon TUBING 3112 299 9,577.9 9,6630 5,866.0 9.30 IT55 EUE&rtlABM00 Completion Details Top(TVD) Top -1 Nomloal PrvwW Fluk-,13NeBr8Ta: Top IXNB) Me) O° Item Daa Com ID lin) 9.a66.69,5TLR ty/ffi2m9 9,5779 5.8241 5&.92 PER BAKER PB R 4000 NIPPLE: Raba 9591.6 5.8312 5993 PACKER BAKER FHL PACKER 2.992 9,6294 5,8507 5090 NIPPLE CAMCO D NIPPLE NO GO 2750 9,6621 5,&675 59.03 ISOE IBRUWN SHEAR OUT SUB 3.000 Other In Hole (Wineline retrievable plugs, valves, pumps, fish, etc.) mplrvpd Tap ma L0GTOR:9,n37 ToprdkBd InNB) p) Des corn Run Date m(n) 9,902.0 5.991.8 58.31 FISH 1 112" DMY Empty Pocket, Dropped in Ratbole 8/23"989 Perforations & Slots SEUAssv: 95746 PSR: aM9 Shot Don Top(TVDg B.ITVD) Isla. Tap(Me) BM(It ) (SKES (NINE) On.IDne Dae 1 Type Co. PACKER. %and 6-9)90.0 9,860.0 5,9334 5,9698 CA,3 8 F8 0/6-1988 1, /PERF tlegphesing,2 EnerJet 9,878.0 9,899.0 5,979.2 5,9902 A4,31H-18 &3-1996 4.0 (PERF Zero UOg.pbasing, EnerJet NIPPLE9.6204 9,9000 9,920.0 5,990.6 6.0013 71, 3H-10 SOIi 4.0 (PERF 120 degphasing, Ultra Pack Mandral Inserts WE. a.wzt at de Non 'P1N[B) Tap (NDI (KKBI Ma Ke Matlel pound Sery Valve Type laleh Type Pon Slss (el iRO sun (pig Run Oae coin 9,466.6 5,766.5 Camco KBMG 1 INJ DV INT 0000 0.0 12/212018 Notes: General & Safety End Date Annoetion 7/19/2005 NOTE: WAIVERED WELL: T v[ACOMMUNICATION &IV2U09 NOTE: TAG OBSTRUCTION @9098'SLIM 9-22010 NOTE: View Sohema0c wl Alaska Schematr9. IPERra)so.os,ew.o— 1WO18 NOTE: Vier SMerri w/ Alaska bonematic 109 (PERF: BaTe.o9.eW 0� FIBN:E903.0 IPERF:0.P000L ENI PROWCTON:EB101864 Operations Summary (with Timelog Depths) 3H-18 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Cepm Start Time End Time our(hr) Phase op Code Activity Code Time P -T -X Operation MKS) End Depth(flKB) 12/7/2018 12/8/2018 3.00 MIRU MOVE RURD P Continue cleaning pits. Break down 21:00 00:00 berming. Prep cellar for transport. 12/8/2018 12/8/2018 11.00 MIRU MOVE MOB P (MIRU on 31-1-18) Empty pits and kill 00:00 11:00 tank, move pits off of sub base. Mobilize rig sub base off 31-1-04. 12/8/2018 12/8/2018 3.00 MIRU MOVE MOB P (MIRU on 31-1-18) Spot sub base over 11:00 14:00 31-1-18 mobilize pits into location, make up interconnect. 12/8/2018 12/8/2018 1.00 MIRU WELCTL MPSP P RU lubricator to pull BPV start taking 14:00 15:00 on kill weight fluid. Rig accepted at 15:00 Hrs 12/8/2018 12/8/2018 1.00 MIRU WELCTL MPSP P Pull BPV and LD lubricator secure 15:00 16:00 well. 12/8/2018 12/8/2018 4.00 MIRU WELCTL RURD P RU circulating lines for well kill 16:00 20:00 continue to load pits. Load pits with 11.1 PPG NaBr/NaCl. Test circulating lines and tiger tank lines to 2500 PSI. 12/8/2018 12/9/2018 4.00 MIRU WELCTL KLWL P Pump 11.1 PPG KWF around STS at 20:00 00:00 2 BPM. Maintained back pressure with choke until KWF started up the backside. Opened choke all the way. Pumped a total of 436 Bbls. Lost 131 Bbls to well over circulation. 12/9/2018 12/9/2018 1.00 MIRU WELCTL OWFF P 11.1 PPG fluid coming back. Shut 00:00 01:00 well in monitor pressures. Blow down tiger tank lines and choke house. 100 PSI on tubing 200 PSI on IA. 12/9/2018 12/9/2018 3.00 MIRU WELCTL KLWL P Line up to take returns through rig 01:00 04:00 choke manifold and poor boy degasser. Circulate BU+. Pumped 253 Bbls. Lost 73 Bbls to well during circulation. 12/9/2018 12/9/2018 3.00 MIRU WELCTL OWFF T Shut well in monitor pressures. 04:00 07:00 Iniatiall50 PSI on tubing 240 PSI on IA. After 30 min 100 PSI on tubing 175 PSI on IA. Open up and bleed 1.6 Bbls through super choke into trip tank. Shut back in 40 PSI on tubing 110 PSI IA. After 30 min 50 PSI on tubing and 130 PSI IA. Open up bleed 1.6 Bbls. to TT. SI 25 PSI on tubing 100 PSI on IA. After 30 min 25 PSI on tubing 110 PSI on IA. Open up IA to trip tank through wide open super choke recording volume gain every 5 min. Return volumes per 5 min: 1.6, 1.3. Shut well back in 0 PSI on tubing 50 PSI on IA. Decision made to weigh system up to 11.3 12/9/2018 12/9/2018 9.00 MIRU WELCTL KLWL T Mixing Sodium Bromide to weight 07:00 16:00 1 system up to 11.3 12/9/2018 12/9/2018 4.50 MIRU WELCTL KLWL T Circulate 11.3 PPG NaBr/NaCl down 16:00 20:30 IA taking returns up tubing. Pumped 280 Bbls. Shut down to mix more 11.3 PPG. Pump additional 92 Bbls down backside. Lost 38 Bbis to well during circulation. 12/9/2018 12/9/2018 2.00 MIRU WELCTL OWFF T Shut well in monitor pressures. 0 PSI 20:30 22:30 on tubing and IA for 30 min. Opened bleeder on both tubing and IA sides independently both sides on vac. Weight up HEC pill to 11.3 PPG. Page 115 ReportPrinted: 12126/2018 Operations Summary (with Timelog Depths) 3H-18 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth rt De Start TMe EM Time our tv ( ) Phase O Code p Activity Code ry Time Pd -X operation Entl Depth (RKB) 12/9/2018 12/9/2018 1.00 MIRU WELCTL KI -WL T Spot 50 Bbls HEC pill at top of perfs, 22:30 23:30 pump down tubing taking returns out IA. Lost 3 Bbls to well during circulation. 12/9/2018 12/10/2018 0.50 MIRU WELCTL OWFF T Shut well in monitor pressures. 0 PSI 23:30 00:00 on tubing and IA 12/10/2018 12/10/2018 0.50 MIRU WELCTL OWFF T Cont monitor well. 0 PSI on tubing 00:00 00:30 1 and IA. Open bleeders well on vac 12/10/2018 12/10/2018 0.50 MIRU WHDBOP MPSP P Dry rod in H BPV 00:30 01:00 12/10/2018 12/10/2018 0.50 MIRU WHDBOP PRTS P Rolling test on BPV to 1000 PSI for 5 01:00 01:30 min. Pump at 4.15 BPM no flow through tubing. Lost 31 Bbls to well during test. 12/10/2018 12/10/2018 8.00 MIRU WHDBOP NUND P ND tree. Inspect tubing hanger 01:30 09:30 threads. Install blanking plug 11 1/2 turns. NU BOP's 12/10/2018 12/10/2018 0.50 MIRU WHDBOP SFTY P PJSM/operational mtg. for testing 09:30 10:00 1 BOPE with dg crew. 12/10/2018 12/10/2018 6.00 MIRU WHDBOP BOPE P Flood all surface equipment choke,kill, 10:00 16:00 manifold evac air from system. Wittness waived by AOGCC rep Bob Noble. Start BOPE test: Test#1: BR, CMV 1-2-3-16, 2" Demco Kill. IBOP Test#2: CMV 4-5-6, HCR Kill, Saver sub Test#3: CMV 7-8-9. Manual Kill, HT -38 Standing valve, Test#4: Super choke/Man choke Test#5: Annular, FOSV, HT -38 dart valve, CMV 10-11 Test#6: UPR, CMV 12-13-15 Test#7: CCMV14 Test#8: Choke HCR Test#9: UPR, Manual Choke Test#10: LPR Test #11: DDT Koomey time 12/10/2018 12/10/2018 2.00 MIRU WHDBOP RURD P RD test equipment blow down lines 16:00 18:00 and pull test joint and blanking plug. Spot Pollard E -line unit simultaneously 12/10/2018 12/10/2018 2.00 COMPZN RPCOMP PULL P MU landing pup joints. BOLDS. PU 18:00 20:00 on string hanger unseated at 30K work up to 87K PUWT on string. Unable to pull free. Set in slips with 15K over string weight from upcoming cut depth. Break out upper landing pup joint. 12/10/2018 12/10/2018 2.50 COMPZN RPCOMP RURD P RU Pollard E -Line. 20:00 22:30 12/10/2018 12/11/2018 1.50 COMPZN RPCOMP ELNE P RIH with CCL and Chemical cutter at 22:30 00:00 2000' 12/11/2018 12/11/2018 3.50 COMPZN RPCOMP ELNE P RU cement hose to Pollard pump in 00:00 03:30 sub. Pump E -Line down 1 BPM 400 PSI. Correlate with CCL. Cut tubing at 6971' with chem cutter. Good indication of cut at surface. POOH. Difficulty pulling cutter up through SSSV. 12/11/2018 12/11/2018 2.50 COMPZN RPCOMP ELNE T Attempted to circulate through the 03:30 06:00 SSSV down the tubing to IA and work TS through the flapper. unable to make it through the flapper. Pumped dry job. Page 2/5 ReportPrinted: 12/26/2018 Operations Summary (with Timelog Depths) 3H-18 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time End Tme our (hr) Phase O Code Op Aclivi Code ty Time P -T- X Oparebon ebrt Depth MKS) End Depth (i1K8) 12/11/2018 12/11/2018 1.50 COMPZN RPCOMP ELNE T Re -rig E -line sheaves, pull hanger to 06:00 07:30 floor, pump open SSSV at hanger body. POOH with Eline to top of safety valve, re -land tubing hanger. 12/11/2018 12/11/2018 1.50 COMPZN RPCOMP ELNE P Pooh with E -line from SSSV at 1890' 07:30 09:00 MD and RD E -line. 12/11/2018 12/11/2018 0.50 COMPZN RPCOMP SFTY P PJSM for laying down tubing. 09:00 09:30 12/11/2018 12/11/2018 0.25 COMPZN RPCOMP RURD P Rig up to pull tubing from chem cut at 09:30 09:45 6971' 12/11/2018 12/11/2018 0.75 COMPZN RPCOMP RURD P RU power tongs, SLB spooler, to pull 09:45 10:30 tubing 12/11/2018 12/11/2018 4.00 COMPZN RPCOMP PULL P Pull hanger to floor, lay down landing 6,971.0 6,936.0 10:30 14:30 joint and tubing hanger, continue to POOH with tubing (PU WT=70K) from surface to SSSV at 1822.0' MD 12/11/2018 12/11/2018 0.50 COMPZN RPCOMP RURD P Clear floor of SLB spooler, RD SLB 5,114.0 5,114.0 14:30 15:00 1 1 spooling tools. 12/11/2018 12/12/2018 9.00 COMPZN RPCOMP PULL P Continue to lay down tubing from 5,114.0 36.0 15:00 00:00 SSSV a11822' MD to cut at 6971' Tot lay down 225 jt 9.3# J-55 BTC ,21' cut joint,2 GLM and 1 SSSV 12/12/2018 12/12/2018 3.00 COMPZN RPCOMP RURD P R/D Tubing Euipment, Install W.R. 00:00 03:00 1 Bushing and clean up floor. 12/12/2018 12/12/2018 2.00 COMPZN RPCOMP BHAH P PJSM Make up BHA # 1 w/ overshot 03:00 05:00 12/12/2018 12/12/2018 4.00 COMPZN RPCOMP PULD P Continue P/U 3 1/2" work string and 05:00 09:00 1 1 RIH to 3640' MD 12/12/2018 12/12/2018 2.00 COMPZN RPCOMP SVRG P Slip and cut drilling line 09:00 11:00 12/12/2018 12/12/2018 4.50 COMPZN RPCOMP TRIP P TIH to top of cut joint at 6962' MD. 11:00 15:30 12/12/2018 12/12/2018 0.50 COMPZN RPCOMP FISH P Established SPR's 2BPM=100 PSI 15:30 16:00 3BPM=200 PSI Rot Wt=98K at 14 RPM. PU WT = 125K Space out DP and engage fish 6959' RKB. 12/12/2018 12/12/2018 0.50 COMPZN RPCOMP JAR P PU 175K 50Kover sting fired jars, WT 16:00 16:30 broke back to 110K straight pull to 145K string moving freely 12/12/2018 12/12/2018 4.00 COMPZN RPCOMP CIRC P Close annular, line up to gas buster 16:30 20:30 and ciculate surface to surface. 12/12/2018 12/13/2018 3.50 COMPZN RPCOMP TRIP P TOOH with DP to fish. 20:30 00:00 12/13/2018 12/13/2018 1.00 COMPZN RPCOMP TRIP P TOOH with DP to fish. 9,577.9 9,577.9 00:00 01:00 12/13/2018 12/13/2018 2.50 COMPZN RPCOMP BHAH P PJSM UD BHA# 1 and R/U to UD 3 2,642.4 2,629.2 01:00 03:30 1/2" 9.3# BTC J-55 Tubing 12/13/2018 12/13/2018 6.50 COMPZN RPCOMP PULL P Continue UD 3 1/2" 9.3 # BTC J-55 2,629.2 0.0 03:30 10:00 Tubing 12/13/2018 12/13/2018 1.00 COMPZN WELLPR RURD P RD tubing handling tools RU DP 0.0 0.0 10:00 11:00 handling tools. 12/13/2018 12/13/2018 1.00 COMPZN WELLPR BHAH P MU BHA #2 G -plug 0.0 20.5 11:00 12:00 12/13/2018 12/13/2018 4.50 COMPZN WELLPR PULD P Single in 90 joints of 3-1/2" DP. 20.5 2,810.0 12:00 16:30 12/13/201812/13/2018 5.00 COMPZN WELLPR TRIP P Start trip in hole with stands, hold pre 2,810.0 5,000.0 16:30 21:30 j j tour meeting discuss plan forward, continue tripping in hole. Page 315 Report Printed: 1212612018 Operations Summary (with Timelog Depths) 3H-18 Job: RECOMPLETION Rig: NABORS 7ES Time Log slart Depth StartTime End Tune our (hr) Phase Op Code Ad Ity Code Time P -T -X P Openihon Set RBP @ 9448' top of plug @ 9443' (MB) 5,000.0 End Depth Me) 9,448.0 12/13/2018 12/13/2018 1.00 COMPZN WELLPR MPSP PUW156 SOW 90 Release pull 2 21:30 22:30 STD test plug t/1500 PSI Allgood 12/13/2018 12/14/2018 1.50 COMPZN WELLPR TRIP P POOH and STD back 30 Stds of 3 9,448.0 6,640.0 22:30 00:00 1/2" Work string 12/14/2018 12/14/2018 1.50 COMPZN WELLPR TRIP P TOOH with stands to 4752' Up 6.640.0 4,752.0 00:00 01:30 WT=95K DWT=65K 12/14/2018 12/14/2018 0.50 COMPZN WELLPR MPSP P MU storm packer 01:30 02:00 12/14/2018 12/14/2018 0.50 COMPZN WELLPR MPSP P TIH with storm packer and set at 90' 02:00 02:30 12/14/2018 12/14/2018 0.50 COMPZN WE- RURD P Pull wear ring 02:30 03:00 12/14/2018 12/14/2018 1.50 COMPZN WELLPR NUND P NO BOPE and stand back remove 03:00 04:30 DSA and ann valve. 12/14/2018 12/14/2018 4.00 COMPZN WELLPR CUTP P7- Remove tubing head, pull pack off and spear 7" 26# J-55 casing. PU 225K 04:30 08:30 and set on slips. BO spear same. 12/14/2018 12/14/2018 3.00 COMPZN WELLPR CUTP P Cul do casing to accommotlate new tubing head. cut off xx" of casing 08:30 11:30 12/14/2018 12/14/2018 1.50 COMPZN WELLPR NUND P Install new Cameron "C" -Bowl tubing head. FFill void with plastic pack and 11:30 13:00 energize seals. 12/14/2018 12/14/2018 0.50 COMPZN WELLPR -RTS P Pressure test 7" casing pack -off to 13:00 13:30 3000 psi for 30 minutes. 12/14/2018 12/14/2018 0.50 COMPZN WELLPR SF1 T7- PJSM for NU BOPE. 13:30 14:00 12/14/2018 12/14/2018 2.00 COMPZN WELLPR NUND P Set 7" x 11" adapter and 11"x13" DSA. NU BOPE and charge system set test 14:00 16:00 plug in new tubing spool. 12/14/2018 12/14/2018 1.50 COMPZN WELLPR BOPE P Fill stack with brine shell test BOPE to 250/3000 psi for five minutes each. 16:00 17:30 12/14/2018 12114/2018 1.50 COMPZN WELLPR RURD P R/D test euipment and install wear 17:30 19:00 ring bushing 12/14/2018 12/14/2018 1.50 COMPZN WELLPR MPSP P M/U Baker retrieving tool KIN 104' and latch up on storm PKR POH and L/D 19:00 20:30 same 12/1412018 12!15/2018 3.50 COMPZN WELLPR TRIP P RIH w/ 3 1/2" work string f/ derrick 4,752.0 9.443.0 20:30 12/15/2018 00:00 12/15/2018 1.00 COMPZN WELLPR MPSP P Continue RIH t/ 9448' Latch on to 9,448.0 9,438.0 Baker RBP and Release Plug PUH 00:00 01:00 10'. 12/15/2018 12/15/2018 2.00 COMPZN WELLPR CIRC P CBU @ 4 BBLS 850 PSI. 9,438.0 9,438.0 01:00 12/15/2018 03:00 12/15/2018 9.00 COMPZN WELLPR -P-ULD P L/D31/2"workstring 9,438.0 20.5 03:00 12/15/2018 12:00 12/15/2018 0.50 Z -CO -MP N WELLPR BHAH P Lay down BHA# RBP 20.5 0.0 12:00 12115/2018 12:30 12/15/2018 0.50 Z CO -MP N RPCOMP KURD P PU test plug running tool and retrieve 0.0 0.0 wear ring from tubing head. 12:30 12/15/2018 13:00 12/15/2018 1.00 COMPZN RPCOMP 'ITU -RD P Clear floor and RU tubing running 0.0 0.0 tools. Verify joint count and jewelry in 13:00 14:00 pipe shed. 310 total joints 1 MMG mandrel, 1 Camco X -nipple. 12/15/2018 12/15/2018 0.50 COMPZN RPCOMP SFTV P PJSM for running tubing, review 0.0 procedure and hazard mitigations. 14:00 14:30 12/15/2018 12/15/2018 0.50 COMPZN RPCOMP -!TV-RG- 77- Service Rig 14:30 12/15/2018 15:00 12/15/2018 1.00 COMPZN RPCOMP PUTB P M/U Baker seal Assembly,/ joint 3-1/2' 0.0 160.0 joint, EUE 8rd 9.3# L -80,w/ X nipple,1 joint, 15:00 16:00 3 1/2" EUE 8rd w/ 1 GLM w/ SOV Page 415 Report Printed: 1212612018 ALOperations Summary (with Timelog Depths) 3H-18 Rig: NABORS 7ES Job: RECOMPLETION Time Log span Dept Stan Time End-rme Dur(hr) Phase Dp Code Activity Code Time P -T -X Operation (lin) End Depth(fiKin 12/15/2018 11211612018 8.00 COMPZN RPCOMP PUTB P Continue PIU 3 1/2" EUE 8rd 9.3# L- 160.0 5,060.0 16:00 00:00 80 MOD Tubing MIN Tq 3100 FTP 12/16/2018 12/16/2018 6.00 COMPZN RPCOMP PUTB P Continue P/U 3 1/2" EUE 8rd 9.3# L- 5,060.0 9,550.0 00:00 06:00 80 MOD Tubing M/U torque 3100 Ft/Lbs. from 5037' MD to 9550' MD. PU WT=84K DN WT=64K. 12/16/2018 12/16/2018 1.00 COMPZN RPCOMP HOSO P Tagged top of PBR at 9577.88' fully 9,550.0 9,589.7 06:00 07:00 located at 9589.68' MD. Lay down 3 joints, PU 17.23' space out pups, joint 305 and tubing hanger. 12/16/2018 12/16/2018 1.50 COMPZN RPCOMP HOSO P Mu Space out pups and single PU lag 9,589.7 9,575.0 07:00 08:30 joint and hanger, MU to string at floor. 12/16/2018 12/16/2018 0.50 COMPZN RPCOMP RURD P Prep and RU to test on floor. 9,575.0 9,575.0 08:30 09:00 12/16/2018 12/16/2018 0.50 COMPZN RPCOMP WAIT T Waiting on AES trucking support—with 9,575.0 9,575.0 09:00 09:30 corrosion inhibitor due to mechanical failure on vac truck 24 hour advance notice was given. 12/16/2018 12/16/2018 1.00 COMPZN RPCOMP CRIH P Spot 1% corrosion inhibited 11.3 ppg 9,575.0 9,575.0 09:30 10:30 brine from 8869' to 9575' at 4 bpm chased with 76 bbls 11.3 brine. 12/16/2018 12/16/2018 0.50 COMPZN RPCOMP THGR P Drain BOPE stack and land tubing 9,575.0 9,586.1 10:30 11:00 hanger at 24.10' 7ES RKB, P/U=90K, SOW=63K RILDS, Space out seal assembly 3.59' from fully located depth at 9586.09' MD. 12/1612018 12/1612018 2.50 COMPZN RPCOMP PRTS P Drop ball and rod with 1.3125" ball 9,586.1 9,586.1 11:00 13:30 and 1-1/2" rope socket. Pressure test tubing to 3000 psi for 15 minutes, bled back tubing to 1500 psi pressure tested 7" casing to 2500 psi for 15 minutes. Bled off tubing and sheared SOV, established communication T x IA and IA xT. 12/16/2018 1.00 COMPZN WHOBOP MPSP P B/O landing joint and set BPV 14:30 12/16/2018 2.50 COMPZN WHDBOP W W WH P Flush BOP stack out with Clean water 17:00 through choke manifold.kill line and r162 function all rams 12/16/2018 5.50 COMPZN WHDBOP SVRG P Perform BOP inspection,open All ram 22:30 doors on stack Due to AOGCC Program inspection. 12/17/2018 1.50 COMPZN WHDBOP NUND P N/D BOP slack 22:30 00:00 12/17/2018 12/17/2018 1.00 COMPZN WHDBOP NUND P Finish N/D bop 00:00 01:00 12/17/2018 12/17/2018 4.00 COMPZN WHDBOP NUND P Install well head adapter flange and 01:00 05:00 test 5000 psi U 15 mins ok and install production tree test tree t/ 5000 psi 12/17/2018 12/17/2018 7.00 COMPZN WHDBOP FRZP P R/U LRS and test lines U 2500 psi 05:00 12:00 Circ Down Ann 1% corrosion inhibited seawater 251 bbls followed w/ 82 bbls diesel and U -Tub 12/17/2018 12/17/2018 2.00 COMPZN WHDBOP MPSP P Lubricate in CIW H -plug BPV. LD 12:00 14:00 lubricator and secure well. Release rig at 1400. Page 515 ReportPrinted: 1 212 612 01 8 ORIGINATED •• 1/14/2019 ALASKA E -LINE SERVICES 01142019 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 • Kuparuk PH: (907) 283-7374 FAX: (907) 283-7378 RECEIVED 3 0 2 5 4 JAN 16 2019 DELIVERABLE DESCRIPTION LOG DESCRIPTION DATE OF • 2649 3H-18 50-103-20095-00 1 CCL -Final Field 12/10/2018 BP North Slope 1 0 0 1 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 USPS Tracking # Conoco Phillips Alaska Inc. 0 1 0 1 1 Attn: NSK-69 700 G Street Anchorage, Alaska 99501 USPS Tracking # 9405 5036 9930 0389 2658 77 AOGCC 0 0 1 ATTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 USPS Tracking # 9405 5036 9930 0388 0662 77 DNR 0 0 1 Attn: Garrett Brown -Geologist I DNR, Division of Oil & Gas 550 West 7th Ave, Suite #1100 - Anchorage, AK 99501 USPS Tracking # 9405 5036 9930 0388 0662 91 return via e-mail a copy to both Alaska E -Line Services and Conoco Phillips Alaska: terkamp@conocophillips.com reception(Make-line.com THE STATE °fALASKA GOVERNOR BILL WALKER Kyle Hampton Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3H-18 Permit to Drill Number: 188-009 Sundry Number: 318-460 Dear Mr. Hampton: Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Main: 907.297.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for the 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, Hollis S. French Chair DATED thisZy day of October, 2018. RBMi OCT 2 4 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Ju (Z4(1 V APPLICATION FOR SUNDRY APPROVALS 'rL1_YeU➢�7.T1 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑� Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑� Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development -. El Service d6, 188-009 ' 3. Address: API Number: P.O. Box 100360, Anchorage, AK 99510 IS 50-103-20095-00 -vU 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 3H-18 ' Will planned perforations require a spacing exception? Yes ❑ No Q 9. Property Designation (Lease Number):Ai 4 -A;V 3/ 10. Field/Pool(s): ADL X649 ,q l>` z55 1 Ku aruk River Field / Ku aruk 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): '� -B&t6 2,055 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 84 16" 115 115 Surface 4140 9-5/8" 4169 2966 Intermediate Production 10166 7" 10165 6130 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9790'-9860', 9878'-9899', 9900'- 5933'-5970', 5980'-5990', 3-1/2" L-80 9578 9920' 5991'-6001' Packers and SSSV Type: Packer (Baker FHL) Packers and SSSV MD (ft) and TVD (ft): Packer (9591'15,831') SSSV (Camoo TRDP-IA-SSA) SSV (1822' / 1647') 12. Attachments: Proposal Summary , Wellbore schematic 13. Well Class after proposed work: /D, o" /F Detailed Operations Program ❑ BOP Sketch ❑� Exploratory ❑ Strati ra hic g p ❑ Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/1/2018 OIL ❑ WINJ ❑� WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Kyle Hampton Contact Name: Kyle Hampton Authorized Title: Sr. Wells Engineer Contact Email: k le.ham ton Co .Com ( O� /p/Z ptp Contact Phone: 263-4627 Authorized Signature: Date: -Omofi2Bi8w G COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 4 LOO Plug Integrity ❑ BOP Test u Mechanical Integrity Test Location Clearance ❑ Other: B o p to ff-fi, #,) p, -c ✓ sv, f r ✓ ft5 � % Z sv v /� �J Post Initial Injection MIT Req'd? Yes �'No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: - Qa APPROVED BY I D I Zi I (� Approved by: COMMISSIONER THE COMMISSION Date: GI NAS �.,�, / "0 Submit Form and �J' .VIS( Form 10403 Revised 4/14W Wap i from the date of approval. Attachmen n Duplicate ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 10 October, 2018 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7" Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner:► ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over KuparukPer 3H-18 (PTD# 188-009). Well 3H-18 was drilled and completed in March 1988 as a Kuparuk C sand producer well. The C -sand was stimulated in June 1988. In 1996, the A -sand was perforated, and the well was turned into an injector. In 2001, a tubing leak was discovered via leak detect log at 7,010' RKB and a patch was installed. In 2005, another tubing leak was discovered, but the well was waivered for water injection only. In Feb 2018, the well was shut-in in anticipation of the upcoming RWO. In October 2018, the well passed MITOA to 1800 psi, IC POT, IC PPPOT, T POT, and T PPPOT. The objective of this rig workover is to pull and replace the production tubing. We will be pulling out of the seals above the current packer at 9,59 P MD and stacking a packer with a non -sealing overshot. If you have any questions or require any further information, please contact me at 263-4627. Sincerely, ��L q�A6_ Kyle Hampton Senior Wells Engineer CPAI Drilling and Wells 3H-18 RWO Procedure Kuparuk Injector PTD #188-009 Current Status: The well is currently shut in. In Feb 2018, the well was shut-in for the repair of the tubing due to a TxIA leak that was discovered in 2005. In October 2018, the well passed MITOA to 1,800 psi, IC POT, IC PPPOT, T POT, and T PPPOT. In May 2016, a SBHP of 3,145 psi was measured. Scope of Work: Pull the tubing out of the seals at 9,578' RKB. Run in the hole with a non -sealing overshot and packer, stabbing into the seals above the current packer. Bring the well back to injection. ✓ General Well info: MPSP: 2,546 psi (using 0.1 psi/ft gas gradient) Reservoir pressure/TVD: Combined Kuparuk A & C -Sands — 3,145 psi / 5,987' TVD (10.1 ppg EMW) 10.3 ppg KWF Wellhead type/pressure rating: McEvoy Gen 3, 7 1/16" 5M BOP Config: Annular / Variable Pipe Ram / Blind Ram / Pipe Ram MIT results: MIT -OA— Passed to 1,800 psig/Opsig on 10/3/2018 Well Type: Injector d Estimated Start Date: November 1, 2018 Production Engineers: Kenneth Lloyd Martin/Toon Changklungdee Workover Engineer: Kyle Hampton (263-4627 / Kyle.Hampton@conocophilIips.com) Remaining Pre -Rig Work 1. Pull lower GLV, Swap to dry hole tree configuration for RU. 2. Install BPV. Rig Work MIRU 1. MIRU on well location. 2. Pull BPV and pump kill weight fluid. 3. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure, and weight up fluid as necessary. Complete 30 -minute NFT. Verify well is dead. 4. Set BPV, ND Tree, NU BOPE (Configuration B) and test to 250/2,500 psi. Test annular 250/2,500 psi. a. Notify AOGCC of BOP test 24 hours prior to nipple up and every 7 days thereafter or when the stack is broken. Retrieve Tubing 5. Pull BPV and MU landing joint. 6. Pull 3-1/2" tubing and lay down the tubing. Install in 3-Y" Tubing 7. MU 3 %:" completion with non -sealing overshot, packer, and tubing. RIH and place the packer above the existing packer. Set packer with ball and rod. 8. Pressure test tubing to 3000 psi for 5 minutes. 9. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ✓ ND BOP, NU Tree Page 1 of 2 17'- NABORS ALASKA RIG 7ES BOP STACK CONFIGURATION IJ 5/8" 50001 WP HYDRIL, TYPE "GK" 13 5/8" 50001 WP LATCHED TOP BY 13 5/8" FLANGED BOTTOM ANNULAR BOP 54 1/2" LENGTH 13-5/8" 50001 FLANGED HYDRIL DOUBLE GATE PREVENTOR 58 1/8" LENGTH 3" 50001 HCR VALVE 2" KILL LINE 0001 GATE VALVE - HYDRIL 13-5 8" 5k PSI HYDRAULIC RA SINGLE GATE FLANGE. CONNECTION 36 LENGTH KUP INJ "'Wlips ll Attributes Conoco ""�I''S Weervamc Alaska,lhc. KI IPARIIK RIVFR IINI NEI WO 3H-18 aK.1e.lawm+e e:m 4a AM Last Tag Varuz xn^nalclae'YI Annotation Ena O,m DepIn IBKBI Vat M1IW By last Tag:SLM 512412016 9.8]2.0 .proven w,xDER; asp cLHo.T.P 3c1111.D saFErvvLv',+ea.o GAS UFT: at. suRPACE,xw,lms— lmf:aro3a PATCHL69i PAEUI 69110 rx+suFT', a.. PBR:9.Sll.B \ PACKER:%Rub nA V�1 xIPPLE', 98A.4 MNa. a..1 \ PERF 97900-96900 /PERF:9eTfla9.me.p—� FIBX: B,dR,O (PERF, 99]1Dacco0 PRODUCTION.35.0-10.10.4 '- 1 Last Rev Reason AnoOlaron Dale Last lose 9y Rev R..s TAG 5'"56612016 .proven Casing Strings Lasing DeccnpBon ODlln) IDnnf TOPInKL* swcepM RK01 set CepM IND/... WVLen ...,Neale TopT ED CONDUCTOR 16 15.06 3fi0 1150 115.0 fi2.50 H-00 WELDED Lasing Dean Iui— OD gn)ID lip Tap lN(BI Se10epN lRNB1 aN DI'M RVD1...wuten h—librade TOPThrea4 SURFACE 9518 8.92 35.0 4,160.5 2,9663 3600 J-55 BTC linin. Descnpxon I OD Op mlml TOP he"o an Vi INNER) I all Dion Rvo)...wpLen V- creta ToPThnea PRODUCTION ] 628 35.0 10,1654 6,130.1 26.00 J-55 BTG Tubing Strings Tulin. Daunpnon mina I.la... ID ImI TOP lnleel 9,t De (n.. set be (ND) l-. wl llluvn Bmea rop eonnedbn TUBING 3112 2.99 350 9,663.0 5,868.0 9.30 J-55 BTC AB -MOD Completion Details III mm ""u"i xamm,l Top Me) inks) I.1 nam Das coin mop 35.0 350 003 HANGER MCEVOY TUBING HANGER 3500 1,822.0 1,647] 45 d2 SAFETY VLV CAMCO TRDP-tA-SSA SAPETVVALVE 2.812 9,5]].9 5,8241 58.92 PBR BAKER PER 4000 9,591. 5,8312 56.93 PACKER BAKER FHL PACKER 2992 —9-6274— 5.850.7 58.98 NIPPLE CAMCO D NIPPLE NO GO 2750 9,662.1 5,867.5 5903 505 BROWN SHEAR OUT SUB 3.000 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top RVDI Top mal TepIKKBI (nKB1 l') Des coin RunD. 10Ii.) 6,990.0 4,449.2 58.34 PATCH 205' HES tubing patch over hole @ ]005' )1322001 ,902.0 5,991.8 58.31 FISH 111, DMY Empty Pocket, OroppeUin Rathole 82Y1989 Perforations & Slots ToPVl BM MB) TOPRVD) "B) Blar "IR (BKBI LlnkM lun DM .hot Dene Nhotbat I Type Lwn 9,790.0 9,860.0 5,933A 5,969.8 C74,3H-18 8/611988 12.0 /PERF 4eg.pbasing, 1 " EnerJet 98780 9,899.0 5,9]9.2 5,9902 A-1,31-1 61311996 40 (PERF eroDeg.pbasing, L' EnerJet $900.0 9,920.0 5,9908 60013 A -T H-18 5x]11988 40 _PERF M Beg.p sung, Ultra Pack Mandrel Inserts m I TOPOVDI Valve Lakn Pert Size TRORun N TOP BMBI MKBI MaFe MMeI ODIip Sery B. Type Bp 11 Run Date Com 1 3,139.2 2,42fi5 CAMCO KBUG 1 GASLIFT DMY BK -2 0000 0.0 62J 2 6,603.3 4,242.6 CAMCO Inc.. 1 1 1.P, LIFT DMY SK -2 JIAAJI 0.0 IbLi7lable 3 8,911.0 5,411.9 CAMCO KBUG 1 GASLIFT DMY BK -2 0.000 00 212611 J 4 9,536.8 1 5,802.9 CAMCG MMU -2 I 12 GASLIFT DMY RK I 0.000 00 11122/1 96 Notes: General & Safety End Dale nonontlOa ]11912005 NOTE WAIVERED WELL: T x IA COMMUNICATION 61112009 I NOTE: TAG OBSTRUCTION X19898' SILM 902010 INCTE: View Schematic .1 Alaska Schemal Loepp, Victoria T (DOA) From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, October 24, 2018 10:26 AM To: Loepp, Victoria T (DOA) Subject: RE: [EXTERNAL]KRU 3H-18(PTD 188-009, Sundry 318-460) RWO to change out tubing Victoria, We are planning to land the stacked packer as close as possible to the existing packer. Given the existing at 9,591' and top of the seals at 9,578', we would stack an overshot (20'), pup joint (5'), nipple profile (3'), pup joint (5'), pup joint (5'), and packer (8'). This lands the top of the packer at -9,532'. Thanks for the help on this. We are running into some scheduling crunches and trying to work through our options. Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 Kyle.Hampton@cop.com From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Wednesday, October 24, 201810:13 AM To: Hampton, Kyle <Kyle.Hampton @conocophillips.com> Subject: [EXTERNAL]KRU 3H-18(PTD 188-009, Sundry 318-460) RWO to change out tubing Kyle, How far above the existing packer will the stacked packer be? Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. Loepp(daiaska.00v CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete if, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)7931247 or victoria LoeaPsolaskaspv Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Wednesday, October 24, 2018 9:06 AM To: 'Hampton, Kyle' Subject: RE: 3H-18 Sundry That's feasible. When is the new commencement date? From: Hampton, Kyle <Kyle.Hampton@conocophillips.com> Sent: Wednesday, October 24, 2018 8:23 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Cc: Haggerty -Sherrod, Ann (Northland Staffing Services) <Ann.Haggerty-Sherrod@contractor.conocophillips.com> Subject: 3H-18 Sundry Victoria, I wanted to try to check in to see how the sundry for 3H-18 was coming. We just recently had some schedule delays that may affect getting on 3C-08 next with Nabors 7ES. We are considering moving to 3H-18 after 1C-26. How feasible would this be? Thanks, Kyle Hampton Senior Wells Engineer I Office. 907-263-4627 1 Cell. 832-421-1506 1 KVIe.Hampton@cop.com CONOCOPHILLIPS ALASKA, INC., KUPARUK RIV UNIT 31-1-18 (188-009) KUPARUK RIVER, KUPARUK RIV OIL Monthly Production Rates 1,000,000 100,000 t Y c c0 10,000 G d Q LL 1,000 u 100 10 1,000,000 100,000 W v 1 l 10,000 N 13 1,000 0 3 100 s 10 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 Monthly Injection Rates 1,000,000 100,000 L Y i 0 10,000 L d C 1,000 LL u 100 10 1,000,000 W d 100,000 m 0 10,000 m M 1,000 m 100 0 s 10 Jan -1985 Jan -1990 Jan -1995 Jan -2000 Jan -2005 Jan -2010 Jan -2015 Jan -2020 SPREADSHEET_Prod-I nject_Cumes_W ell_V 116_1880090_KRU-3H-18_20181010.xlsx 10/11/2018 ll- O 0 O , • • Sa O V° If ro m ~ >. b° r o w ' 1 wiew v O O J ( CD L L + N _ C�7�Z� 00 �'' c0 >. 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U h. 0 0 N N M M 0 M 0 N N N N N N N N N N ` _9 R 0) M O) O) 0) 0) 0) M 0) G) vi O N 0 N N N N N 0 N �1 01 0 e- 0 O O O O e- O 3 L O O O O O O O O O 00 C U) lA U") 10 Ul U) A IA 1100. � I- [0 v f0 a) 1=1r„. z al E 0) � U W CC Y O )y CC C C U • Q L W E _Z w CU GO Q e'in O r r r) r) N E 47 U1 io = K cn ^ -1 LL Z 066 2 2 2 2 c° ` a C �. a Q O N J M M e- e- e- e- N 0 Z aJ N O0 .= ' ri L r W C +-, f6 to = eaov7 aub4 � 3 i L m H a a Q • pTD h98 -a°9 Loepp, Victoria T (DOA) From: Loepp,Victoria T(DOA) Sent: Tuesday, February 13, 2018 12:53 PM To: NSK Well Integrity Supv CPF3 and WNS;Wallace,Chris D (DOA) Cc: Senden, R.Tyler Subject: RE: 10-403 Requirement Clarification Rachel, Please prepare a 10-403 and outline the potential plans depending on the results of the diagnostics.A sundry is required when work is performed that impacts the IA on an injector. Thanx, Victoria From: NSK Well Integrity Supv CPF3 and WNS[mailto:n2549@conocophillips.com] Sent:Tuesday, February 13, 2018 11:54 AM To:Wallace,Chris D(DOA)<chris.wallace@alaska.gov>; Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:Senden, R.Tyler<R.Tyler.Senden@conocophillips.com> Subject: 10-403 Requirement Clarification Chris/Victoria, A Kuparuk injector 3H-18(PTD 188-009), as reported several years ago for IA pressurization. Subsequent diagnostics suggested TxIA communication an t e well has been shut-in since pending a repair plan. Additional diagnostics suggest the leak may be below an older existing patch. We need to pull the patch to investigate the tubing below the patch. Depending on the results of the diagnostics,we may or may not end up setting/resetting a patch. It is also possible we will attempt but be unable to pull the patch. In either case,a different repair plan would be pursued. We would certainly plan to submit a 10-403 to set/reset patches to repair the tubing. However,do we need to submit a 10-403 to pull the existing patch? Regards, Rachel Kautz/Travis Smith � Well Integrity Supervisor,ConocoPhillips Alaska Inc. SCANNED Office:907-659-7126 Cell:907-943-0450 1 • • la.t 31,_ )6 • f teegno Regg, James B (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Tuesday,June 27, 2017 8:19 AM To: Regg,James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA);Wallace, Chris D (DOA) Subject: Recent KRU MITs Attachments: MIT KRU 3H-22 & 24 06-24-17.xlsx; MIT KRU 3M-06 06-24-17.xlsx; MIT KRU 3K-15 06-24-17 .xlsx; MIT KRU 2K PAD 06-24-17.xlsx; MIT KRU 2S-13A 06-24-17.xlsx; MIT KRU 1C-150 & 152 06-25-17 .xlsx; MIT KRU 1B PAD WSW-05&06 06-25-17.xlsx; MIT KRU 3H PAD 06-24-17.xlsx Hello All— Attached, please find completed 10-426 forms for several recent MITs completed in KRU. Let me know if you have questions or comments. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED EP 1 42017, • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.reacaalaska.aov' AOGCC.Inspectorsi talaska.gov; phoebe.brooksCaaalaska.gov chris.wallacenalaska.gov OPERATOR: ConocoPhillips Alaska,Inc. FIELD I UNIT/PAD: Kuparuk/KRU/3H Pad /t ` q 77 f 7 DATE: 06/23/17 OPERATOR REP: Arend/Sumrall AOGCC REP: Waived by Chuck Scheve Well 3H-02 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1871070 Typelnj N Tubing 1160 1160 1160 1160 Type Test P Packer TVD 5759 BBL Pump 2.4 IA 150 2000 1910 1900 Interval 4 Test psi 1500 BBL Return 2.1 OA 110 130 130 130 Result P Notes: Well 3H-09 Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1871120 Typelnj N Tubing 1375 1375 1375 1375 Type Test P Packer TVD 5861 BBL Pump 1.6 IA 110 2100 2050 2045 Interval 4 Test psi 1500 BBL Return 1.8 OA 90 100 100 100 Result P Notes: Well 3H-12 A Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2110810 Typelnj N Tubing 1700 1700 1700 1700 Type Test P Packer TVD 5878 BBL Pump 0.7 IA 1575 2500 2460 2455 Interval 4 Test psi 1500 BBL Return 0.7 OA 180 180 180 180 Result P Notes: Well 3H-18 - Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. / PTD 1880090 Type Inj N , Tubing 1500 1500' 1500 - 1500 . Type Test P ✓ Packer TVD 5831 - BBL Pump 2.0 - IA 735 2200- 2140- 2130 - Interval 4 Test psi 1500 ' BBL Return 1.8 - OA 65 240 - 250- 245 - Result P IV Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Notes: TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W=Water P=Pressure Test I=Initial Test P=Pass G=Gas 0=Other(describe in Notes) 4=Four Year Cycle F=Fail S=Slurry V=Required by Variance I=Inconclusive I=Industrial Wastewater 0=Other(describe in notes) N=Not Injecting Form 10-426(Revised 01/2017) MIT KRU 31-I PAD 06-24-17 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 Organization (done) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals: [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: i-~'~ NOTES: ORGANIZED BY; BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds Other /S/ Project Proofing ti! [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Is~ PAGES: 1 ~)'~ (at the time of scanning) SCANNED BY2 BEVERLY BREN VINCENT SHERYL~LOWELL RESCANNEDBY:~ BREN VINCENT SHERYL MARIA LOWELL IS/ General Notes or Comments about this file: Quality Checked (done RevlNOTScanned.wpd ~ ~ Conoc P ' ' o hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 11, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission ~~ ~~ r~ ~/ 333 West 7~' Avenue, Suite 100 , / Anchora.ge, AK 99501 ,~ ~ ~ y~, ~ a.. ~ ~ V . .rv L. . ~ c.,~:. ~ ',i i..' ~ F ~ i.~,:'~ ~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRL~. Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatrnents took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped July 30~' 2009 and the corrosion inhibitor/sealant was pumped August 8~`, 9~' and l Oth 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~~G~' ( MJ Lov land ConocoPhillips Well Integrity Projects Supervisor ~ ~ ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 08/11/09 ~n_ ~u ov o on n,..~ ell Name PI # TD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date ,,., Corrosion inhibitor . Corrosion inhibitor/ sealant date bbls al 3G-12 50103201310000 1900730 24' 4.00 20" 7/30/2009 4.25 8/10/2009 3G-13 50103201370000 1901160 17" n/a 17" n/a 2.97 8/10/2009 3G-15 50103201390000 1901210 18" n!a 18" n/a 2.97 8/10/2009 3G-23 50103201440000 1901320 17" n/a 17" n/a 1.27 8/10/2009 3H-02 50103200830000 1871070 21" n/a 21" n/a 3.82 8/8/2009 3H-06 50103200780000 1870780 8'S" 2.00 18" 7/30/2009 5.52 8/8/2009 3H-07 50103200790000 1870790 17" n/a 17" n/a 2.97 8/8/2009 3H-09 50~03200860000 9871120 17" n/a 17" n/a 5.52 8/8/2009 3H-10B 50103200870200 2031600 16" n/a 16" n/a 2.55 8/8/2009 3H-12 50103200880000 1871290 2'7" n/a 2'7" n/a 8.92 8/9/2009 3H-15 50103200820000 1871030 19" n/a 19" . n/a 3.4 8/9/2009 3H-16A 50103200960100 2000220 15' 2.75 17" 7/30/2009 1.7 8/9/2009 3H-18 50103200950000 1880090 SF n/a 17" n/a 5.52 8/9/2009 3H-20 50103200930000 1871340 16' 3.75 16" 7/30/2009 2.25 $/9/2009 3H-22 50103200970000 1880110 27'6" 4.25 21" 7/30/2009 8.5 8/9/2009 3H-25 50103202030000 1990400 30" n/a 30" n/a 7.65 8/9/2009 3H-26 50103202080000 1940290 SF n!a 9" n/a 2.12 8/9/2009 3H-28A 50103202360100 1960370 SF n/a 18" n/a 5.1 8/9/2009 3H-32 50103203220000 2000010 10" n/a 10" n/a 1.27 8/9/2009 3K-102 50029233786000 2071650 n/a n/a 5" n/a 1.27 8/8/2009 3Q-01 50029222200000 1911250 15'7" 2.00 17" 7/30/2009 4.25 8/8/2009 3Q-02 50029216880000 1870040 41' 4.75 21" 7/30/2009 5.52 8/8/2009 3Q-04 50029222190000 1911240 4'10" 1.50 16" 7/30/2009 4.25 8/8/2009 3Q-07 50029216820000 1861940 6" n/a 6" n/a 1.7 8/9/2009 3Q-12 50029216770000 1861890 7" n/a 7" n/a 2.97 8/8/2009 3Q-13 50029216640000 1861760 44'6" 5.00 21" 7/30/2009 8.92 8/8/2009 3Q-15 50029216660000 1861780 49'5" 4.50 20" 7/30/2009 9.35 8/8/2009 3Q-16 50029216670000 1861790 46' 5.25 30" 7/30/2009 8.5 8/8/2009 ~ • MEMORANDUM 1'0: Jim Regg ~~~ ~~~p~~~~ P.I. Supervisor FROM: huck Scheve~ C Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, June 10, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3H-18 KUPARiIK RIV LJNIT 3H-18 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv v~>r~'- Comm Well Name: KUPARUK RIV LJNIT 3H-18 API Well Number: 50-103-20095-00-00 Inspector Name: Chuck Scheve Insp Num: micCS090608150550 Permit Number: 188-009-0 •i Inspection Date: 6~~~2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~l 3H-18 Type Inj. N 'j~~ 5831 jA 1220 2480 ~ - 2420 2420 P.T.D 188009o TypeTest SPT Test psi isoo p,~ ~ o 0 0 _ Interval antTST p~F r ~ Tubing ~ 600 ~ 6so ~oo ~oo Notes• Well waivered for IA x OA comunication. • `'-'~ S2~? ~-~p~ C' 9~"~ ~ulU;~ ~~;~3U,-~- ~Pt~6F:M (~11Q.~,Sc.(,Qc~,rtsci~^ ~CP~) 7~2~~~ ~~..: . .~ tb ~~ ~ , ~ ~11=:; )V~ .t ~ ... ... ~. ~ ~y'~y.~ . rv.r . , Wednesday, June 10, 2009 Page 1 of 1 ~ ~ Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Sunday, July 26, 2009 2:25 PM ~~ p~ I~-R~~~ To: Regg, James B (DOA) ~ ~ Cc: Schwartz, Guy L(DOA); NSK Problem Well Supv; NSK Weli Integrity Proj; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: RE: KRU 3H-18 (PTD 1880090) Jim, I have spoken with CPF3 Operations and confirmed that there is a laminated copy of a TxIA communication waiver in the waiver tube in the 3H-18 wellhouse. Considering this, I would assume that the documentation of IA x OA communication is a typo on Chuck Scheve's part. You are correct in saying that a patch was set on 07/31/01 as per Sundry 301-197 and documented in a subsequent 10-404 on 09/02/01. I plan to send a formal notification to Operations to remove the waiver from the wellhouse and return the well to Normal status. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Welis Supervisor ConocoPhillips Alaska inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, July 22, 2009 11:57 AM To: NSK Problem Well Supv Cc: Schwartz, Guy L (DOA) Subject: KRU 3H-18 (PTD 1880090) Inspector witnessed MIT for KRU 3H-18 (PTD 1880090) on 6/7/2009. Report attached. He notes the well is carrying a waiver for IA xOA communication. Last well integrity info I find in our well file was TxIA communication that was remedied with a tubing patch (sundry 301-197). Would appreciate ciarification. Thank you. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 7/27/2009 ~~r~~~~~i~~r Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth N0.4947 Well Job # ~.,~„ Log Description ~~ Company: Alaska Oil & Gas Cons Gomm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/29/08 3S-08C 12066554 MEM PRODUCTION PROFILE (,~ - ~' 10/14/08 1 1 1C-26 11978487 SBHP SURVEY I .(j ~ 10/15/08 1 1 iC-119 11978488 INJECTION PROFILE ~ 10/16/08 1 1 3H-15 12080445 INJECTION PROFILE - '~G/ 10/16/08 1 1 iC-121 11978490 INJECTION PROFILE 10/17/08 1 1 3H-18 12080446 INJECTION PROFILE ~ - 10/17/08 1 1 iJ-159 12097431 PRODUCTION PROFILE ~ y" 10/13/08 1 1 iF-10 12080453 INJECTION PROFILE 10/27/08 1 1 iC-121 11978490 INJECTION PROFILE 10/17/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ~~i-~ • ¡VIEMORA.NDUM . State of Alaska . "-Iaska Oil and Gas Conserv>1tion Commission TO: Jim Regg P.L SupenisorC/ 7/ 1''----.-··, q ( 1 DArE: IlIese/a\ JUtle:: 122007 / ! ~!. ,) 7 SIBJECT: \lcch:lI1icallntcgrn) Test; CONOCOP¡¡¡U.:rs '\LA.SL~ he: FRO~I: John Crisp Petroleum Inspector KUPA1UJK RIV UNIT 3H-18 ì ~~-{Joq Src: Inspector Reviewed By: P.L Suprv J'f32- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3H-18 Insp N um: mltJCr070612135244 Rei Insp Num: API Well Number: 50-103-20095-00-00 Permit Number: 188-009-0 Inspector Name: John Crisp Inspection Date: 6/8/2007 Packer Depth Pretest Initial ----I -.--,-.-. '---T- ¡- Well; 3H-I8 ,Type Inj. , N : TVD 5831 IA I 1335 -- --~---r---·t--~-----r- --------------+---~-- -~----~--- P.T.DI1880090 ¡TypeTest: SPT i Test psi . . I5000A. 230 260_260____26~~_ _____ I~~erv;._ ;-~HER- ---P/F -- -;- -- /c- -- -Tubing,- 13ÓO- -1300-~' 1300 i 1300, ; ~. _ ____ _._ _ ._____...___.. __....___._._L..~ ._~_.__~________~.._ _. .__.~__.___._ Notes: 3.3 bbJ's pumped for test. 2 year test, repair sundry # 301-197. 51 since 04!l5ì07 due to CPF 3 5W1 shutdown facility work. / 2990 15 Min. 30 Min. 45 Min. , 2950 I 2930 I I 60 Min. I sCANNED JUN· ~ 1 2007 Tuesday, June J 2, 2007 Page I of J Re: 3H-18 (188-009) . . Subject: Re: 3H-18 (188-009) From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Tue, 12 Jun 2007 16:18:35 -0800 To: NSK Problem Well Supv <nI617@conocophillips.com> CC: James Regg <jimJegg@admin.state.ak.us> Marie, You are correct regarding 3H-18. It appears that planning to perform an MIT every two years was a typo. If an injection well successfully passes the standard MIT and it is not a slurry disposal well, the standard MIT interval is 4 years. Since the repair in 2001, the Commission is not aware of any integrity issue with 3H-18. It is appropriate that the MIT interval be 4 years. I will place a copy of this message in the well file. Call or message with any questions. Tom Maunder, PE AOGCC ~JUN 142007 NSK Problem Well Supv wrote, On 6/12/20072:12 PM: Jim, Yes, I agree that sundry variances on injectors should be changed to AAs. However, 3H-18 does not have a sundry variance, the sundry 301-197 was for a repair to return the well to normal service. I think it was an oversight that Jerry put a 2 yr MIT in item #4 of the proposed repair plan rather than the normal 4 yr cycle for a repaired well when he wrote up the 10-403. I think that AOGCC would have approved the repair sundry regardless if Jerry specified a 2 yr or a 4 yr MIT cycle post tbg patch. In the past, when there has been a typo or oversight on a repair sundry, we've discussed it informally and if all agreed, then red lined both AOGCC's and CPAI's copies with the change. I meant to ask if you all agreed, if we could red line the 2 to a 4 on both copies of our 10-403s. Since wells that are repaired are returned to the normal 4 yr cycle. I have been concerned that if we only invite the inspectors over every 4 yrs to witness 3H-18's MITIA, that anyone reviewing the public well files with a microscope may accuse CPAI of being in violation of the promise made in line 4 for 2 yr MITs, so I have this well flagged in several spots in our well integrity database as an anomaly that needs inspector witness every 2 years. If it isn't a big deal, I'd like to standardize it back to the normal 4 yrs like every other injector that has been successfully repaired with a tbg patch. Please let me know your thoughts, Marie -----Original Message----- From: James Regg [mailto:jim regg@admin.state.ak.us] Sent: Tuesday, June 12, 2007 1:53 PM To: NSK Problem Well Supv Cc: Thomas Maunder Subject: Re: FW: KRU June MITs for 3B, 3F, & 3H Change may be appropriate; you should request an admin approval to replace the outdated sundry. We are trying to replace older sundry approvals with AA's as opportunities arise. 100 6/12/20074:19 PM Re: 3H-18 (188-009) . . Jim Regg AOGCC NSK Problem Well Supv wrote, On 6/11/2007 8:30 PM: Tom & Jim, Looking over 3H-18's test cycle requirements, the sundry approval to patch the tbg leak and return to WAG service (301-197), indicated that CPAI would perform MITIAs every 2 years rather than continue the 4 yr test cycle as is typical for a well that has been repaired to restore integrity. Would it be possible to revise line #4 of the sundry's proposed action plan to perform an MIT every 4 years rather than the 2 years that was committed to in the original proposal to keep test criteria consistent with other injectors repaired with tbg patches? Please advise, Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com *From: * NSK Problem Well Supv *Sent: * Monday, June 11, 2007 8:28 PM *To: * 'Thomas Maunder'; Robert Fleckenstein; 'James Regg' *Subject: * KRU June MITs for 3B, 3F, & 38 Tom, Bob, & Jim, Attached are passing injector MITIA results for 3B pad, 3F pad, and two 38 wells on a 2 yr MIT cycles due to sundry or AA requirements. The tests were completed on 6/8/07 as witnessed by John Crisp. All injector MITIAs due in June 2007 are now complete. «MIT KRU 3B 06-08-07.xls» «MIT KRU 3F 06-08-07.xls» «MIT KRU 38 06-08-07.xls» Please let me know if there are any questions, Marie McConnell Problem Well Supervisor (907) 659-7224 2 of3 6/12/20074:19 PM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille Taylor Chair THRU: Tom Maunder P.I. Supervisor FROM: John H. Spaulding Petroleum Inspector DATE: June 27, 2002 SUBJECT: Mechanical Integrity Tests PAl 3H multiple KRU Kuparuk River Field NON- CONFIDENTIAL Welli 3H-15 '. P:,'r..D.! 1871030 Notes: WellI 3H-17 P.,'r.D.I 1870990 Notes: .... W'eliI 3H-18 P.T.D. I, 1880090 Notes: P.T.D.! 1880110 Notes: 'welli 3H-24 piT.D.I 1960150 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I Type Inj. I G I T'.V.D. I" 5832 I I 3 oo I I I' 'lintervall 4L Type testl _ P I Testps, i l 1458 ICaSingl'22,75 I 2875 1,285° I 2850 J PIE I P J Typelnj. J G J T.~.DI. J 5927 JTubingJ 'J450 J 1440 J 14t~5"J 1465 J lntervalJ 4' Typetest ' Pi ITes{ psiJi 1482,I I CaSing ' 200J, I 2280 I 2270, J' 226'0 i "PIF IP, _ ITypeln}-I' 's I'T'v'D' I 5831 I Tubingl 14001 1400I 1430I 1425 l interVall 4' TyPe testJ.... P' JTestpsi ' 1'4~8J J' .Casingl 1875 J 2320 J I2320 I..... 2320 J PiE J _P J Type~nj.I S !T-v'D- I 5951"! Tubing l 1~001 1490 I 1490 J 1460 I Intervall' 4' I ;I'Ype, testl P., ITest,. psil 1488 ! CasingI,,,1110o''2180 .......... I 2150 I' 2140 I pIF I _ P J Typelnj. JI' S' J T.V.D. ! 5940I'j TubingJ 160o 114~0'i 1425 1141o li;~t&va, J 4 Type test 'J., 'P ,J' Test pSi.. .J 1485 ........... J CasingJ 11001 2275 J '2260 J 22501 PIF I P I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Page 2 of 3 Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) M.I.T.'s performed: _5 Attachments: none Number of Failures: 0 Total Time during tests: 3 hrs. cc: none MIT report form 5/12/00 L.G. mit(2) kru 3h 6-27-02js.xls 7/16/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ Pull tubing _ Alter casing _ Repair well _X Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1055' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM 5. Type of Well: Development __ Exploratory _ Stratig raph ic _ Service__X (asp's 498656, 6000600) 6. Datum elevation (DF or KB feet) RKB 76 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3H-18 At top of productive interval 1374' FSL, 1324' FEL, Sec. 3, T12N, R8E, UM At effective depth At total depth 3825' FNL, 1750' FEL, Sec. 3, T12N, R8E, UM (asp's 491342, 6003114) 9. Permit number / approval number 188-009 / 10. APl number 50-103-20095 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 10293 feet 6197 feet Effective depth: measured 10083 feet true vertical 6086 feet Plugs (measured) Casing Length CONDUCTOR 1 15' SUR. CASING 4092' PROD. CASING 10089' Junk (measured) Size Cemented 16" 21o sxAS I 9-5/8" 1600 sx AS III, 400 sx Class G 7" 645 sx Class G, 175 sx AS I Measured Depth TrueverticalDepth 115' 115' 4168' 2966' 10165' 6129' Perforation depth: measured 9790'-9860', 9878'-9899', 9900'-9920' true vertical 5933'-5969', 5979'-5990', 5990'-6001' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, J-55 Tbg @ 9663' MD. Packers & SSSV (type & measured depth) BAKER 'FHL' @ 9592' MD. CAMCO 'TRDP-1A-SSA' @ 1822' MD. '~nC/~o~'°ns~ Cot, 13. Stimulation or cement squeeze summary Inte~als treated (measured) N/A Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation Injection Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 2500 Casing Pressure Tubing Pressure 2300 2200 Subsequent to operation Shut-in 15. Attachments I I Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~///~~--~-f~~~'~ Title PhillipsProblemWellSupervisor Jerry D~hlefs SI SI SI Suspended __ Service _WAG___ Questions? Call Jerry Dethlefs 659-7224 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE Phillips Alaska, Inc. Kuparuk Well 3H-18 SUNDRY NOTICE 10-404 REPORT OF OPERATIONS 09/02/0 ! This Sundry Notice is to notify the AOGCC that Phillips Alaska, Inc., repaired the tubing on Kupamk well 3H-18 injector with a patch. The repair was approved by Sundry #301-197. On 7/31/01 a 3-1/2" 20-foot Halliburton DWP patch (1.81" ID, retrievable) was set (centered) over a tubing collar leak @ 7005' md. A passing MIT (State witnessed) was performed on the casing to verify the repair integrity (attached). NSK Problem Well Supervisor 09/02/01 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_MaUnder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: Phillips Alaska, Inc. FIELD / UNIT/PAD: Kuparuk / GKA / 3H-18 DATE: 8/1/01 PTD: 1880090 Diesel 5,831 1,458 1,790 1,790 1, 790 1,790 Well #: 3H-18 N P SW 9,592 7"/26#/J-55 3.500 1,500 1,600 2,560 2,540 2,530 1010 COMMENTS: MIT post patch repair tubing set 6994-7014' across collar leak. Retrievable patch. Ce.T~: I I I I ° I I COMMENTS: .em: I I I° I I I COMMENTS: -e".~.:; I I I I I ° I I COMMENTS: .:,T:: I I I I I o i I COMMENTS: TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig - Well File c - Operator c- Database c - Trip Rpt File c- Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 WELL TEST: Initial 0.00 4- Year 0.00 Workover X 0.00 Other 0.00 OPERATOR REP SIGNATURE: Pete Nezaticky , AOGCC REP SIGNATURE: John Crisp MIT KRU 3H-18 08-11-01 .xls (Rev 9/23/99) (1822-1823, OB:3,SqO) l landre~Dummy (6603 6604, OD:5313) TUBING (0-9663, OD:3500, ID:2992) Gas Lift OD:5313) Gas bfi i landrel/Dummy Valve 4 (9537-9538, OD:5 750) PBR (9578-9579, OD:3500) PKR (9592-9593, NO GO (9629-9630, 0D:3500) SOS (9662-9663, 0D:3500) (9790-9860) Ped (9878-9899) Ped (9900,9920) KRU APk!501032009500 I WeiIType: INJ AnGe(~.TS 59de9~9784 ]~-' ~SV Ty~_ TRDP J O8~_Com pier ion [~71 ~ ~'~ An~le .~ ~D: ~g deg ~ 10293 Anoular F~id:I ..... I E~W/O: Re~'~eas~n~ T~g, ~et Patch by Reference Log: ~ Ref Log Date: j Las Upda e 8 5 2001 escr ton Sze To BoSom ~D Wt I Grade I Thread ~ CONDUCTOR 16,000 i 0 115 [ 115 i 62,50 I H-40 ~- 7~8~--'~ ~ 1016~1 61~-' ~ ~ i J-55 Top Bottom I TVD i Wt i Grade -- Th[Bad Interva TVD Zone Status Ft SPF[ Date Type I .(~qmment ~79~;~8~8 ~5970 · C-4 i ~ ~ i 8/6/1988 IPERF 160deg'phasin9'2 l/8"Ene Je ~%~899 5979:5990 ~:~ 21 i 4 16/3/1996 IPERF ....... , ~ Ener Jet 9900-9920 5~1 -6001 A-I 20 i 4 i 5/5/1985 IPERF ~120deg. phasing, 4 1/2" ~ I ~ Pack ~ GaS Eiff MandrelsNalves St MD i~D Man Man VMfr VType ~VOD Latch Pod ~TRO Date IVv i I Mfr I T~e , I i I Run ~ % 313~ 242¢ Camco --~ DMY 10 ] BK-~ ~5 ~ 6~ 996 2 6603 4243] Camco DMY 10._Z.~:~ i ~80 ~ 0 62 996"~ 1822 ~ Camco 'TRDP-IA-SSA' I ZBf2 6990 4449 ~P-~ ~:~Pt~}~bi~(t patch over hole ~-700-5; ~ ~ ~i0~ i 1 795 ~ ~824 · PBR Baker j 4 O00 9592 5831 PKR Baker 'FNL' i 2992 5850 NO GO Camco'D' Nipple ~l~9i~ii~BCA;~ Pl~g ' I 2 750 9662 5867 SOS Brown I 2992 9663 5868 TTL i ~:~ Depth i Description i Comment 9902 i I 1/2" DMY l ~P?/P~et[ D?pB~d !ER¢~hof~ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 2, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Report Of Sundry Operations for Phillips Alaska, Inc., well 3H-I 8. Also attached is an MIT form and a well schematic diagram. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachment MEMORANDUM TO: Julie Heusser Commissioner State of Alaska Alaska 011 and Gas Conservation Commission DATE: August 11, 2001 THRU: Tom Maunder P.I. Supervisor FROM: John Crisp Petroleum Inspector NON' CONFIDENT!AL SUBJECT: Mechanical Integrity Tests Phillips Alaska KRU 3H Pad 3H-18 Kuparuk River Unit Kuparuk River Field I Packer Depth Pretest Initial 15 Min. 30 Min. w,~!31-1-18 IType~nj.I N "i T.V.D. I ~ I Tubi~J'l 1790 I ~7~0 i i790 I' 17g0' I~n~e--a~l 0' I b,-T:D-! ~ .8s°°~' IType.testl. P ' iTestpsil 25oo .Ic=~.~l ~= I 2560 I 2540 I =~ I',~..I -" ~: This well recently had tubincJ patch ins~l!ed. First' .Ml~after rel:~_ ir. . .... . . ... ., . ' we.'I iTYpeInj. i IT.V.D.iITubingI I I , , I Imterva'l · ' P.~:o..IIType~l 'l'~est. ~,1 .' I C,~n~ I I I . I I P~F. I ' wa~ P.T.D.I' Notes: .,. P.T-D.I !~__~_: 'w~., , P.T.D. I Typelni. l' I T-V'D- i ' i Tubing ! ' ' I' . I' '!", ' I'"~,~'!'' Typetestl ,', I'~~'1 , ,I, C,,s~.~ i .. !. I , I , I P/F,I ~ I Typelnj. I I T.V-D.' i I Tubing'l ' I ,', I "I ' ,,' t'nt, ,ewa'l _. T~)et~tl,, J Tes~'psiJ .... i casi.~,l,, , I , ! ' I I, P~: ~ i TYpelnj. I ' '/ T.v.D. i ' i Tubing I' ' I I' '1 ' I*nte-,a*l ' Typetesti' I Testps, I I Ca~ing I , ,i I I I P~: I · Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. 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 This was first MIT performed on this well after a tubing patch had been installed across a leaking collar. M.I.T.'s performed: Attachments: Number of Failures: O_. Total Time during tests: 1 hr. ¢C; MIT report form 5/12/00 L.G. MIT KRU 3H 8-11-01jc.xls 8/13/01 STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-~'nter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _X Vadance _ Perforate _X Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 79 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510,0360 service__ Kuparuk Unit 4. Location of well at surface 8. Well number 4792' FNL, 5134' FEL, Sec. 17, T12N, R10E, UM (asp's 539830, 5991690) 1 R-22A At top of productive interval 9. Permit number / approval number 2018' FSL, 86' FEL, Sec. 17, T12N, R10E, UM (asp's 544862, 5993252) 199-049 ..... At effective depth 10. APl number 50-029-22206-01 At total depth 11. Field / Pool 969' FNL, 4861' FEL, Sec. 16, T12N, R10E, UM (asp's 545347, 5995546) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 11591 feet Plugs (measured) true vertical 6753 feet Effective depth: measured 9432 feet Junk (measured) true vertical 6639 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 117' 16" 331 sx AS ~ 117' 117' SURFACE 5909' 9-5/8" 119o sx E, 550 sx G 5988' 4171' PRODUCTION 6418' 7" 300 sx Class G 6497' 4490' PRODUCTION 5248' 3-1/2" 1000 sx Class G 11594' 6753' PRODUCTION Perforation depth: measured 9210'-9224', 10320'-10350' true vertical 6539'-6548', 6717'-6715' RECEIVED Tubing (size, grade, and measured depth 3-1/2", 9.3#, L-80 Tbg ~ 6397' MD. JUL 1 ;5 2001 Packers & SSSV (type & measured depth) BAKER ZXP LT @ 6346' MD. Alaska 0il & GaS CONS. Commission ................. ~CAMCQ DS @ 516' MD ..... Anchorage 13. Attachments Description summary of proposal __X Detailed operations program 14. Estimated date for commencing operation 15. Status of well classification as: July 18, 2001 16. If proposal was verbally approved Oil __X Gas Name of approver Date approved Service 17. I hereby certify that the toregoing is true and correct to the best of my knowledge. Questions? Call Todd Mushovlc 265-6974 Tom Brockwa)/ Prepared b~/ Sharon A//sup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness J Approval n~...~,~)/ /~' Plug integrity _ BOP Test _ Location clearance _ . Mechanical Integrity Test_ Subsequent form required lO- Approved by order of the Commission Commissioner Date R[JRMIT IN TRIPLICATE PHILLIP$ a, inc. ~ A subsidiary of PHILLIPS PETROLEUM CONIPANY NIP (516517, -- 0D;4,562) GasL~[ Man0relNalve 0D;5,390) A~l~i 5oo2~2~2oo01 Gas L~ ~andrettDummy VaNe 3 (6263-6264. OD:B390) 1R"22A SSSV T' Annular Fluid: SW/DSL An le TS; de ' - 1/1412000 An~Ie ID: 84de ~-11591 1512000 Re Las~t Update: 7110/2001 TD: 11594 ffKB 10337 CONDUCTOR SURFACE Thread PRODUCTION PRODUCTION L-80 I SLHT Thread 3.500 EUE 8md*mod Interval TVD Comment -_~%90 ~.4 6539~6~ 6548 ! §20-10350 6717- 6715 ] Interval I Date I-- Type } -Comment VMfr I v'~ Cmnt Gas UIt (8313-6314, OD:6.018) PKR {6346-6347, OO:6.000) NIF (6359-6380. 00:4.520) HANGER SEAL P6R (9199-9200, OD:4.562) (9210-9224) NiP {9282-9283, 0D:4.652} FRAC ' (10320-10350) Ped 00320`10350) LANDING L-- OD:4.000} Camco DS Description [ ID 4,375 GBH-22 ] 3.000 ~aker 80-40 4.000 6372 i ~7 1MULESH(~E~,; baker 3.000 2.750 9~9 i 6533 NiP i caTn~ XN 2~75~ 11528 6746 ~NDING Baker 3,000 Date ~F~72]~000 JDd~ tubing wi6' X 2 1/8 drif~oass down to 9483' WLM. Note: Tiph spots ~,, 6199 t i~h 6274' WLM. 8/7~/_2000 J CQRKSCREWED TBG SECTION ¢,6200'~350' 1R-22A GENERAL WORKOVER PROCEDURE STATUS: Originally drilled and completed during January 2000. A 3-1/2" liner was run and cemented across the horizontal section through the Kuparuk A&C Sands and 3-1/2" tubing run back to surface. The tubing is now cork-screwed preventing wellwork in the liner. WorkoVer will use Nordic 3 to pull 3-1/2" cork-screwed tubing, drill pipe convey =1600' perf guns to shoot selective intervals of the A&C sands, and rerun 3-1/2" gaslift completion. PRE-RIG WORK: . 2. 3. 4. 5. Pull top GLV, replace with dummy valve. Pressure test 3-1/2" x 7". Pull bottom GLV. Set BPV in tubing and install VR plug in annulus valve. Remove floTM riser and gas lift riser, well house and scaffolding as required. GENERAL WORKOVER PROCEDURE: 1. MIRU Nordic Rig 3. Lay hard-line to tree. Pull BPV and VR plug. 2. Load pits with 9.5 ppg NaCl brine and displace seawater & diesel from well. Ensure well is dead. 3. ND tree. NU and test BOPE. 4. POOH 6400' of 3-1/2" tubing standing back tubing that is re-useable, lay down jewelry. 5. PU 2".hollow carrier perf guns and blank spacer. RIH on 2-1/16" CS Hydrill and 3-1/2" drill pipe off racks. 6. Place guns on depth and perforate 3-1/2" liner. Circulate brine to kill well. 7. POOH laying down drill pipe and perf guns. 8. Run 3-1/2" tubing and gas lift mandrels. 9. Stab seals into tieback sleeve, space out, land tubing hanger. 10. Pressure test tubing and annulus. 11. ND BOPE. NU and test tree. Displace well with seawater. Freeze protect well with diesel. Lower Limit: 4 days No problems running perf guns or killing well. Expected Case: 7 days Upper Limit: 10 days Difficulties running perf guns or killing well. TJM 7/13/01 MEMORANDUM TO: Julie Heusser ~ _~,~t~ DATE: July 7, 2001 Commissioner ^~.1/' ~_ SUBJECT: Mechanical Integrity Tests THRU: Tom Maunderj<:::r~ -~,~~/~r~TCj~ BPX P.I. Supervisor \ PM1 Pad ~..)\,,~\ ' P1-01 FROM: Jeff Jones PBU Petroleum Inspector Point Mcintyre Field NON- CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission Packer Depth Pretest Initial 15 Min. 30 Min.. ' . W~,! P~-O~ I Ty. pe Inj.! "N ' I T.V.'D. i '8387 '1 Tubing I 2720 I 2920 '1 "29-~.o I. ~ J',ntervad 1. I P.T.'D.I 'm00270 IT~.Pet~tl ' P ',lTest,psil 2O97I ca,,n0'l = '1,,2990 1.299° ! 299°. I P/F I E Notes: YeadY CMIT per AOGCC sunder #398-188 ' . !', "1 " i, .'1 I I'."'1 '. I ..... I' ,'1 ", '1 , I'",I _ Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. 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'$ Details Saturday, Jul_v ~ 200.1.: I traveled to BPX's Point McIntyre Field PM-1 Pad and witnessed a 1-year CMIT on well P1- O1 as required by Sundry approval #398-188. This well was not injecting and has a gas lift mandrel leak causing the known communication between the tubing and the inner annulus. The pretest tubing and casing pressures were observed and found to be stable. The combined tubing / inner annulus pressure test was then performed with the well passing the CMIT. .Summa.ry...- i witnessed a successful CMIT on BPX's well P1-01 in the Point McIntyre Field / PBU. M.I.T.'s performed: 1_ Attachments: Number of Failures: _.0 Total Time dudng tests: I hr. c,q.: MIT report form 5/12/00 L.G. MIT PM 1-01 PBU 7-7-01 JJ.xls 7116/01 PHILLIPS Alaska, Inc. ^ Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 9, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED JUL 7 7 2001 0il & Gas Cor~s. ComffJissjor /~chorage Dear Mr. Maunder: Enclosed please find a 10-403 Application for Sundry Approval for Phillips Alaska, Inc., well 3H-18. Also attached is a discussion to support the request and a well schematic diagram. Please call Pete NezatickY or me at 907-659-7224 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachment STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 76 feet 3. Address Exploratory _ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 1055' FNL, 4997' FEL, Sec. 12, T12N, R8E, UM (asp'$ 498656, 6000600) 3H-18 At top of productive interval 9. Permit number / approval number :::;:::::::;:::; :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :: ::::::::::.:.:::.: .: :::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::: :..:::::.;.:<:::::: .::::. ===================== :::::::: :::::: :::::::; :: :::::::::::: :; u:u::: u:u: :: ::u:u:u:L :: u:u: u:L :: L :: :: :: :: us: L :: u: L ::u: LL L :: ::L :U: :: At effective depth 10. APl number 50-103-20095 :!:!:!:!:!:!:i:!:i:::i:::i:!:i:::i:i:i:i:!:::i:!:i:::!:!:!:~:!:!:!:!:~:!:~:~:!:i:i:!~!:!:!:!:!:!:!:!:!:?!:!:!:!:!:!:!:!:!:!:!:!:i:::!:!:!:!:i:!:i:!:i:}:!:!:i:::!:!:!:::i:i:i:!:i:i:i:::i:i:i:i:i:::i:i:i:!:!:i:i:i:!:::i:~:i:::!:!:!:::i:~:i:::!:~:!:?i:i:i:i:i:i:i:i:!:i:i:i:i:i:i:i:i:i:i:i:i:i:i:!:i:!:!:!:!:i:!:iSi:!:!:i:!:!:i:!Si:!:i:!:i:iiS!:i:i:i:i:!:!S At total depth 11. Field / Pool 3825' FNL, 1750' FEL, Sec. 3, T12N, R8E, UM (asp'$ 491342, 6003114) Kuparuk Oil Pool 12. Present well condition summar Total depth: measured 10293 feet Plugs (measured) true vertical 6197 feet :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :'::::::::: ::: :::::::::::::: :::: :::: ::::::::::::.:-::: ::::.:.:::::-:.: ::::::::::::::::::::::::::::::::::::::::::: ::::: ::::: ::: -:: true vertical!ii:~!iii!;iii;;:?:i::i::iii::i;ii:~;::iii::i::!::i?:i;::i~8~!~: feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 1 1 5' 1 6" : 5' 1 1 1 1 5' ......... 29661. i. !.i. i~i.i.i..i!i ::i:~i~ !~ iii~i SUR. CASING 4092' 9-5/8" ?.'-i;6i3i31~ii~iiii;:~(~(~!i~;x;~ib~:~i:: ::;::; 4168' :::::::::::::::::::::::::::::::::: ' ' ' ........................ '"'" ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :.: ·:.: ·: .:. ::: ·: ::: ·: .:,: · ;:: .:::. ::,:::::: :: :::.:::::.:: :::: :. ::: - :::; PROD. CASING 10089' 7" 10165' :' .... : ..... '::'::: :':':':":"':':'"':':':':':::':':':':':':' ........ " ~:6~1~29~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:~:;~:~:~:~:~:.~:~:~::~::~:~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: !! i:!:!:i:! !:l ! i:!:i:!: i i ! :. :. :. :. :. :. :.: :... :. :. :. :. :. :. :.::: :. :. :, :. :.: :. :. :. :. :.:. :. :.: ::. Perforation depth: C E IV E D :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::5::::::::::::::::::::::::::::::::::: ::: :::: ::: :::::: :::]: :::::::::::: ::::: :::::: :::::::: :::: ::::': ': ': :::: :::: ': ' 8as Cons. 6ommission Tubing (size, grade, and measured depth 3-1/2", 9.3#, J-55 Tbg @ 9663' MD. Anchorage Packers & SSSV (type & measured depth) BAKER 'FHL' @ 9592' MD. CAMCO 'TRDP-1A-SSA' @ 1822' MD. !~i~ii~iii~}~iii~:~~t~i~i~i~i~i~i~.i~i~D~t~h~i~~i~i~~::~ii i i:: il i D~it~i!~e~tl~.i~gr~i~: ::.... ~.~.~ ~ ~ ..~.:. ~ ~.~BOP.~ketCh~.~.~: ~.~.~.~ ~ ~.~.~ ~ ~ ~:~.:~.~.~... 14. Estimated date for commencing operation 15. Status of well classification as: -.-... , .... ...-.. .......... ... ?~ oi~ Gas ~ Suspended ~ 17. I hereby cedi~ that the foregoing is true and~rect to the best of my ~owledge. Questions? Call Jerw Dethlefs 659-7224 Signed ~ '~~- - ~ Title: Problem WelISupe~isor Date Je~ Pethlefs ( j Prepared by Sharon AIIsu~Orake 263-4612 F~OR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may witneSSp,ug integd~ __--BOP Te. _ Location clearance _ Il,/Oq Mechanical Integr~ Test ~ Subsequent lo~ required 10- Approved byorder of the Commission D Tayl~~l ~ I ~ , Commissioner Form 10-403 Rev 06/15/88 · Return to: Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3H-18 SUNDRY NOTICE 10-403 REPAIR REQUEST 07/09/01 The purpose of this Sundry Notice is to notify the AOGCC of Phillips Alaska, Inc., intent to repair the tubing on Kuparuk well 3H-18 injector. The AOGCC was notified of a failed MIT on 1/3/01. Diagnostics showed the failed MIT was due to a leak in the tubing, but the leak rate was too small for traditional logging tools (0.36 gpm with 500 psi DP T x IA). A video log was performed on 7/8/01, which showed the leak in a tubing collar connection at 7010' md. No other leaks were found and the tubing appears to be in good condition. A 3-1/2" patch (1.81" ID, retrievable) will be set (centered) over the tubing collar leak @ 7010' md. An MIT will be performed on the casing to verify the repair integrity. Near-term plans for this well include conversion from water to gas injection (WAG service). PROPOSED ACTION PLAN Phillips proposes to use the following action plan for operation of this injector: 1. The well may be used for either gas or water injection (WAG); 2. Tubing / casing integrity must be maintained by installation and maintenance of a patch or other repair over the known tubing leak @ 7010'md to meet AOGCC MIT criteria; 3. Successfully MIT the casing / tubing after installation of the patch and after any future replacement or maintenance of the patch; Perform an MIT every 2-years subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); Notify the AOGCC should MIT's or injection rates and pressures indicate further problems. 4, 5, NSK Problem Well Supervisor 06/23/01 ARCO Alaska, Inc. (1622-1823, OD:3 600) PBR (9578~9579, OD:3500) PKR (9592-9593, OD:6151) NO GC (9629-9630, 06:3500) TUBING (0-9863, 00:3500, ID:2992) Perf (9790-9860) (9878-9899) GKA 3H-18 APJ: 501032009500 Well Type: SSSV Type: Camco O6g Completion: 12/88 AnnutarFluid: Las[W/O: Ref Log Date: Last Ta 10293 8KB Last Tag Date: 10/29/99 Max Hole Angle: 61 deg @ 3600 Angle ~ TS: An~l~ ~ ZD; 58 d~g ~ ! 0293 LastUpdate: 11/4/99 Size Top Bottom TVD Thread 16,000 0 1t5 115 Size Bottom J TVD Thread 9625 0 4168 2966 Size Bottom J TVD Thread 7000 0 10166 6130 Size Bottom TVD Thread 3500 0 9663 5868 BTC AB MOD Interval TVD Comment 9790 - 9860 5933 - 5970 60 deg phasing, 2 1/8" EnerJet 9878 - 9899 5979 - 5990 2 1/8" Ener Jet 5991 * 600t I, phasing, 4 1/2" Ultra Pack Description Camco 'TRDP-1A-SSA' Baker Baker 'FHL' Camco 'D' NipCe 11/2/99 Pulled CA-2 Plug Description Comment Empty Pocket; Dropped n Ralhoie MICROFILMED 10/12/00 DO NOT PLACE' ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate Plugging ~ Perforate X Pull tubing ~ Alter casing ~ Repair well ~ Other 2. Name of Operator 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 1057' FNL, 282' FWL, Sec. 12, T12N, RSE, UM At top of productive interval 1374' FNL, 1324' FEL, Sec. 3, T12N, RSE, UM At effective depth 1424' FNL, 1563' FEL, Sec. 3, T12N, RSE, UM At total depth 1456' FNL, 1751' FEL, Sec. 3, T12N, RSE, UM 12. Present well condition summary Total Depth: measured true vertical 1 0293 feet 61 96 feet 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-18 9. Permit number 88-09 10. APl number 50-103-20095 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None feet Effective depth: measured 1 0083 feet true vertical 6086 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth Length Size 115' 16" 4168' 9-5/8" 10165' 7" measured 9790'-9860', true vertical 5933'-5969', Cemented 200 Sx AS I 1600 Sx AS III & 400 Sx Class G 645 Sx Class G 9900'-9920' 5990'-6001' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9663' Packers and SSSV (type and measured depth) Pkr: Baker FH @ 9592', SSSV: Camco TRDP-1A-SSA @ 1822' Measured depth 115' 4168' 10165' True vertical depth 115' 2967' 6130' 13. Stimulation or cement squeeze summary See Attached summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Subsequent to operation Representative Daily Avera.qe Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 250 155 110 100 0 0 4700 1 0 0 Tubing Pressure 140 1600 15. Attachments Wellbore schematic Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil Gas Suspended Service H2.O Injector 17. I he?y-lertify that the foregoing is true and correct to the best of my knowledge. , Signed ~,/~,-~ Title Wells Superintendent Form/'~04i R~ ~)~715~8 '~ SUBMIT IN DUPLICAT~E ARCO Alaska, Inc. KUPARUK RIVER UNIT A WELL SERVICE REPORT Kl(3H-18(W4-6)) WEII. JOB SCOPE JOB NUMBER 3H- 18 MISC RESERVOIR MANAGEMENT 0520960801.2 DATE DAILY WORK UNIT NUMBER 06/03/96 PERF 'A' SAND DAY OPERATION COMPLETE [ SUCCESSFUL KEY PERSON SUPERVISOR 1 YES] YES SWS-SCHWARTZ PAIGE FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE 998497 230DS36HL $7,702.00 $15,808.00 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 1600 PSI ~ 1600 PSI 100 PSI 100 PSI[ 700 PSII 700 PSI DAILY SUMMARY IPERFORATED 'A' SAND INTERVAL USING 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH SHOOTING THE LOWSIDE F/9877.5'-9899.5' ELM (REF DIL DATED 3/7/88) TIME LOG ENTRY 13:30 MIRU SWS. HELD SAFETY MTG. 14:45 PT LUB TO 3000#; TEST OK. RIH W/GUN - WGT BAR, MPD, CCL. 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH, ORIENTED 0 DEG F/LOWSIDE TO SHOOT 9878'-9900' ( REF DIL DATED 3/7/88) 15:45 TIED INTO DIL; TAGGED TD @ 9900' ELM. THERE IS NO RATHOLE TO SHOOT FROM. WILL BE SHOOTING OFF BOTTOM, THEREFORE PERF INTERVAL WILL BE 9877.5'-9899.5'. t 6:15 FIRED GUN: POH. 17:00 AT SURF W/GUN; ALL SHOTS FIRED. 18:00 RDMO. SERVICE COMPANY - SERVICE HALLIBURTON SCHLU3/IBERGER TOTAL FIELD ESTIMATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown~ Stimulate Plugging Pull tubing Alter casing Repair well Perforate Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development m Exploratory Stratigraphic Service X 4. Location of well at surface 1057' FNL, 282' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1374' FNL, 1324' FEL, Sec. 3, T12N, RSE, UM At effective depth 1424' FNL, 1563' FEL, Sec. 3, T12N, R8E, UM At total depth 1456' FNL, 1751' FEL, Sec. 3, T12N, R8E, UM 12. Present well condition summary Total Depth: measured true vertical 1 0293 feet 61 9 6 feet 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit 8. Well number 3H-18 9. Permit number/Approval number 88-09/96-1 1 1 10. APl number 50-103-20095 11. Field/Pool Kuparuk River Oil Field/Pool Plugs (measured) None feet Effective depth: measured 1 0 0 8 3 feet true vertical 6086 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth Length Size 115' 16" 4168' 9-5/8" 10165' 7" Measued 9790'-9860', true vertical 5933'-5969', Cemented 200 Sx AS I 1600 Sx AS III & 400 Sx Class G 645 Sx Class G 9900'-9920' 5990'-6001' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9663' Packers and SSSV (type and measured depth) Pkr: Baker FH @ 9592', SSSV: Camco TRDP-1A-SSA @ 1822' Measured depth 115' 4168' 10165' True vertical depth 115' 2967' 6130' 13. Stimulation or cement squeeze summary Converted oil producer to water injector.. (a:~' Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 250 155 1 1 0 1400 1 40 Subsequent to operation 0 0 4700 1 8 0 0 2688 15. Attachments Wellbore schematic Copies of Logs and Surveys run __ Daily Report of Well Operations 16. Status of well classification as: Oil Gas Suspended Service H20 Injector 17. I h~rtify that the foregoing is true and correct to the best of my knowledge. ~./~~,-,...//"' / / ~,.,~~~.,~ Title Wells Superintendent Form 1/e~"~'0z¢ [::l/e~' 0~7~5¢8~8'"" / Date /'~-- SUBMIT IN DUPLICATE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon_ Suspend _ Operation Shutdown_ Re-enter suspended well _ Alter casing _ Repair well Plugging _ Time extension Stimulate Change approved program _ Pull tubing _ Variance _ Perforate _ Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1057' FNL, 282' FWL, Sec. 12, T12N, R8E, UM At top of productive interval 1374' FNL, 1324' FEL, Sec. 3, T12N, R8E, UM At effective depth 1424' FNL, 1563' FEL, Sec. 3, T12N, R8E, UM At total depth 1456' FNL, 1751' FEL, Sec. 3, T12N, RSE, UM 5. Type of Well: Development Exploratory _ Stratigraphic _. Service ORIGINAL 12. Present well condition summary Total Depth: measured true vertical 10293 6196 6. Datum elevation (DF or KB) RKB 76 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3H-18 9. Permit number 88-09 10. APl number 50-1 03-20095 11. Field/Pool Kuparuk River Oil Field/Pool feet Plugs (measured) None feet Effective depth' measured 1 0 0 8 3 feet true vertical 6086 feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 115' 16" 4168' 9-5/8" 10165' 7" measured 9790'-9860' true vertical 5933'-5969' Cemented 200 Sx AS I 1600 Sx AS III & 400 Sx Class G 645 Sx Class G 9900'-9920' 5990'-6001' Tubing (size, grade, and measured depth) 3.5", 9.3#, J-55 @ 9663' Packers and SSSV (type and measured depth) Pkr: Baker FH @ 9592', SSSV: Camco TRDP-1A-SSA @ 1822' Measured depth 115' 4168' True vertical depth 115' 10165' ' RECEIVED MAY t 1 1996 Alaska 011 & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ CONVERT WELL FROM OIL PRODUCER TO WATER INJECTOR Detailed operation program _ Name of approver Date approved 14. Estimated date for commencing operation 115. Status of well classification as: May 29,1996 I Oil __ Gas _ 16. If proposal was verbally approved BOP sketch To be reclassified as: Service WATER INJECTOR Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ -'~'~ .r/~,./vI,E.,¢C/r.., Title Wells Superintendent ~/ ~/' / FOR COMMISSION USE ONLY Date Conditions of approval: Plug integrity __ BOP Test Mechanical Integrity Test _~ Approved by order of the Commission Form 10-403 Rev 06/15/00 Notify Commission so representative may witness IApprov.ql, No. Location clearance I ~Q"' ..../// -- Subsequent form r'--~quire 10-~0/~' Approved Copy Returne~ ,.~ri~jlnal Signed By ,¥/~zLt/~ ~ David W. Johnston CommissiJnei 'Da~e/ - :~/"Z'~/~[ (,~ SUBMIT IN TRIPLICATE Attachment I ,, Conversion to Water Injection Kuparuk Well 3H-18 ARCO Alaska requests approval to convert Well 3H-18 from an oil producer to a water injector. This well will be operated as a Class Il UIC well in compliance with Area Iniection Order No. 2. Water will be injected for the purpose of enhanced recovery into the Kuparuk interval between the depths of 5933' and 6001'. This interval correlates with the strata found in AP, CO's West Sak River State Well No. 1 between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Intecjrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, avera§e injection pressure, and average annulus pressure will be reported to the AOGCC monthly. Dale: ARCO Alaska, Inc. August 11, 1989 Transmittal #: 7536 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3 O- 1 7 Kuparuk Well Pressue Report 1 - 2 3 - 8 9 Sand 'A' 3 O- 1 2 Sub-Surface Pressure .Survey 1 - 1 2 - 8 9 # 71 6 0 5 3 H- 1 1 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H - 1 6 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H- 1 8 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing 3 H - 1 3 Kuparuk Fluid Level Report 8 - 0 7 - 8 9 Casing Receipt Acknowledged: DISTRIBUTION: BP Chevron Unocal Mobil State of Alaska D&M CC: DS Engr. NSK Files~ -- DP Engrg.?_~s .... P-r~man KUPARUK FLUID LEVEL REPORT Well ~ Fl-I '~' Date ~'-7- sssv GLM DV or GLV Fluid Level Found @ , Ft Fluid Level >Shot Down: t// Casing Tubing CSG Press During Shot =...-7/'/0_ # TBG Press During Shot--~# Reason For Shooting FL: ~_/ To Determine Operating Valve Well Status: Comments: On Continuous GL Operating CSG Press-- 7~O # GL Rate (If Available)= MCFD On Intermittent GL On Time =____ Min. OFF Time= Hr.. Min. Delta Time From End Of On Cycle =~ Min. No GL ARCO Alaska, Inc. Date: July 28, 1989 Transmittal Ct: 7523 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 2 T- 0 9 Post Frac Job Report 1 0 - 1 1 - 8 9 "4 0 9 7 4 7 3 B - 0 4 .... Kuparuk F!uid Level RePOrt . 7.- 2 1 - 8 9 , '.;asing 3J,0'2' Kuparuk ;--':~id Level'RepOrt " 7~'1 9-89' Casing 3 H - 1 8 Kuparuk Fluid Level Report 7 - 2 5 - 8 9 Casing 3 H - 1 I Kuparuk Fluid Level Report 7- 2 4 - 8 9 Casing ReceiPt Acknowledged: Cons. DISTRIBUTION' BP Chevron Unocal Mobil State of Alaska D&M sssv z, GLM DV or GLV KUPARUK FLUID LEVEL REPORT CC: DS Engr. NSK Files OP Engrg. Files Prod. Foreman - Well ;~- I~1~ Date Fluid Level Shot Down: ,,./Casing Tubing CSG Press During Shot =_~__# TBG Press During Shot = ReasOn'For Shooting FL:' .. ~ .To Determine Operating Valve Well Status: .: ~ Level Found @ Et On Continuous GL Operating CSG Press = '753-8~ # GL Rate (If Available)= -7~ MCFD On Intermittent GL On Time = ~ Min. Off Time = Hr. Min. Delta Time From End Of On Cycle No GL Comments: Min. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Revised to reflect added perforations and Arctic pack Classification of Service Well OIL ~ GAS ~ SUSPENDED ~ ABANDONED ~ SERVICE [] 2. Name of Operator 7. Permit Number ARCO A]aska, Inc. 88-09 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 103-20095 9. Unit or Lease Name Kuparuk River Unit 4. Location of well at surface 1057' FNL, 282' F'WL, 5ec.12, T12N, RBE, UN At Top Producing Interval 1374' FSL, 1324' FEL, Sec. 3, T12N, RBE, UN At Total Depth 1/+56' FSL, 1751' FEL, 5ec.3, T12N, RBE, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 76' RKB I ADL 25532 ALK 2658 10. Well Number 3H-18 11.FieldandPool Kuparuk River Field Kuparuk River 0il Pool 12. Date Spudded 02/29/88 17. Total Depth (MD+TVD) 10293 'ND/6196 'TVD 13. Date T.D. Reached 03/06/88 18. Plug Back Depth (MD+TVD) 10083'HD/6086'TVD 14. Date Comp., Susp. or Aband. J 15. Water Depth, if offshore J 16. No. of Completions 06/27/88* I N/A feet MSL[ 1 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost YES ~ NO [] 1822 feet MD I 1600' (approx} _ 22. Type Electric or Other Logs Run DIL/LSS/GR; DIL/GR/SP/SFL: FDC/CNL: Cal; CET; GCT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 210 :x AS ! 16" 9-5/8" 6_? _5# _56.0# H-40 J-55 Surf Surf !!5' 7" 26_0~ J-55 S,-rf ! 0165 ' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) Perforated w/12 spf, 60° phasing 9790 '-9860 'MD/5933 ' -5969 'TVD Perforated w/4 spf, 90° phasing 9900 ' -9920 'MD/5990 '-6001 'TVD 27. 8-!/2" v ~'1 Lee ~ xAS ~ 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" 9663' 9698' 9850' 9592' ~asJa ~i! ~ ~as C0n~ ~.0mmiss~:~: l "~'~:~'"~~T I' O N TEST -- Date First Production N/A Date of Test Hours Tested Flow Tubing Casing Pressure Press. Method of Operation (Flowing, gas lift, etc.) PROI~UCTION FOR TEST PERIOD J~ OIL-BBL GAS-MCF CALCULATED OIL-BBL GAS-MCF 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. iWATER-BBL WATE R-B B L ICHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (corr) None * NOTE: Drilled RR 03/12/88. Perforated well and ran tubing 5/7/88. Added perforations 8/6/88. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Fractured well 6/27/88. WCS/01 ? Submit in duplicate 29. GEOLOGIC MARKERS. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A MEAS. DEPTH 9783' 9862' 9862' 9965' 31. LIST OF ATTACHMENTS Addendum (dated 10/27/88) 30. FORMATION TESTS TRUE VERT. DEPTH 5929' 5970' 5970' 6024' Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 32. I hereby certify that the foregoing is true and correct to the best of my knowledge _ Title Area Drilling EngineerDate 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 eievation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6/27/88 8/06/88 3H-18 Attempt to frac Kuparuk "A" sand perfs 9900'-9920' in nine stages per procedure dated 6/22/88 as follows: Stage 1: 20 bbls 145° diesel @ 3 BPM, 3380 - 3500 psi Stage 2: 170 bbls gelled diesel @ 3 to 20 BPM, 3500 - 6440 - 5100 psi Stage 3: 9.5 bbls gelled diesel 1 ppg 16/20 Carb @ 20 BPM, 4800 - 4580 psi Stage 4: 18.5 bbls gelled diesel 2 ppg 16/20 Carb @ 20 BPM, 4580 - 4675 psi Stage 5: 17 bbls gelled diesel 4 ppg 16/20 Carb @ 20 BPM, 4675 - 4980 psi Stage 6: 16 bbls 6 ppg 16/20 Carb @ 20 BPM, 4940-4980 psi Stage 7: 15 bbls gelled diesel 8 ppg 16/20 Carb @ 20 BPM, 4980 - 5220 psi Stage 8: 10.5 bbls gelled diesel 10 ppg 16/20 Carb @ 20 BPM, 5220 - 5185 psi Stage 9: 22 bbls gelled diesel Flush @ 20 - 18 BPM, 5185 - 7600 psi Screened out @ 7600 psi w/22 bbls flush away. Fluid to Recover: 298.5 bbls diesel Sand in Zone: 2750# 16/20 Carbolite Sand in Csg: 15,382# Avg Pressure: 4800 psi RIH w/hot oil unit. Pressure tst Ins to 3000 psi. Displ tbg w/90 bbls cln diesel @ 1.5 BPM, 2100 psi. RU Schl, RIH, perf 9840'-9860' 9840'-9860' 9815'-9840' i ' , 9815'-9840' 9790'-98 5' & 9790'-9815' Superv~r ARCO Alaska, Inc. Date: November 28, 1988 RETURN TO: Transmittal #: 7362 ARCO Alaska, Inc. Attn. Brenda K. Miernyk 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. 3H-03 3H-18 3A-01 3A-01 30-O2 3H-22 3H-12 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report .Kuparuk Fluid Level Report 1 1 - 1 1.8 8 Casing 1 1 - 1 1 - 8 8 Casing 1 1 - 2 3 - 8 8 Casing 1 1 - 1 8 - 8 8 Casing 1 1 - 1 9 - 8 8 Casing 1 1 - 1 7- 8 8 Tubing 1 1 - 1 7 - 8 8 Tubing Receipt Acknowledged. DISTRIBUTION; D&M Mobil SAPC State of Alaska Chevron Unocal ARCO Alaska, Inc. Date: November 4, 1988 Transmittal #: 7342 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmi[ted herewith are the following items. one signed copy of this transmittal. 3H-18 Resevoir Fluid Study Please acknowledge receipt and return 1 0-28-88 #880462 Receipt Acknowledged: DISTRIBUTION; Drilling State of Alaska Franzen Chevron D&M Unocal Mobil Resevoir SAPC ARCO Alaska, Inc. Date: November 4, 1988. Transmittal #: 7343 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 1 Q- 0 5 Kuparuk Fluid Level Report 1 0 - 2 5 - 8 8 1 Y- 1 6 Kuparuk Fluid Level Report 1 0- 2 5 - 8 8 3 K - 0 6 Kuparuk Fluid Level Report 1 0 - 2 5 - 8 8 31 - 0 2 Kuparuk Fluid Level Report 1 0 - 2 2 - 8 8 2 H - 0 8 Kuparuk Fluid Level Report I 0 - 3 0 - 8 8 2 D- 0 6 Kuparuk Fluid Level Report 1 0 - 3 0 - 8 8 3 H - 1 8 Kuparuk Fluid Level Report 1 0- 3 0 - 8 8 3 M - 1 3 Kuparuk Fluid Level Report 1 0 - 3 0 - 8 8 Casing Casing Casing Tubing Casing Casing Casing Casing Receipt Acknowledge '~~~- ate- DISTRIBUTION: D&M ~State of Alaska Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Date: October 21, 1988 Transmittal #: 7330 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3H-1 4 Sub-Surface Pressure Survey 9-1 4-88 #AKU3H14 3H-15 Sub-Surface Pressure Survey 9-1 7-88 #01KU3H15 3H-16 Sub-Surface Pressure Survey 9-21-88 #01KU3H16 3H-18 Sub-Surface Pressure Survey 9-27- 88 #01KU3H18 3 N - 1 7 Kuparuk Fluid Level Report 1 0 - 1 3 - 8 8 Casing Receipt Acknowledged: DISTRIBUTION: D&M State of Alaska Unocal Mobil SAPC Chevron ARCO Alaska, Inc. Date: September 21, 1988 Transmittal #: 7291 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 2 D- 1 2 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 PBU 3 H- 1 8 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 Flowing Gradient r.J~r~'~ 011 & Gas Cons. Commls,:i:,~ Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION: D&M State of Alaska Unocal(+vendor package Mobil(+vendor package) Unocal(+vendor package) SAPC(+vendor package) ARCO Alaska, Inc. Date: August 26, 1988 Transmittal #: 7280 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk 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. 3 H - 2 2 Kuparuk Well Pressure Report 6 - 2 9 - 8 8 Amerada 3 H- 2 2 Kuparuk Well Pressure Report 8 - 1 0 - 8 8 Sand 'A' 3 H - 1 8 Bottom-Hole Pressure Survey 8 - 2 2 - 8 8 PBU 3 K - 1 7 Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 4- Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing 3 B - 1 3. Kuparuk Fluid Level Report 8 - 1 9 - 8 8 Casing Receipt Acknowledged: DISTRIBOTION: D&M State of Alaska Chevron Mobil Unocal SAPC 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 [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] , , , 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 88-09 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 103-20095 4. Location of well at surface 9. Unit or Lease Name 1057' FNL, 282' FWL, Sec.12, T12N, R8E, UM Kuparuk River Unit . . At Top Producing Interval 10. Well Number 1374' FSL, 1324' FEL, Sec. 3, T12N, R8E, UM 3H-18 At Total Depth 11. Field and Pool 14.56' ...... FSL, 1751' FEL, Sec.3, T12N, RSE, UM Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 7.6'.. RKBI ADL 25532 ALK 2658 1'2. Date spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water DePth, if offshore 16. No. of Completions 02/29/88 03/06/88 06/27/88*I N/A feet MSL 1 , 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. D~ectional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10293'MD/G196'TVD 10083'MD/G086'TVD YES~'~_l NO []I 1822 feet MD 1600' (approx) 22. Type Electric or Other Logs Run . DIL/LSS/GR, DIL/GR/SP/SFL, FDC/CNL, Cal, CET, GCT 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 11_5' . 24" ?lr~ ~× AR I .. 9-5/8" :36.0# J-55 Surf 4168' 12-1/4" 1F;O0 sx AR Ill & /~0~ ~× CI~ C Top job w/121~ .~× A~ I _ .7" 26.0# J-.55 Surf 10165' 8-1/2,, 64.5 sx (;]ass G .... , 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) 3-1/2" 9663' qF, qR ' q~n, q~9, , , Perforated w/4 spf, 90° phasing '26. ACID, FRACTURE, CEMENTSOUEEZE, ETC. 9900'-9920'MD/5990'-6001'TVD . DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL usED See attaeh~.d Add~.n, I,,m ~ dated R/79/88~ for Fracture det~ · · , ,,, 27. PRODUCTION TEST Date First Production I Method Of Operation (Flowing, gas lift, etc.) N/A Date of Test Hours Tested PRODUCTION FOR OIL-I~B'L GAS-MCF WATER-BBL CHOKE sIZE GAS-OIl_ RATIO TEST PERIOD ~' "'Flow Tubing i CaSing Pressure CALCU"~_ATED,1~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE '"ll~ - ,, 28. CORE DATA , Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None * NOTE: Drilled RR 03/12/88. Perforated well and ran tubing 5/7/88.: ~Fractured well 6/27/88. .... Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC5/01 2 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 9783' 9862' 9862' 9965' TRUEVERT. DEPTH 5929' 5970' 5970' 6024' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 6/29/88) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ;)3~.,'~)~.~'~_ .~. ~_/~t~,~ .¢ 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 as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 6/27/88 3H-18 Attempt to frac Kuparuk "A" sand perfs 9900'-9920' in nine stages per procedure dated 6/22/88 as follows: Stage 1: 20 bbls 145° diesel @ 3 BPM, 3380 - 3500 psi Stage 2: 170 bbls gelled diesel @ 3 to 20 BPM, 3500 - 6440 - 5100 psi Stage 3: 9.5 bbls gelled diesel 1 ppg 16/20 Carb @ 20 BPM, 4800 - 4580 psi Stage 4: I8.5 bbls gelled diesel 2 ppg 16/20 Carb @ 20 BPM, 4580 - 4675 psi Stage 5: 17 bbls gelled diesel 4 ppg 16/20 Carb @ 20 B?M, 4675 - 4980 psi Stage 6: 16 bbls 6 ppg 16/20 Carb @ 20 BPM, 4940-4980 psi Stage 7: 15 bbls gelled diesel 8 ppg 16/20 Carb @ 20 BPM, 4980 - 5220 psi Stage 8: 10.5 bbls gelled diesel 10 ppg 16/20 Carb @ 20 BPM, 5220 - 5185 psi Stage 9: 22 bbls gelled diesel Flush @ 20 - 18 BPM, 5185 - 7600 psi Screened out @ 7600 psi w/22 bbls flush away. Fluid to Recover: 298.5 bbls diesel Sand in Zone: 2750# 16/20 Carbolite Sand in Csg: 15,382# Avg Pressure: 4800 psi Drilling Supervisor Date Reservoir Fluid Study ARCO OIL & GAS COMPANY Kuparuk 3H-18 Well Kuparuk Field North Slope, Alaska RFL 880462 ::: <. ~:i VIE D Western Atlas International A Litton/Dresser Company CORE LABORATORIES October 28, 1988 Arco Oil & Gas Company 2300 West Plano Parkway PRC E-1738 Plano, TX 75075 Attention' Mr. Jerry Haley Subject: Reservoir Fluid Study Kuparuk 3H-18 Well Kuparuk Field North Slope, Alaska RFL 880462 Gentlemen' A subsurface fluid sample was submitted to our Irving laboratory for use in a reservoir fluid study. Presented in the following report are the results. Thank you for the opportunity to perform this service for Arco Oil & Gas Company. If you have any questions or if we may be of further assistance in any way, please feel free to call upon us. Sincerely, James R. Fortner Area Manager Reservoir Fluid Analysis JRF' DK' 1 b 17 cc' Addressee ,-.- 1300 East Rochelle Boulevard, Irving, Texas 75062-3963, RO. Box 152053, Irving, Texas 75015-2053, (214) 541-2673, (800) 248-CORE Western Atlas International A Litton / Dresser Company CORE LABORATORIES LABORATORY PROCEDURES Arco Oil & Gas Company Reservoir Fluid Study Kuparuk 3H- 18 Wel 1 Kuparuk Field North Slope, Alaska RFL 880462 The composition of the reservoir fluid was determined by low temperature fractional distillation, along with gas chromatography. The results of the distillation, in terms of both mole percent and weight percent, are presented on page three. A small quantity of the reservoir fluid was charged to a high pressure windowed cell and thermally expanded to the reservoir temperature of 151°F. During a constant composition expansion at this temperature, the fluid was found to have a bubblepoint pressure of 2872 psig. The results of the pressure-volume relation measurements at reservoir temperature may be found on pages four and five. When subjected to differential pressure depletion at the reservoir temperature, the fluid evolved a total of 484 cubic feet of gas at 14.65 psia and 60°F per barrel of residual oil at 60°F. The resulting relative oil volume factor was 1.234 barrels of saturated fluid per barrel of residual oil at 60°F. The oil density and the properties of the evolved gases were measured at each point during the differential pressure depletion. These data are included in the summary of the differential depletion data on page six. The viscosity of the reservoir fluid was measured over a wide range of pressures at 151°F in a rolling ball viscosimeter. The viscosity of the fluid was found to vary from a minimum of 1.93 centipoises at the saturation pressure to a maximum of 7.17 centipoises at atmospheric pressure. The results of the viscosity measurements are tabulated on page nine. Three separator tests, one on the original reservoir fluid and two on differentially prepared oils, were performed at specified conditions. The results of these separator tests are tabulated on pages 11 through 13. The data from the pressure-volume relations test, differential pressure depletion and flash separator test were blended to create the data necessary to calculate in-place reserves and perform depletion drive calculations. These data are presented on page 14. -- i Western Atlas International A Litton/Dresser Company CORE ~ ~BORATORIES Company Well Field Arco Oil & Gas Kuparuk 3H- 18 Kuparuk Compan,¥ Fi 1 e RFL 880462 County North S1 ope State Alaska TABLE OF CONTENTS Page Laboratory Procedures i Table of Contents ii Well Information 1 Summary of Reservoir Fluid Data 2 Reservoir Fluid Composition 3 Pressure-Volume Relations 4 Compress i bi 1 i ty 5 Differential Vaporization 6-8 Viscosity 9-10 Separator Tests 11-13 Adjusted Differential Vaporization Data 14 Nomenclature and Equations 15 ii The analyses, opinions or interpretations contained in this report are based upon observat ons and material supplied by the client for whose exclusive and confidential use this report has been made. The interpretations or opinions expressed represent the best judgement of Core Laboratories. Core Laboratories assumes no responsibility and makes no warranty or representations, express or implied, as to the productivity, proper operations, or profitableness however of any oil, gas, coal or other mineral, property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. Page 1 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 WELL INFOIU~ATION FORMATION CHARACTERISTICS Formation Datum Date First Well Completed Original Reservoir Pressure Original Produced Gas/Liquid Ratio Production Rate Separator Conditions Stock Tank Liquid Gravity ft ss psig @ ft scf/bbl B/D .psig and__°F °API@ 60°F Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Reservoir Conditions: Pressure Date Temperature Status of Well Water Cut WELL CHARACTERISTICS ft ft ft in. to ft B/D/ps i @ B/D 2963 psig @ 9765 ft 151 °F @ ft percent Depth Sampled Status of Well Tubing Pressure Bottomhole Pressure Sampled By Date Sampled SAMPLING CONDITIONS ft psig ,psig @ ft Page 2 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 SUMMARY OF RESERVOIR FLUID DATA Volumetric Data Bubblepoint pressure (Pb) = 2872 psig at 151°F Thermal expansion at 5000 psig = V at 151°F = 1.04109 V at 68 ° F Differential Vaporization (DV) Data Solution gas/oil ratio (Rsdb) at bubblepoint : 484 standard cubic feet of gas per barrel of residual oil at 60°F Relative oil volume (Bodb) at bubblepoint = 1.234 barrels of oil per barrel of residual oil at 60°F Density of reservoir fluid at bubblepoint : 0.7908 gm/cc Viscosity Data Viscosity of reservoir fluid at bubblepoint = 1.93 centipoises Separator Test Data Separator Conditions 250 psig at 150°F Bofb(1) Rsfb(2) Tank Oil Gravity, °API at 60°F 1.250 503 24.7 Standard conditions = 14.65 psia and 60°F (1) Formation volume factor, barrels of oil at bubblepoint per barrel of stock tank oil at 60 F. (2) Solution gas/oil ratio at bubblepoint, total standard cubic feet of gas per barrel of stock tank oil at 60 F. Page 3 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 RESERVOIR FLUID COMPOSITION Cylinder Number Component 63544 Mole Weight Molecular Percent Percent Weight(z) Hydrogen Sulfide 0.00 0.00 Carbon Dioxide 0.34 0.11 Nitrogen 0.14 0.03 Methane 39.53 4.72 Ethane 3.89 0.87 Propane 3.08 1.01 iso-Butane 0.83 0.36 n-Butane 2.28 0.99 iso-Pentane 0.92 0.49 n-Pentane 1.21 0.65 Hexanes 2.30 1.44 Heptanes plus 45.48 89.33 100.00 100.00 34.080 44.010 28.013 16.043 30.070 44.097 58.123 58.123 72.150 72.150 84 264(2) Density, gm/cc at 60°F(1) 0.80064 0.81720 0.80860 0.29970 0.35584 0.50648 0.56231 0.58343 0.62408 0.63049 0.685 0.9141(2) Molecular weight of reservoir fluid = 134.40 (1) Assigned properties (2) Measured. taken from literature. Page 4 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 PRESSURE-VOLUME RELATIONS AT 151'F (Constant Composition Expansion) Pressure, Relative Y ps i g Vol umel 1 ) Funct i onl 2) 5000 0.9835 4500 0.9870 4000 0.9908 3500 0.9947 3300 0.9964 3200 0.9972 3100 0.9981 3000 0.9990 2872 Pb 1.0000 2842 1.0021 2814 ].0042 2751 ].0090 2703 1.0129 2593 1.0227 2393 1.0438 4.540 2170 1.0740 4.342 1943 1.1147 4.138 1694 1.1760 3.917 1462 1.2577 3.704 1257 1.3605 3.522 1078 1.4886 3.359 909 1.6620 3.209 667 2.0813 2.990 482 2.7174 2.800 333 3.8137 2.593 Density, _qm/cc 0.8041 0.8012 0.7981 0.7950 0.7937 0.7930 0.7923 0.7916 0.7908 Thermal expansion at 5000 psig = V @ 151°F : 1.04109 V @ 68°F (1) Volume at indicated pressure per volume at bubblepoint. (2) Y Function = (Pb ' P)/[(Pab$)(Rv - 1)]. Page 5 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 COMPRESSIBILITY AT ]51'F From 5000 psig to 4500 psig : 7.15 x 10-6 V/V/psi From 4500 psig to 4000 psig : 7.53 x 10-6 V/V/psi From 4000 psig to 3500 psig : 7.94 x 10-6 V/V/psi From 3500 psig to 2872 psig : 8.44 x 10-6 V/V/psi Page 6 . of 15 File .... RFL. 880462 Well Kuparuk $H-18 DIFFERENTIAL VAPORIZATION AT 151'F Sol uti on Rel at i ve Oi 1 Devi at i on Pressure, Gas/Oil Oil Volume, Density, Factor psig Ratio, Rsd(~) Bod(2) gm/cc Z 2872 Pb 484 1.234 0.7908 2600 441 1.218 0.7964 0.848 2300 395 1.201 0.8023 0.849 2000 348 1.184 0.8084 0.854 1700 301 1.167 0.8148 0.863 1400 254 1.150 0.8215 0.877 1100 207 1.133 0.8283 0.897 800 160 1.116 0.8353 0.920 500 112 1.098 0.8423 0.949 200 60 1.077 0.8511 0.979 0 0 1.038 0.8682 @ 60°F = 1.000 60°F : 0.9015 Gas Formation Volume Factor(3) 0.00558 0.00631 0.00730 0.00866 0.01067 0.01385 0.01942 0.03172 0.07838 Incremental Gas Gravity 0.634 0.625 0.618 0.616 0.615 0.622 0.634 0.662 0.725 1.185 Gravity of residual oil = 25.3°API @ 60°F Standard conditions : 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of residual oil at 60°F. (2) Barrels of oil at indicated pressure per barrel of residual oil at 600F. (3) Cubic feet of gas at indicated pressure per standard cubic foot. Page 7 of 15 File RFL 880462 ~ell KUPARUK aH-ia SOLLIF!ON GAS/OiL fiA'TiO DURING DIFFFJRBNTIAL VAPORiZAI-iON ~00 5O0 4O0 ~00 200 / 0 500 !O00 ~.500 2000 2500 3000 PRESSURE, PSI6 Page 8 of 15 File RFL 880462 Wall KUPARUK 3H-!8 RELATIVE OIL VOLUI*,IE DURING DIFFERENTIAL VAPORIZATION l ,30 LE 0 i ,20 i,15 ,05 i ,00 0 500 lO00 1500 2000 2500 3000 PRESSURE, PSIG Page. 9 of File RFL 880462 Well Kuparuk 3H-18 15 Pressure, .p..sig 5OOO 4500 4000 3500 3000 2872 2600 2300 2000 1700 1400 1100 800 500 2O0 0 VISCOSITY AT 15]'F Calculated Oil Gas Oil/Gas V i scos i ty, Vi scos i ty, V i scos i ty cent i po i se cent i po i se Rat i o Pb 2.37 2.27 2.17 2.O6 1.96 1.93 2.12 2.34 2.56 2.81 3.07 3.36 3.72 4.18 5.08 7.17 0.0189 0.0177 0.0167 0.0158 0.0149 0.0142 0.0135 0.0129 0.0122 112.2 132.2 153.3 177.8 206.0 236.6 275.6 324.0 416.4 Page iO o¢ ~5 File RFL 880452 Well WUPARUK BH-i8 V;SCOSZTY OF RESERVO~.R FLUZD 8.0 7 0 6 0 4 0 2 0 0 1000 2000 3000 4000 5000 6000 PRESSURE, PSZ6 Page 11 of 15 File RFL 880462 Wel 1 Kuparuk 3H- 18 Separator Conditions psig °F SEPARATOR TESTS (Reservoir Fluid) Stock Tank Formation Liquid Volume Separator Gas/Liquid Ratio Gravity, Factor Volume Gas (1) (2) °API at 60°F Bofb(3) Factor(4) Gravity 250 150 393 426 1.085 O. 671 to 0 180 73 77 24.7 1.250 1.051 1.317 Rsfb = 503 Standard conditions = 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. (2) Standard cubic feet of gas per barrel of stock tank liquid at GO°F. (3) Barrels of liquid at bubblepoint per barrel of stock tank liquid at 60°F. (4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at BO°F. Page 12 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 SEPARATOR TESTS (]800 psic] DV 0il) Separator Conditions Gas/Liquid Ratio psig °F (1) (2) Stock Tank Formation Liquid Volume Separator Gravity, Factor Volume Gas °API at 60°F Bofb(3) Factor(4) Gravity 250 150 239 258 to 0 180 73 77 Rsfb = 335 1.080 O. 681 24.9 1.195 1.051 1.308 Standard conditions = 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. (2) Standard cubic feet of gas per barrel of stock tank liquid at GO°F. (3) Barrels of liquid at bubblepoint per barrel of stock tank liquid at 60°F. (4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at GO°F. Page 13 of File RFL 880462 Wel 1 Kuparuk 3H- 18 15 Separator Conditions Gas/Liquid Ratio psig °F (1) (2) SEPARATOR TESTS (8oo psig DV 0il) Stock Tank Formation Liquid Volume Separator Gravity, Factor Volume Gas °API at 60°F Bofb(3) Factor(4) Gravity 250 150 83 91 to 0 180 87 91 Rsfb : 182 1.095 0.687 24.9 1.]40 1.051 1.330 Standard conditions = 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of liquid at indicated pressure and temperature. (2) Standard cubic feet of gas per barrel of stock tank liquid at 60°F. (3) Barrels of liquid at bubblepoint per barrel of stock tank liquid at 60°F. (4) Barrels of liquid at indicated pressure and temperature per barrel of stock tank liquid at 60°F. Page 14 of 15 File RFL 880462 Wel 1 Kuparuk 3H- 18 DIFFERENTIAL VAPORIZATION AT 151°F ADJUSTED TO SEPARATOR CONDITIONS Formation Gas Gas/Oil Volume Oil Formation Oil/Gas Pressure, Ratio, Factor, Density, Volume Viscosity ps i g Rs( ~ ) Bo(2) gm/cc F actor(3) Rat i o 5000 503 1.229 0.8041 4500 503 1.234 0.8012 4000 503 1.239 0.7981 3500 503 1.243 0.7950 3300 503 ].246 0.7937 3200 503 1.247 0.7930 3000 503 1.249 0.7916 2872 Pb 503 1.250 0.7908 2600 459 1.234 0.7964 0.00558 2300 413 1.217 0.8023 0.00631 2000 365 1.199 0.8084 0.00730 1700 318 1.182 0.8148 0.00866 1400 270 1.165 0.8215 0.01067 1100 222 1.148 0.8283 0.01385 800 175 1.130 0.8353 0.01942 500 126 1.112 0.8423 0.03172 200 74 1.091 0.8511 0.07838 0 0.8682 112.2 132.2 153.3 177.8 206.0 236.6 275.6 324.0 416.4 Separator Conditions' Primary Separator Stock Tank 250 psig at 0 psig at Standard conditions = 14.65 psia and 60°F (1) Standard cubic feet of gas per barrel of stock tank liquid at 60°F. (2) Barrels of oil per barrel of stock tank liquid at 60°F. (3) Cubic feet of gas at indicated pressure per standard cubic foot. 150°F 180°F Page. ]5 of File RFL 880462 ]5 Well Kuparuk 3H-18 NOHENCLATURE AND EQUATIONS Symbols Bo Barrels at reservoir conditions per barrel of stock tank oil. Bod Relative oil volume from differential vaporization test. Bodb Bod at bubblepoint pressure. Bofb Formation volume factor from separator test. Bt Total (two-phase) formation volume factor. Btd Total formation volume factor from differential vaporization test. Pres Reservoir pressure. Pb Bubblepoint pressure. Rs Standard cubic feet of gas per barrel of stock tank oil. Rsd Solution gas/oil ratio from differential vaporization test. Rsdb Rsd at bubblepoint pressure. Rsfb Sum of separator and stock tank gas/oil ratios from separator test. RV Relative volume from pressure-volume test. EQuations For Bo at and above the bubblepoint pressure- Bo : (RV)(Bofb) For Bo below the bubblepoint pressure' BO = (Bod)(Bofb/Bodb) For Rs· Rs : Rsfb _ [(Rsdb _ Rsd)(Bofb/Bodb)] For Bt: Bt : (Btd) (Bofb/Bodb) * SCH~UMBERG£R · GCT DXRECTIONA~ SURVEY CUSTOMEA blSTING FOR ARCO AbASKA, IbC, KUPARUK NORTH ~bOPE~AbASKA &URVEY DATEI 05-MAY-88 ENGINEERI M, MCBRIDE METHOD& OF COMPUTATION TOO6 60CATIONI TANGENTZAb' Averaged deviation and azlmuth INTERPObATIONI blNEAR V£RTICAb &ECTIONI HORIZ, DIST, PROUECTED ONTO A TARGET AZIMUTH OF NORTH 70 DEG 57 ARCO ALASKA, INC. 3H-18 KUPARUK NORTH SbOPE~ALASKA COMPUTATION DATES 19-HA¥-88 ,, PAGE 1 DATE OF SURVEY{ 05-HAY-8-8 KELLY BUSHING EbEVATZONI 76,00 FT ENGINEER~ M, MCBRIDE INTERPOLATED VALUE5 FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIHUTH DEPTH DEPTH DEPTH DEG HIN DEG log* 2O0 3O0 4OO 5OO 60O 7OO 8OO 9OO O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 O0 lO0 2OO 300 399 499 597 695 791 885 -76 O0 0 0 O0 24 O0 0 4 O0 124 O0 0 13 O0 224 O0 0 36 26 423 26 7 54 87 521 87 11 22 15 619 15 15 3 08 715,08 17 54 32 809,32 20 54 N 0 0 E S 48 55 W S 76 3O W N 71 11W N 55 56 W N 63 25 W N 68 13 W N 68 35 w N 66 2 W N 64 44 W 1000 O0 ½oo 1 O0 ! 150i 160 190 O0 1068 O0 1157 O0 1243 O0 1328 O0 1410 O0 1487 O0 1561 O0 1632 O0 1702 978 12 902,12 23 15 84 992,84 26 21 16 1081,16 29 37 30 1167,30 31 4 35 1252,35 32 24 41 1334,4! 37 35 87 1411,87 40 38 97 1485,97 44 16 28 1556,28 45 42 61 1626,61 44 39 N 64 11 W N 62 55 W N 62 36 W N 62 20 W N 63 3 W N 63 48 W N 63 28 ~ N 64 43 W N 64 38 W N 64 50 W 2000 O0 1773 10 1697,10 46 12 2100 2200 2300 240O 2500 2600 2?O0 2800 2900 O0 1840 O0 1901 O0 1958 O0 2013 O0 2066 O0 2120 O0 2175 O0 2231 O0 2289 02 1764,02 49 56 74 1825,74 53 44 94 1882.94 56 23 38 1937.38 57 13 89 1990.89 57 47 59 2044.59 57 8 64 2099,64 55 58 96 2155,96 55 24 21 2213,21 54 41 VERTICAL, DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0.00 0.00 0.00 N O,Oi 0.15 0,03 S 0.20 0.18 0.12 S 0,78 1,32 0,08 S 4.75 3.90 2.14 N 15.57 2.99 7.75 N 32,06 4.39 14,32 N 55,09 2,52 22,52 N 83,22 2,83 33.55 N 116,47 1.47 47.51 N 3000 O0 2347 14 2271.14 54 47 O0 2404 07 2328 07 55 50 153 47 195 14 241 51 29 6 34~ 7 79 4OO 40 463,1i 529,72 600,39 671,07 3300 3400 37 39OO O0 2460 O0 2517 O0 2573 O0 2625 O0 2674 O0 2723 O0 2773 O0 2824 74i 62 60 59 76 29 70 98 38 89 70 N 65 34 W N 65 20 W 815 N 62 14 W 893 N 63 55 ~ 974 N 67 53 W 1058 N 68 51 w 1142 N 68 30 W 1226 N 68 11 w 13LO N 67 24 W 1392 N 66 55 W 1474 31 2384 31 55 32 N 69 30 ~ 1720 62 244162 54 45 N 69 41W 1802 94 2497 94 57 8 N 71 ll W 1885 35 2549 35 60 36 N 70 44 W 1971 10 2598 10 60 42 N 70 23 W 2058 46 2647 46 60 9 N 70 25 W 2145 67 2697 67 59 35 N 70 15 W 2231 65 2748,65 59 7 N 69 55 W 231 7 0,00 g 0,02 ~ 0,26 W 0,85 W 4 28 W 13 80 k 28 97 W 50 50 W 76 46 W 106 0,00 N 0 0 E 0.04 S 29 57 W 0 29 S 64 55 W 0 85 $ 84 22 W 4 79 N 63 23 '~ 15 82 N 60 4( 32 32 N 63 41 w 55 29 N 65 57 W 83 50 N 66 18 w 82 W 116 91 N 66 I W N 66 56 w 1555 99 N 69 24 W 1638 ~ 69 3O O5 36 32 80 82 3,07 2,03 3,11 ,18 ,31 2,72 2O 51 96 93 63.48 N 140 44 W 154 12 N 65 40 W 82 34 N 178 O1 W 196 13 N 65 10 W 103 127 151 17b 204 234 264 295 82 N 219 20 N 264 46 N 311 79 N 362 89 N 419 35 N 479 83 N 543 03 N 608 65 W 242 95 N 64 42 W 74 W 293 71 N 64 20 W 41 W 346 29 N 64 3 W 55 W 403,36 N 64 0 W 19 W 466 58 N 63 57 W 49 W 533 70 N 63 57 W 73 W 604 79 N 64 I W 08 W 675 87 N 64? W 3 22 4 83 3 76 3 41 311 o 0 1 O9 1 O2 0 97 324 55 28 1 72 0 64 0 91 1 17 3 92 I 56 0 81 0 67 O, 52 0 68 649 76 N 1421 78 W 1563 22 N 65 26 W 680 709 737 765 793 822 851 880 909 19 N 1498 12 N 1575 77 N 1652 31N 1730 24 N 1 42 N 197~ 48 N 205 80 N 2137 14 W 1645 60 W 1727 38 W 1809 27 W 1891 37 W 62 W 2151 08 W 2237 95 W 2323 32 N 65 34 W 82 N 65 46 W 60 N 65 56 W 97 N 66 8 W 41 N 66 21W 50 N 6631W 28 N 66 41w 59 N 66 49 W 48 N 66 56 W ARCO ALASKAv ZNC. 3H-18 KUPARUK NORTH SbOPEvAbA~KA COHPUTATION DATEI 19-~A¥-88 PAGE DATE OF SURVE¥I 05-NAY-ff~ KELLY BUSHING E~EVATIONI 76,00 ENGINEER1 M, HCBRIDE ZNTERPObATED VALUES FOR EVEN 100 FEET OF NEASURED DEPTH TRUE SUB-SEA COURSE ~EASURED VERTICAL VERTICA~ DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG HIN DEG HIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET PEG 000 aoo 4400 4500 4600 4700 4800 49O0 O0 ~876 O0 929 O0 O0 ~983 037 O0 3090 O0 3143 00 3195 00 3247 00 3299 00 3350 2853, 57 2961,1 57 23 62 3014 62 57 57 42 3067 42 58 15 55 3119 55 58 50 19 3171 19 58 39 30 3223 30 58 43 98 3274 98' 59 0 5000 00 3402 25 3326,25 59 16 5100 00 3453 29 3377,29 59 20 5200 5300 5400 5500 5600 5700 5800 5900 00 3504 00 3554 00 3604 00 3654 00 3704 00 3756 00 3809 00 3862 15 3428,15 59 34 63 3478.63 59 52 57 3528,57 60 9 26 3578,26 60 15 13 3628.13 59 38 13 3680.13 58 1 21 3733.21 57 50 67 3786,67 57 27 6000 O0 3916 6100 O0 3970 O0 O0 4024 6300 00 4078 6 S400 6soo 6600 6?00 6800 6900 00 4132 00 4186 00 4240 00 4294 00 4347 00 4401 47 3840,47 57 30 28 3894,28 57 20 42 3948.42 57 3 76 4002,76 57 15 81 4056,81 57 15 69 4110,69 57 31 43 4164,43 57 30 18 4218e18 57 32 93 4271.93 57 32 45 4325.45 57 52 7400 7500 760 770~ 7800 7900 00 4454 22 4378 22 58 23 O0 4506 O0 4557 O0 4607 O0 4660 O0 4712 O0 4764 O0 4814 00~ 4865 00 4919 23 4430 8 4481 ~8 4531 19 4584 51 4636 02 4688 79 4738 93 4789 78 4843 23 59 0 48 59 19 98 59 26 19 58 5 59 14 79 59 44 93 58 20 78 56 57 N 70 2 w 2403 33 N 70 16 W 2488 N 71 lO w 2572 N 71 23 w 2656 N 71 38 W 2741 N 71 45 W 2826 N 71 39 w 2911 N 70 27 W 2997 N 70 I W 3082 N 70 11 w 3167 34 52 65 15 06 39 03 37 96 N 70 11 W 3253,82 N 70 17 W 3339.81 N 70 22 N 3425,90 N 70 15 W 3512,22 N 70 8 W 3598.85 N 70 ! W 3685,62 N 69 37 W 3772.27 N 67 55 W 3857.62 a 67 58 ~ 3942.25 N 68 5 ~ 4026.65 N 68 10 W 4110.84 N 68 10 W 4195.04 N 68 6 W 4279 Ol N 68 12 W 4362 86 N 68 28 W 4446 90 N 68 36 W 4531 07 N 68 35 W 4615 33 N 68 30 W 4699 59 N 68 28 W 4783 83 N 68 42 W 4868 23 N 68 52 W 4953 11 N 69 0 W 5038 48 N 69 5 W 5124 30 N 69 32 W 5210 57 N 72 6 W 5295 84 N 72 25 W 5381 04 N 72 40 W 5466 72 N 72 54 W 5552 83 N 73 29 W 5638 70 N 74 41 N 5722 81 0.95 1.05 0.96 0.24 0.57 0.47 0.49 1.84 0.83 0.33 0 O2 0 15 0 41 0 28 0 17 0 10 I 67 0 3O 0 15 0,79 0 22 0 37 [ os 59 0 35 0 17 0 O! 0 11 0.67 0,66 0 48 0 95 I 16 2 19 13 52 0 58 3 O4 1 O7 939 11N 2218.30 W 2408 90 N 67 3 W 967 98 N 2298.27 W 2493 79 N 67 9 W 995 85 N 2377.70 W 2577 82 N 67 16 W 1022 83 N 2457.39 N 2661 75 N 67 24 W 1049 65 N 2537.52 W 2746 05 N 67 3~ ". 1076 26 N 2618.17 W 2830 75 N 67 35 1103 03 N 2699,20 W 2915 88 N 67 46 W 1130,61N 2780,27 W 3001 36 N 67 52 W 1159.63 N 2860.53 ~ 3086.64 N 67 55 ~ 1188,76 N 2941.03 W 3172,19 N 67 59 W 1217 84 N 3021.82 N 3257 1246 1275 1304 1334 1363 1393 1424 1456 1488 ,99 N 68 2 W 92 N 3102 75 ~ 3343.93 N 68 6 ~ 87 N 31~3 83 W 3429;96 N 68 9 W 95 N 3265 11 W 3516,22 N 68 12 W 31N 3346 62 N 3602.81 N 68 15 ~ 87 N 3428 21 W 3689.54 N 68 18 ~ 57 N 3667 70 W 3946.35 N 68 20 ~ 19 N 3746 07 W 4030.8~ N 68 20 N 1519,58 N 3824 30 W 4115 14 N 68 19 W 1582' ; , 60 W 428 ,44 N 4058 51 W 436 46 N 1550 87 N 3902 19 N 3980 1613 1644,50 N 4136 1675,32 N 4215 1706,07 N 4293 1736,89 N 4372 1~67,85 N 4450 1 98,6~ N 4529 57 W 4199 43 N 68 19 W 51 N 68 19 w 68 19 W 70 W 4451 59 N 68 19 w 11 W 4535 84 N 68 1E 63 W 4620.16 N 68 19 ~ 13 ~ 4704.50 'N 68 20 W 56 W 4788~81 N 68 20 W 20 W 4873,29 N 68 20 W 1829 40 N 4608,39 ~ 4958 23 N 68 20 W 1860 10 N 4688 ~0 W 5043 64 N 68 21 W 68 22 W 1890 1921 1949 1975 2001 2026 2051 2074 81 N 4768' ,29 W 5129 45 N 4848.98 ~ 5215 33 N 4929,57 ~ 5300 30 N 5010,73 W 5386 02 N 5092,49 W 5471 51N 5174,80 W 5557 51N 5257,01 W 5643 32 N 5338,1~ W 5726 5O N 80 N 68 23 W 99 N 68 25 W 02 N 68 29 W 53 N 68 32 W 45 N 68 36 W 12 N 68 40 w 97 N 68 45 W ARCO ALASKAA ZNC, 3H-18 KUPARUK NORTH SLOPE~ALASKA COMPUTATION DATE: 19-HA¥-88 PAGE 3 DATE OF SURVEY1 05-MAY-§8 KELLY BUSHING ELEVATXONI 76,00 FT ENGINEER~ N. MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG VERTICAL DOGLEG RECTANGULAR COORDINATES HORXZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG 8000.00 4973.97 4897.97 57 12 8100.00 5028.07 4952.07 57 18 8200,00 5085.96 5005.96 57 32 8300,00 5135,32 5059,32 57 32 8400,00 5190 42 5114,42 56 16 8500,00 5245 73 5169,73 56 28 8600.00 5300 92 5224.92 56 40 8700.00 5355 77 5279.77 56 43 8800,00 5410 59 5334,59 56 36 8900,00 5465 44 5389,44 56 55 N 74 46 W 5806 N 74 52 W 5890 N 74 57 W 5974 N 75 8 W 6058 N 76 17 W 6142 N 76 41W 6225 N 76 55 W 63O8 N 77 3 w 6391 W N 77 19 N 77 32 9000 O0 5519 80 5443,80 57 14 9100 O0 5573 65 5497,65 57 35 9200 O0 5626 80 5550,80 58 8 9300 O0 5679 28 5603,28 58 25 9400 00 5735 41 5655.4! 58 39 9500 O0 5783 27 5707 27 58 50 9600 O0 5834 83 5758 83 58 56 9700 O0 5886 38 5810 38 59 5 9800 O0 5937 89 5861 89 58 47 9900 O0 5990 06 5914 06 58 18 ,68 ..62 .99 ,05 .00 6474.30 6557,38 N 77 51W 6640.74 N 78 I W 6724,37 N 77 59 W 6808,43 N 77 54 W 6892.92 N 78 4 W 6977.62 N 78 20 W 7062.43 N 78 24 W 7147.40 N 78 39 W 7232.34 N 78 46 W 7357.28 N 79 8 W 7401,75 79 09 22 ~' . , 57 , ~0~00.00 6147.62 71 62 22 79 65 34 oo ,, · t0293 , , 73 69 , 20 39 22 79 0 17 0 23 0 70 I 92 0 83 0 84 0 47 0 28 0 97 0 35 2096.48 N 5419.19 W 5810 2118.48 N 5500.36 W 5894 2140,41 N 5581,69 W 5978 2162,28 N 5663,39 W 6062 2182.81N 5744,27 W 6145 2202,25 N 5825.28 W 6227 2221.26 N 5906.47 W 6310 2240,09 N 5987,94 W 6393 2258,67 N 6069,49 W 6476 2276,85 N 6151,10 W 6558 58 N 68 51W 22 N 68 56 W 02 N 69 1W 14 N 69 6 W 02 N 69 1! ~ 66 N 69 13 ' 34 N 69 23 ~ 23 N 69 29 ~ 13 N 69 35 ~ 97 N 69 41 w 0 37 0 35 0 77 0 61 0 16 0 33 0 40 0 46 0 50 0,83 2294 75 N 6233,11 W 6642 10 N 69 47 W 2312 35 N ~9~85 51 w 6725 52 N 69 53 W 2329 94 N 2347 2365 2382 2400 241~i 243 2450 37 W 6809 72 N 6481 62 W 6893 46 N 6565 09 k 6978 94 N 6648 79 W 7062 17 N 6732 73 W 7147 22 N 6816 70 W 7232 04 N 6900 75 ~ 7317 39 N 6984 47 W 7401 39 N 69 59 W 70 N 70 5 W 24 N 70 11W 91 N 70 16 W 76 N 70 22 W 59 N 70 28 W 44 N 70 34 W 84 N 70 40 W 5.50 0.00 0,00 0.00 2466,26 N 7067,96 W 7485,89 N 70 45 W 2482.05 N 7151,63 W 7570.10 N 70 51,W 2497.84 N 7235.31 W 7654.34 N 70 57 W 2512,53 N 7313,12 W 7732,70 N 71 2 W ARCO AIaASKA~. INC, 3H-18 KUPARUK NORTH SbOPE~AbASKA COMPUTATION DATEI 19-HA¥-88 PAGE 4 DATE OF SURVEYI 05oMAY-88 KELLY BUSHING ELEVATXONI 76.00 FT ENGfNEERI M, MCBRIDE INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 1000 2000 50gO 6OOO 7000 8000 9000 0.00 '76.00 0 0 O0 978.12 902.12 23 15 O0 1773.10 1697,10 46 12 O0 2347.14 2271 14 54 47 O0 2876.47 2800:47 58 29 O0 3402.25 3326.25 59 16 O0 3916.47 3840,47 57 30 O0 4454,22 4378,22 58 23 O0 4973.97 4897,97 57 12 O0 5519,80 5443,80 57 14 I0000.00 10293.00 6042,75 5966.75 58 15 6196,39 6120,39 58 22 VERTICAL DOGLEG RECTANGULAR COOkDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/iO0 FEET FEET FEET DEG N 0 0 E 0.00 N 64 11W 153.47 N 65 34 W 741.62 N 66 56 W 1555.99 N 70 2 W 2403.33 N 70 11W 3253,82 N 68 10 W 4110,84 N 68 52 W 4953.11 N 74 46 W 5806.68 N 77 51W 6640.74 N 79 19 W 7485.85 N 79 18 W 7732.69 0.00 3.07 3,22 1.72 0.95 0.02 0.22 0.48 0.17 0,37 5.50 0,00 0 O0 N 63 324 649 939 1217 1519 1829 2096 2294 0.00 E 0 O0 N 0 0 E 48 N 140.44 W 154 12 N 65 40 W 99 N 672 36 W 746 79 N 64 12 W 76 N 1421 78 W 1563 22 N 65 26 11 h 2218 30 N 2408 90 N 67 84 N 3021 82 W 3257 99 N 68 58 N 3824 30 W 4115 14 N 68 40 N 4608 39 ~ 4958 23 N 68 20 W 48 N 5419,19 ~ 5810.58 N 68 51 75 N 6233,11 W 6642.10 N 69 47 2466.26 N 7067.96 W 7485,89 N 70 45 W 2512.53 N 7313.12 ~ 7732,70 N 71 2 W 3H-18 NORTH SLOPE w ALASKA'- ..... :/ :' ,¢h0;.a§.3 INTERPOLATED VAbUE$ FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG 0,00 .76,00 )76,00 276.00 376 05 47~ 53 5 74 610 19 784 16 89O 02 0 O0 76 O0 176 O0 276 O0 376 O0 476 O0 576 O0 676 O0 776 O0 876 O0 '76.00 0 0 0.00 0 2 100.00 0 10 200 O0 0 24 300 00 3 30 400 00 7 13 500 00 10 28 600 00 14 28 700,00 1~ 25 800,00 2 46 N 0 0 E S 20 36 W $73 7 W N 82 43 W N 55 47 W N 61 14 w N 67 39 W N 69 N 66 7 W N 64 43 W 997 69 O1 ~17 1108 1221 1338 1457 2 O4 2157 73 27 1276 24 1376 39 1476 69 1576 39 1676 18 1776 22 1876 976 00 900,00 23 10 00 1000,00 26 33 00 1100,00 30 11 00 1200,00 31 36 O0 1300,00 35 12 00 1400.00 40 23 00 1500.00 44 52 00 1600.00 45 13 00 1700.00 46 20 00 1800.00 52 7 2331.10 1976.00 1900.00 57 25t7.07 2076.00 2000.00 57 2700.64 2176.00 2100.00 55 58 2877,08 2276,00 2200,00 54 53 3050.36 2376,00 2300,00 55 17 3227,62 2476,00 2400,00 55 14 3403,79 2576,00 2500,00 57 17 3603,89 2676,00 2600,00 60 40 ]804.622776.00 2700.00 5934 ,09 2876.00 2800.00 58 30 N 6413 W N 6254 W N 6241W N 6221W N 6348 W N 6329 W N 6445 W N 64 56 W N 65 38 W N 63 11W PAGE 5 DATE OF SURVEY{ 05-MAY-88 KELLY BUSHING ELEVATION{ 76,00 ENGINEER{ M. MCBRIDE 05 45 65 62 78 N 6456 W 100060 N 68 47 W 1157 12 N 68 10 W 1310 91 N 67 0 W 1456 N 6822 W 1597 N 6929 W 1743 N 7112 W 1888 N 7023 W 2061 N 70 14 W 2235 N 7O 2 W 2402 01 18 49 48 76 79 56 453 543 644 744 859 0,00 0,00 0,14 0,57 3.08 12 51 27 86 5O 05 78 40 112 93 152 55 2 23 22 0,00 0,05 0,07 0,62 5,84 3,17 3,86 3,61 3,70 1,61 2:32 1.63 O4 2,4b 2,06 51 3 75 0 55 1 08 0 89 1 4 O1 0 8~ 0 51 0 93 0 00 N 0.00 E 0.00 N 0 0 E 002 ~ 0.00 W 0.02 S 1335 W 010 S 0.18 W 0.20 $ 6047 W 0 14 $ 0,65 W 0,66 $ 78 6 W I 18 85 09 7 3~ '~ : ' .06 ~ ,73 6063 ' ' 40 26 65 , 6308 N 139.6! W 15320 N 6541 W 83 98 N ~8~.20 W 199 72 N 65 8 W 282. 339.78 W 108 136 165 200 240 283 326 374 80 N 28 W 253 78 N 64 36 W 44 N 36 W 313 59 N 64 12 W 59 N 377 99 N 64 I W 37 N 410,11 W 456 44 N 63 57 W 25 N 491,98 k 547,51 N 63 58 W 76 N 584.02 W 649,30 N 64 5 W 24 N 675,11 W 749,80 N 64 12 W 73 N 780,20 W 865,53 N 64 20 W 39 23 N 906.91 W 9830 N 1052.10 W 1164 554 610 665 717 766 823 881 938 70 N 1195.32 W 1317 26 N 1329.64 W 1463 48 N 1459.93 W 1604 08 N 1596.90 b 1750 34 N 1733.28 W 1895 38 N 1896,90 W 2067 82 N 2060,83 ~ 2241 85 N 2217,57 W 2408 1007 67 N 64 9 W 14 N 64 39 W 76 N 65 6 W 00 N 65 20 W 45 N 65 29 W 51 N 65 4' ~ 13 N 66 b w 89 N 6632 W 57 N 665O ~ 12 N 67 3 ~ 4372.514186.96 2976.003076.00 2900.003000.00 57574~ ~ 71 3~ ~2717,862561 .57 ~'. 5324 1042992 .' 2930~_ 2367.352515 .43 ~ ]5667229082 ~ 67~ 432915 ~ 71 41 2879 17 47 I092,91 2668.60 : ]883 73 456231 3176.00 3100.00 58 40 71 ' §' 114658 ~ 282462 70 . e 475''25}. 3276.00 3200.0058 3~ ~ ~ 3044 3209 14 . . ~ 494"'70 3376,00 3300,00 59 70 12 : ]213 70 21 . ' ' ' ' ' 20 3889 . . : ~893. ~ 8 19 5543.81 3676.00 3600.006013 54 143669 3618 63 40 -- ~ 68 ' ' 5924,74 3876,00 3800,00 57 20 · ' ' VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZIMUTH FEET DEG/100 FEET FEET FEET DEG MIN ARCO ALASKA~ ZNC, 3H-18 KUPARUK NORTH SLOPEwAbASKA COMPUTATION DATEI 19-HA¥-88 . . PAGE 6 DATE OF SURVEY: 05-NAY-~8 KELLY BUSHING ELEVATION{ 76.00 FT ENGINEER{ M, MCBRIDE INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEV/ATION AZIHUTH DEPTH DEPTH DEPTH DEG HIN DEG NZN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DI~T, AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG NIN 6110 60 3976 O0 3900 O0 57 18 89 4076 O0 4000 O0 57 14 6294 6480 6666 6852 7~41 7 36 7430 19 09 4176 17 4276 32 4376 68 4476 53 4576 05 4676 46 4776 12 4876 O0 4100 O0 57 30 O0 4200 O0 57 29 O0 4300 O0 57 35 O0 4400 O0 58 35 O0 4500 O0 59 47 O0 4600 O0 58 26 O0 4700 O0 59 21 O0 4800,00 57 50 8003 75 4976 O04900,00 57 12 oo ooo.oo 8 06 5176 O0 5100.00 56 0 8554 77 5276 O0 5200.00 56 8 8736 90 5376 O0 5300.00 56 48 5400.00 8919 36 5476 O0 56 58 9!0.4 39 5576 00 5500.00 57 37 9293 74 5676 O0 5600.00 58 24 9485 96 5776 O0 5700,00 58 50 9679 80 5876 O0 5800,00 59 3 9873,18 10293,00 5976,00 5900,00 58 28 6196,39 6120,39 58 22 N 68 10 W 4203.95 N 68 11W 4358.56 N 68 34 W 4514.29 N 68 33 W 4671.08 N 68 36 W 4827.95 N 68 55 W 4988.63 N 69 7 , 5155.77 N 72 13 W 5321.40 N 72 43 W 5486,88 N 73 53 W 5654,94 N 74 46 w 5809 82 N 74 56 W 5965 N 76 4 W 6120 N 76 50 w 6270 N 77 6 W 6421 N 77 35 W 6573 N 78 ! W 6728 N 77 54 W 6887 N 78 17 W 7050 N 78 37 W 7215 28 66 46 84 5O O5 63 52 17 N 79 2 w 7379.13 N 79 18 W 7732.69 0 44 0 70 0 18 0 46 0 61 0 50 1 24 0 82 0 59 3 44 0,19 0,59 1 03 0 43 0 17 0 58 0 47 0 55 0 26 0,67 0,66 0.00 1554,19 N 3910,85 W 4208 36 N 68 19 W 1611,84 N 4054.52 W 4363 16 N 68 19 W 1726 45 N 4345' , .65 W 4832 ,55 W 4993 ,71 W 5160 ,90 W 5326 1669,19 N 4199 47 W 4519 , 57 W 4675 1784,01N 4491 1842,20 N 4641 1902.04 N 4797 1957e16 N 4953 2007,02 N 5111,75 W 5491 2056.10 N 5272,60 W 5659 04 N 68 19 W 96 N 6819 w 97 N 68 2r W 76 N 68 2 J 99 N 68 22 W 50 N 68 26 W 64 N 68 33 W 31 N 68 41 w 2097,31N 5422,23 W 5813 71 N 68 51W 2137 98 N 5572,65 W 5968 70 N 69 0 W 2177 6b N 5723. 62 N 69 10 W .71 6272 92 N 69 20 W , 33 W 6123 2212,69 N 5869 W 2246,99 N 6018 02 W 6423 2280,34 N 6166 95 W 6575 2313.12 N 6319 14 W 6729 2346,60 N 6476 40 W 6888 2380.51N 6637 02 W 7051 2413.81N 6799 71 W 7215 83 N 69 3t W 04 N 69 42 W 19 N 69 53 W 42 N 70 4 W 02 N 70 16 W 44 N 70 27 W 2446,0b N 6962,04 W 7379.29 N 70 38 W 2512,53 N 7313,12 W 7732,70 N 71 2 W ARCO AhASKAA INC. 3H-18 KUPARUK NORTH ShOPE,AhASKA MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD COHPUTATION DAT£~ 19-RA¥-88 PAGE 7 · DATE OF SURVE¥~ 05-MAY-SE KELbY BUSHING EbEVATION~ 76,00 FT ENGINEER~ M, MCBRIDE ZNTERPObATED VAbUES FOR CHOSEN HORIZONS MEASURED DEPTH BEbOW KB 9783.00 9862.00 9862,00 9965,00 10083,00 10293.00 ORIGZN= 1057 FNE~ 282 TYD FROH KB SUB-SEA 5929.09 5853,09 5970,16 5894,16 5970,16 5894,16 6024,34 5948,3~ 6086.28 6010.28 6~96,39 6120,39 $URFACE i.OCATION AT F~b SEC 12. T12N. RSE,UM RECTaNGULaR COORDINATES NORTH/SOUTH EAST/WEST 2431.20 N 2444.25 N 6886 48 W 6952 68 W 6952 6R ~ 7038 73 % 7 4 7~37 1 w 13 12 W ARCO AbASKAA INC. 3H-18 KUPARUK NORTH SbOPE~AbASKA COMPUTATION DAT~I 19-MA¥-88 PAGE ~ DATE OF SURVEYI 05-MAY-G8 Kgbb¥ BUSHING EbEVATIONI 76.00 FT ENGINEERI H, MCBRIDE MARKER TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A PBTD TD MEASURED DEPTH BELON KB 83.00 62.00 9862,00 9965.00 0083.00 ~0293,00 SURFACE bOCATION AT ORIGIN= 1057 FNb~ 282 FAb SEC 12. T12N. RSeE,UM TVD RECT~NGUb~R COORDINATE FROH KB SUB-&EA NORTH/SOUTH 5990 16, 5894,16 2444,25 N 5970.16 5894.16 2444.25 N 6024 34, 5948,34 2460,73 N 6086,28 6010.28 2479.37 N 6196.39 6120.39 2512.53 N 688b 48 w 6952 68 w 6952 68 w 7038 73 ~ 7137 41 w 7313 12 W FINAb WEbb bOCATZON AT TDI TRUE SUB-SEA MEASURED VERTICAb VERTZCAb DEPTH DEPTH DEPTH 10293.00 6196.39 6120,39 HORIZONTAb DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 7732,70 N 71 2 W SCHLUMBEROER O I RECT I ONAL SURVEY COMPANY ARCO. ALASKA, INC. WELL 3H- 18 FIELD KUPARUK COUNTRY USA RUN 1 BATE LOOOEO OS - MAY - 88 REFERENCE ?2762 WEL-L' (~057' 3H-18 FNL, 282' FWL, SE 12, T12N, R8E, UM) HORIZONTAL PROJECTION NORTH 10000 BO00 6000 4OOO 2OOO -2OOO WES~ REF 72762 SCRLE : 1/2000 IN/FT - 10000 -8000 -6000 -4000 -2000 0 2000 4000 6000 WELL: (1057' 109. 3H-18 V.ERTICAL PROJECTION FNL, 282' FWL, S. 12, 'T12N, R8E, UM) -4ooo -2ooo o o 2000 ............. ~ ...... ! .,~ .......... ~ .............. ~",+.-.!,..~..'~...~ .... ~ ~"i'"~'~ --~'-' r"~ ...... r"?---?..~ .-.~..-?.~ '7! .......... ~..~ ..... ~-~.-~...~ ...... ~....-.~...~ ...... ~...~...~-.~...~ ..... ~..4-~ ...... ~.4-.~.. ~...~ -.~-.~.-~..~..- -':-'?"'~"'H...~...~.+.~, .++.,.'+--~-..~+'H-..~ ..-~:-'+-'.~..-~"'~-+~_~~ ~-:-~ ...H.+-'~'..~ · -., ...... ~..+.~-.? ....... ~..~ .... ; ..... ~-+.~...~.-~...~-.-;-..~.-.¢nm~--+ ...... :...,...~.++.+.-~.++..~..~.-.~-- "?'"~ ....... ~'T'Y'T"y'~ ....... ~ ~--.4...+...;.4...~...;...;..+..; ....... :...~...*.?.,-..;..+.-,...~ ...... ~...~-..;..-?-.~..+.+-.;---;.-..~.~-4~...~-.;.-. '"FT"T"Y'Y'F'r"r": ....... ?"r"'"' ?"?"; "~ ..... ?' T'"F'T'T T"~'"r'T- , '"?"*"'~'"?'T-t-?'''?' ~ ....... % ~" '"'r"t'"?"~'"T'~'*' '~"' y"t-t ","'~'"t'"?"?" -~ :::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: ~hh~::;::T't:-:~::: ~~ ..~...~...~...; ...... ;...;..{.~ ..... ;..;..,4...~......;..~..~...c.;...;_i ..... ;.4.. }...; ...... ~...,4 .~ ..... ~-¢..L~..¢:~.:~.-;. ~:. ;.. -,.-:2 2 .+.}...}~.:~.. ¢...;.:;.. ~. ~..44,¢.-;... 2 44..4 '-~'-i'+'+',.P~.'-~"~-.+ ..... ~-~--y.+.!...~..~---~}-H.-.H..i.++'++" .... ;...¢...~...~...~.4..~.m.~ ....... +...,...+.4...~.4.+..~. ;...!.4...k.M...!...+.44 ..... i...l..-i...l.-.}4-;. '"~"T~" ,"f'"+' ~'"i ..... e' +-'~'~"'t'"?'T"]~' --.?i- r-..-f.-:.~..[4.~4_4.....-:.-~-?. · "+-~-!-'~ ...... +...+..+..~..--+..~'"f"~-'H"~'"?'; ...... +-..+..-~.--+--.¢-..~"-+-' !"-~ .... ;4.. -.-;.4.-.¢:--¢ ...... ¢...~.-~-. ¢-., ;-¢ ..~g...~--.]' f.-.;--.¢.-$--]-4-..¢..¢ .L.L..~ ..¢...f 4- -4...~--..~.-& · +-.i..4-..~ ..... +~..+..~ ....... +-.+ ~--.~-..t..~ ..... +.-,.--~..m-+-~-+-j.--~--+-e---+-+-.~+-- ...... -~ ................... , .................... , ~~ "TFTI ......FFr'T""Fr"YT"]'"r'T"Fr' ?T'T%P:~ l~ ~ ~ ~ -~'-T" %' T%" ~ ;TT"~"T"?FT''~-T%'~ ~'T'~ ~ ~ ~ ~ ! i · --~..~.4-.~.,-.~--~-.~.-.~.] ~ : ~ ~ : ~ ~. ] ~ ~ ~ ~ ~ ~ ~ i ~ .'4--~'"~'"~ ...... ;-'-~'.~ ...... ~1 ~~ ~'4'' ' ' ~] I ~ ~ T ~ ~r~--~d--%Yi--%-~m'f-T'"i'"T'T"~-~"~1' f:f ~ ~~ f f ~ 285, . ~,,.~ PROJECTION ON VERTICAL PLANE 289. - I~-~]. SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/2000 IN/FT · -"- STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMI, SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging ~ Perforate [] Pull tubing Alter Casing [] Other ~] COMPLETE 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 76' Feet 3. Address 6. Unit or Property name P.O. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1057' FNL, 282' FWL, Sec.12, T12N, RSE, UN At top of productive interval 1374' FSL, 1324' FEL, Sec. 3, T12N, R8E, UN At effective depth 1422' FSL, 1575' FEL, Sec. 3, T12N, R8E, UM At total depth 1456' FSL, 1751' FEL, Sec. 3, T12N, RSE, UM 7. Well number 3H-18 8. Approval number 8-229 9. APl number 50-- 103 - 20095 10. Pool Kuparuk River Oil Pool 11. Present well condition summary Total depth: measured true vertical 10293'MD 6196'TVD Effective depth: measured 10083 'MD true vertical 6086'TVD Casing Length Size Conductor 80 ' 16" Surface 4133 ' 9-5/8" Production 10130' 7" feet feet feet feet Plugs (measured) None Junk(measured) None Cemented Measured depth 210 sx AS I 115'MD 1600 sx AS III & 4168'MD 400 sx Class G Top job w/120 sx AS I 645 sx Class G 10165'MD ~ue Vertical depth 115'TVD 2966'TVD 61 29 ' TVD 12. Perforation depth: measured 9900'-9920'MD true vertical 5990'-6001 'TVD Tubing (size, grade and measured depth) 3½" J-55 tbg w/tail ~ 9663' Packers and SSSV (type and measured depth) Pa~, zone pkrs ~ 9698' & 9850'~ FHL pkr @ Stimulation or cement squeeze summary N/A Intervals treated (measured) 9592' & TRDP-1A-SSA SSSV ~ 1822' Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Compl etlon Well Hi story) Daily Report of Well Operations ~ Copies of Logs and Surveys Run X3 Gyro 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 Associate Engineer Date 5-31-~ (Dani) SW03/91 Submit in Duplicate ARCO Oil and Gas Company Well History- Initial Report- Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior' to spudding should be summarized on the form giving inclusive dates only. District ARco Alaska, Inc. Field KUPARUK RIVER UNIT Auth. or W.O. no. AK2611 Operator ARCO ICounty, parish or borough NORTH SLOPE Lease or Unit ADL: 25532 Title COMPLETE API: 50-103-20095 I Oate 05/03/88 IH°ur 0900 3H-18 IWell no. IARCO W.I. 56.0000 Prior status if a W.O. Spudded or W,O. begun ACCEPT Date and depth as of 8:00 a.m. 05/04/88 ( TD:10293 PB: SUPV:DL 05/05/88 ( TD:10293 PB:10081 SUPV:SC 05/06/88 ( TD:10293 PB:10081 SUPV:SC 05/07/88 ( TD:10293 PB:i0081 SUPV:SC Complete record for each day reported NORDIC I DRLG CMT 7"@10165' MW:10.0 NACL/BR MOVE RIG F/ 3H-19 TO 3H-18. ACCEPT RIG AT 0900 HRS 5/3/88. ND TREE. NU BOPE AND TEST TO 3500 PSI. RIH W/ 6-1/8" BIT. DRL CMT TO 9764' DAILY:S26,637 CUM:$1,203,~00 ETD:S26,637 EFC:$2,871,963 CIRC AND FILTER BRINE 7"@10165' MW:10.0 NACL/BR CIRC CEMENT FROM HOLE. DRILL CEMENT FROM 9764-10081'. DISPLACED DIRTY BRINE WITH 350 BBLS CLEAN. LD KELLY. POOH. CHANGE BHA TO 7" CASING SCRAPER AND JUNK BASKET. SLIP AND CUT DRILL LINE. CHECK BRAKE PADS. RIH. CIRC AND FILTER ALL BRINE. DAILY:S22,137 CUM:$1,225,737 ETD:S48,774 EFC:$2,871,963 RUN 3-1/2" COMP 7"@10165' MW:10.0 NACL/BR FILTER BRINE. POOH. RU SOS. RUN CET F/ 10081' TO 8893'. RUN GCT F/ 10081' TO SURF. PERF F/ 9900-9920' W/ 4 SPF. RUN GAUGE RING. RD SOS. RUN 3-1/2" COMP. DAILY:S202,677 CUM:$1,428,414 ETD:S251,451 EFC:$2,871,963 SET BPV & ND BOPE 7"@10165' MW:10.0 NACL/BR RUN 3-1/2" COMPLETION. LAND AND SET PACKER. BLEW SHEAR OUT SUB. SHEAR PBR. WO SLICK LINE UNIT TO SET STANDING VALVE TO TEST TBG AND PACKER. TEST COMPLETION STRING AND SSSV. PULL STANDING VALVE. SET BPV. SSSV @ 1822', FHL PKR @ 9592', TAIL @ 9663' DAILY:S25,549 CUM:$1,453,963 ETD:S277,000 EFC:$2,871,963 The above is correct Signature . I For form preparation and distri ~ see Procedures Manual, Sectlo~ ]~, Drilling, Pages 86 and 87. %J ASSOCIATE ENGINEER ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. J Accounting cost center code District IC°unty or Parish State ARCO Alaska, Inc. I NORTH SLOPE AK Field ILease or Unit IWell no. KUPARUK RIVER UNIT I ADL: 25532 3H-18 Auth. or W.O. no. I Title AK2611 J COMPLETE Operator ARCO A.R.Co. Spudded or W.O.AcCEPTbegun Date Date and depth as of 8:00 a.m. O5/O8/88 ( TD:10293 PB:10081 SUPV:SC Complete record for each day reported NORDIC I 5) API: 50-029-25532 W.h rrotal number of wells (active or inactive) on this Icost center prior to plugging and I 56. 0000 Jabandonment of this well 1 IHour I Prlor status if a W.O. 05/03/88 J 0900 RELEASED RIG 7"@10165' MW: 0.0 DIESEL ND BOPE. NU TREE. TESTED PACKOFF TO 5000 PSI. DISPLACED WELL WITH DIESEL. SITP 600 PSI. TESTED ORIFICE VALVE TO 1000 PSI - OK. BLED TUBING TO 700 PSI. SET BPV. SECURED WELL AND RELEASED RIG @ 1100 HRS, 5/7/88. DAILY:S26,944 CUM:$1,480,907 ETD:S303,944 EFC:$2,871,963 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) I Producing method I Official reservoir name(s) I Potential test data 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 AlJowable Effective date corrected ... The above is correct For form preparation aq~]distribution, see Procedures ManuaFt~l~ection 10, Drilling, Pages 86 and 87. I J-ZO-Em kSSOCIATE ENGINEER ARCO Alaska, Inc. Date: RETURN TO: May 26, 1988 Transmittal #: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles ~ Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 7168 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 H- 21 Cement Evaluation Log 4 - 2 0 - 8 8 4 6 0 0-1 1 1 9 8 · 3 H- 1 8 ,/ Cement Evaluation Log 5 - 0 5 - 8 8 8 8 9 3-1 0 0 81 30-1 6A Cement Evaluation Log 5 - 0 9 - 8 8 90-8111 3 O- 1 8 Cement Evaluation Log 5 - 0 9 - 8 8 2 6 9 0 - 7 51 5 3 O- 1 7 Cement Evaluation Log 5 - 0 9 - 8 8 2 4 9 0 - 7 9 6 8 3 H - 1 6 Cement Evaluation Log 5 - 2 1 - 8 8 7 7 9 5 - 9 61 4 If you have any questions, concerning this or any other transmittals please call me at 265-6835. -. Receipt Acknowledged: ........................... Date: ............ DISTRIBUTION; ARCO Alaska, Inc. Date: March 31, 1988 Transmittal #: 7135 RETURN TO: ARCO Alaska, Inc. Attn: Sabrina A. McKnuckles 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. ~ 3 H - 1 8 u~n Hole Tape and Listing 3 - 2 0 - 8 8 ~ 7 2 6 3 5 '~ 3 H - 1 8 Waveforms Tape and Listing 3 - 2 4 - 8 8 ~ 7 2 6 3 5 (2 Reels) Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger & 6as Cons .... ...~. Anchorage ........................... Date: ................... State of Alaska STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMN....,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing ~ Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other L-~ 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc. RKB 76' feet 3. Address 6. Unit or Property name P. 0. Box 100360, Anchorage, AK 99510-0360 Kuparuk River Unit 4. Location of well at surface 1057' FNL, 282' FWL, Sec.12, At top of productive interval 1320' FSL, 1320' FEL, Sec. 3, At effective depth 1424' FSL, 1563' FEL, Sec. 3, At total depth 1458' FSL, 1740' T12N, R8E, UM FEL, Sec. T12N, R8E, UM (approx) T12N, R8E, UM (approx) 3, T12N, RSE, UM (approx) 11. Present well condition summary Total depth' measured true vertical 1 0293 ' MD feet Plugs (measured) 6204 ' TVD feet 7. Well number 3H-18 8. Permit number 88-o~ 9. APl number 50-- 1 03-20095 10. Pool Kuparuk River Oil Pool None Effective depth: measured true vertical Casing Length Conductor 80' Surface 4133' Product i on 1 01 30 ' 10083'MD feet feet 6096'TVD Size 1 6" 9-5/8" 7" Junk (measured) None Cemented 210 sx AS 1600 sx AS II I & 400 sx Class G Top job w/120 sx AS 645 sx Class G Measured depth 115'MD 4168'MD I 1 01 65 ' MD ~ue Verticaldepth 115'TVD 2935'TVD 61 38 ' TVD Perforation depth: measured None true vertical Non e Tubing (size, grade and measured depth) None Packers and SSSV(type and measured depth) Pay zone pkrs ~ 9698' & 9850' 12.Attachments Description summary of proposal [] Well History Detailed operations program [] BOP sketch 13. Estimated date for commencing operation May, 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed & ~TUY,./ ~~.A~ Title Associate E n~'in~r ~ Commission Use Only (Dani) Conditions of approval Date SA3/72 Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearanceI Approved Copy Returned Commissioner by order of the commission Date Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report - Daily ./ Instructions: Prepare and submit the "Initial Reporl" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to sPudding should be summarized on the form giving inclusive dates only, District ARCO Alaska, Inc. KUPARUK RIVER UNIT rcounty, parish or borough NORTH SLOPE Leaseo~Unit ADL: 25532 Title DRILL Field Auth. or W.O, no. AK2611 lState 3H-18 IWeH no. Operator ~CO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 02/29/88 ( TD: 110'( SUPV:RB 03/01/88 ( TD: 1930'( 1 SUPV:RB 03/02/88 ( TD: 2453'( SUPV:RB 03/03/88 ( TD: 4185'( 1 SUPV:JP 03/04/88 ( TD: 4185'( SUPV:JP 03/05/88 ( TD: 6090' ( 1 SUPV:JP 03/06/88 TD: 9315'( SUPV:JP API: 50-103-20095 IDate 02/29/88 ]Hour Complete record for each day reported DOYON 14 0745 ARCO W.I. 56.0000 Prior statUS if s W.O. ) 10) ) ~20) ~) ;23) ) '32) ) o) ;) ,05) STRAP BNA MW: 0.0 VIS: MOVE RIG F/ 3H-22 TO 3H-18. NU 20" DIVERTER. ACCEPT RIG AT 0200 HRS, 2/29/88 . STRAP BHA. DAILY:S6,833 CUM:$6,833 ETD:S6,833 EFC:$1,695,000 DRLG AT 1930' MW: 8.9 VIS: 81 STRAP BHA. TEST DIVERTER. SPUD WELL AT 0745 HRS, 2/29/88. DRLD F/ 115' TO 1724' POOH. PU DTU. RIH. DRLD 12-1/4" HOLE F/ 1724' TO 1930'. DAILY:S76,982 CUM:$83,815 ETD:S83,815 EFC:$1,695,000 WASHING ?O BTM MW: 9.3 VIS:122 DRLD 12-1/4" HOLE F/ 1930' TO 1975' POOH. CHANGE BHA. RIH AND DRL TO 2453' POOH TO 2232' TIGHT. RIH. CIRC. POOH TIGHT. WORK PIPE TO 2093' POOH . CHANGE BHA. CUT DRLG LINE. RIH. WASH TO BTM. DAILY:S49,953 CUM:$133,768 ETD:S133,768 EFC:$1,695,000 POOH TO RUN CSG MW: 9.5 VIS:124 DRLD 12-1/4" HOLE TO 4185'. CIRC BTMS UP. SHORT TRIP TO HWDP. CIRC. POOH TO RUN CSG. DAILY:S43,699 CUM:$177,467 ETD:S177,467 EFC:$1,695,000 TIH 9-5/8"@ 4168' MW: 9.5 VIS:135 FIN POOH. RU AND RUN 106 JTS OF 9-5/8" CSG W/ SHOE AT 4168'. CIRC AND COND MUD. TEST LINES TO 3000 PSI. PUMP 80 BBLS WATER. MIX AND PUMP 1600 SX OF AS III AT 12.1 PPG. TAIL W/ 400 SX CLASS "G" AT 15.8 PPG. BUMP PLUG TO 2000 PSI. FLOAT HELD. LOST RETURNS DURING DISPLACEMENT. LD LANDING JT AND ND STACK. PERFORM TOP JOB W/ 120 SX AS I AT 15.7 PPG. CIP AT 1715 HRS. INSTALL BRADENHEAD. NU BOPS AND TEST SAME. MU BHA #5 AND RIH. DAILY:S242,751 CUM:$420,218 ETD:S420,218 EFC:$1,695,000 DRILLING 9-5/8"@ 4168' MW: 9.1 VIS: 34 FINISH TIH. TEST CASING TO 2000 PSI. DRILL FLOAT EQUIPMENT. RUN LOT. TURBODRILL 8-1/2" HOLE TO 6090'. DAILY:S42,666 CUM:$462,884 ETD:S462,884 EFC:$1,695,000 ) DRILLING 9-5/8"@ 4168' MW: 9.6 VIS: 37 25) TURBODRILL 8-1'/2" HOLE TO 9315'. DAILY:S60,650 CUM:$523,534 ETD:S523,534 EFC:$1,695,000 The above is correct For form preparati~'and distribution, see Procedures M/l~ual, Section 10 Drilling, Pages 86~nd 87. IDate }Ti,,s A880ClATE ENGINEER AR3B-459-1-D INumber all daily well history forms consecutively as they are prepared for each well. iPege no ARCO Oil and Gas Company Dally Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or pertorating, show formalion name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm' sheets until final completion. Report official or representative test or~ "Final" form. 1) Submit "Interim" sheets when filled out but not less lrequently thal~ every 30 days, or (2) On Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ,IC°unty or Parish IState ARCO A].&ska, ];nc. ~ NORTH ST.OPE AK Field JLease Or Unit I KUPARUK RIVER UNIT ~ 3H-18 Complete record for each day while drilling or workover in progress DOYON 14 Date and depth as of 8:00 a.m. 03/07/88 ( TD:10293'( SUPV:JP o3/o8/88 ( TD:10293'( SUPV:JP 03/09/88 ( TD:10293' ( SUPV:JP 03/10/88 ( TD:10293'( SUPV:RB 03/11/88 ( TD:10293'( SUPV:RB 03/12/88 ( TD:10293' ( SUPV:RB 8) 978) 9) 0) 0) 0) .1) 0) 2) O) 3) 0) POOH TO LOG 9-5/8"@ 4168' MW:10.1 VIS: 44 TURBODRILL 8-1/2" HOLE TO 10293'. CIRC. HOLE CLEAN. SHORT TRIP TO CASING SHOE. CUT DRILLING LINE. SPOT DIESEL PILL. POOH TO LOG. DAILY:S50,078 CUM:$5~3,612 ETD:S573,612 EFC:$1,695,000 TIH FOR WIPER TRIP 9-5/8"@ 4168' MW:10.1 VIS: 38 FINISH POOH. RU LOGGERS. RIH WITH DIL/LSS/GR. LOG OPEN HOLE FROM 5500'-SHOE. DIL TOOL MALFUNCTIONED. TIH FOR WIPER RUN WHILE LOGGERS LOCATE THE PROBLEM. DAILY:S44,104 CUM:$617,716 ETD:S617,716 EFC:$1,695,000 POOH TO CHANGE TOOLS 9-5/8"@ 4168' MW:10.0 VIS: 50 FIN TIH. CIRC. AND COND MUD. SPOT DIESEL PILL AND PUMP SLUG. POOH. RU TLC TOOLS. RUN TRIPLE COMBO FROM 10293'-8774'. LD SIDE DOOR SUB. POOH TO CHANGE TOOLS. DAILY:S43,219 CUM:$660,935 ETD:S660,935 EFC:$1,695,000 POOH WITH DRILL PIPE 9-5/8"@ 4168' MW:10.0 VIS: 51 POOH TO CHANGE LOGGING TOOLS. RIH. CUT DRILLING LINE. RIH TO 5169'. MU SOS SIDEDOOR. RIH TO 6984'. RUN GR/DIL/LSS FROM 6984'-5169'. RIH TO 6888'. MU SOS SIDEDOOR. RIH TO 8695'. RUN GR/DIL/LSS FROM 8695'-6888'. RIH TO 8525'. MU SOS SIDEDOOR. RIH TO 10293'. RUN GR/DIL/LSS FROM 10293'-8525'. RD LOGGER. POOH WITH DRILL PIPE. DAILY:S45,474 CUM:$706,409 ETD:S706,409 EFC:$1,695,000 POOH LDDP 9-5/8"@ 4168' MW:10.1 VIS: 45 POOH. RD LOGGERS. RIH FOR WIPER TRIP TO 9660'. ?U KELLY AND WASH OUT OF HOLE TO 9503'. LDDP AND WASH FROM 9503'-10293'. CIRCULATE. SHORT TRIP. SPOT DIESEL PILL. POOH LDDP. DAILY:S166,946 CUM:$873,355 ETD:S873,355 EFC:$1,695,000 CEMENTING 7" CASING 7"@10165' MW:10.1 VIS: 46 POOH. LDDP & BHA. PULLED WEAR RING & RU TO RUN 7" CASING. RAN 255 JTS 7", 26#, J-55, BTC CASING WITH SHOE @ 10165'. RU DOWELL. CIRCULATE & CONDITION MUD. TESTED LINES TO 4000 PSI & BEGIN CEMENT JOB. DAILY:S160,360 CUM:$1,033,715 ETD:S1,033,715 EFC:$1,695,000 JWell no, The above is correct For form preparation,4rnd distribution see Procedures Man/~,~l Section 10. Drilling, Pages 86 affd 87 IDate ITM ASSOCIATE ENGINEER ~-24-~ AR3B-459-2-B I N umber all daily well history forms Consecutively as they are prepared for each well. ARCO Oil and Gas Company Daily Well History-Final Report ?1 Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used lot reporting the entire operation if space is available. District ARCO Alaska, Inc. Field KUPARUK RIVER FIELD Auth. or W.O. no. AK2611 County or Parish NORTH SLO?E Lease or Unit ADL: 25532 JTitle DRILL tAccounting cost center code state AK 3H-18 IweH no. Operator ARCO Spudded or W.O. begun SPUD API: 50-103-20095 A.R.Co. W.I. 56.0000 Date I otal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our I Prior status if a W.O. 0745 02/29/88 Complete record for each day reposed DOYON 14 Date and depth as of 8:00 a.m. 03/13/88 ( TD:10293'( SUPV:RB 3) 0) RELEASED RIG 7"@10165' MW:10.0 VIS: CEMENTED 7" CASING WITH 100 SX 50/50 POI & 545 SX CLASS G. SET SLIPS. MADE ROUGH CUT ON 7,' CASING. LD LANDING JT & SET BACK BOPE. MADE FINAL CUT ON 7" CASING. INSTALLED PACKOFF & TUBING HEAD. TESTED TO 3000 PSI - OK. INJECTED 60 BBLS DIESEL DOWN 3H-18 & 3H-19. SECURED WELL & RELEASED RIG @ 1530 HRS, 3/12/88. DAILY:S143,248 CUM:$1,176,963 ETD:S1,176,963 EFC:$1,695,000 Old TD New TD PB Depth Released rig Date Kind of rig Classifications (oil, gas, etc.) ~ Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data ~/ell no. Date Reservoir ProOucing Interval Oil or gasTest lime Prodectio~ Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. water % GOR Gravity Allowable Effective dale corrected The above is correct Signature I Date ITitle sFe°; ~;O~ e~%er~r ~°nnu aaln, ds ed ~t, ~ nb u~ ~°,n' Drilling, Pages 86 and 87. AR3B~459-3-C Number all daily well history forms consecutively as they are prepared for each well. iPage no. Dlvlllon Of AttantlcRlehfletdCompany ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510~0360 Telephone 907' 276 1215 Date: March 17, 1988 Transmittal #: 7124 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 kransmittal. ~" Cyberlook ~ 2" & 5" Raw FDC '-2" & 5" Porosity FD'C ~5" Dual Induction ~" 2" Dual Induction ----2" Long Spaced Sonic- Delta Time '~-~ 5" Long Spaced Sonic - Delta Time '---Long Spaced Sonic - 10" Waveforms 3-8-88 9750-10150 3-8-88 9123-10230 3-8-88 9123-10230 3-7-88 4162-10255 3-7-88 4162-10255 3-7-88 4162-10226 3-7-88 4162~0226 3-7-88 4162-10~6 Receipt Acknowledged: DISTRIBUTION: NSK Drilling Franzen D & M ~State of AlaSka (+sepia) SAPC Unocal ARCO Alaska. Inc. is a Subsidiary Of AtlanticRichfieldCompany I IEMORAN'DdM State of Alaska ALASKA OIL AND~AS CONSERVATION COMMISSION / TO: Lonnie C Smith /I/::-~('' DATE: March 17, 1988 Commissioner F~LENO: D.BDF.89 THRU: FROM: Michael T Minder Sr Petroleum Engineer Petroleum Inspector TELEPHONE NO: SUBJECT: BOP Test ARCO KRU 3H-18 Permit No. 88-09 Kuparuk Rv Field Thursday, March 3, 1988: After completing an MIT on Standard's DIU ~eil i237/P,2'4' i' traveled to ARCO Kuparak River Field well 3H-18 to witness the upcoming BOPE test. Friday, March ~4., 1988: The test began at 1:00 a.m. and was completed at 2:30 ~,m~~o the. attached BOP test report shows, there were no failures. In summary, I witnessed the BOP test on ARCO's 3H-18. Attachment 02-001A (Rev. 8/85) O&G 1!4 ,~. STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date Representative Permit ~! ~ ~ Ca, ng S.t Drillin~ Contractor .,~'--~C:p~C2,/L,z/ Location, General ~..--' Well Sign ~-~ General Housekeeping ~' Rig z--~' Reserve Pit ~ Mud Systems Visual Audio Trip Tank ~/ Pit Gauge ~'~ Flow Monitor ~ Gas Detectors ~ BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Rig #/,~/ Representative ~-~ ACCUMULATOR SYSTEM Full Charge Pressure~~P~ psig Pressure After Closure /~~ psig Pump incr. clos. pres. 200 psiR ~ min~ sec. Full Charge Pressure Attained: ~ mind'sec. ~-'/~ / -~~ psig Controls: Master Remote~~ Blinds switch cover Kelly and Floor Safety Valves Upper Kelly ,./ ,. Test Pressure Lower Kelly / Test Pressure Ball Type / Test Pressure _~~ Inside BOP / Test Pressure Choke Manifold~c:~ Test Pressure No. Valves ~" ~ Test Results: Failures ~) Repair or Replacement of failed equipment to be made within No. flanges Z ~ Adjustable Chokes / Hydrauically operated choke Test Time / //?..~ hrs. days and Inspector/ Commission office notified. Remarks: Distribution orig. - AO&GCC cc - Operator cc - Supervisor January 29, 1988 Telecopy: (907) 276-7542 Mr. J. B. K ewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk' River Unit 3H-18 ARCO Alaska, Inc. Permit No. 88-09 Sur. Loc. 1057'FNL, 282'FWL, Sec. 12, T12N, RSE, UM. Btmhole Loc. 1398'FSL, I545'FEL, Sec. 3, T12N, R8E, 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. Ver~ truly.~yours, Commissioner of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO~-~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ~-"' STATE OF ALASKA ~ / ALAS~ . OIL AND GAS CONSERVATIO~ 'OMMISSION PERMIT TO DRILL 20 AAC 25.005 Drill ~ Redrill lb. Type of well. Exploratory [] Re-Entry [] Deepen la. Type of work Stratigraphic Test ~ Development Oil Service [] Developement Gas ~ Single Zone j~ Multiple Zone 2. Name of Operator ARCO Alaska, inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of wellatsurface 1057'FNL, 282'FWL, 5ec.12, T12N, R8E, UM (~ target) Attop ofproductiveinterval 1320'FSL, 1320'FEL, Sec. 3, T12N, RSE, UM Attotaldepth 1398'FSL, 1545'FEL, Sec. 3, T12N, RSE, UM feet 13. ~¢.ls.t~ce to nearest well 24' ~ 480' feet 12. Distance to nearest property line 1398'~ TD 16. TO be completed for deviated wells Kickoff depth 300 feet 18. Casing program size Hole Casing 24" 1 6" 12-1/4 9-5/8" 7!1 Maximum hole angle 57 0 Specifications Weigh~ Grade ]Coupling I Length 62.s~ H-401 Weld I ~o, ! -5s/ BTC I 4112' BTC HF- EI~W J10075 ' 8-1/2" 5. Datum Elevation (DF or KB) RKB 76' PAD 39' feet 6. Property Designation ADL 25532 ALK 2658 7. Unit or property Name Kuparuk River Unit 8. Well nu ,mber 3H-18 10. Field and Pool Kuparuk River Field Kuparuk River Oil Poo 11. Type Bond (see 20 AAC 25.025) Statewi de Number #8088-26-27 Amount $500,000 t% 1%r~1~ed depth (MD and TVD) (61 84'TVD) feet 25.035 (e)(2)) depth (TVD) 2 9 6 4 9. Approximate spud date 02/24/88 14. Number of acres in property 2560 17. Anticipated pressure (see 20 AAC Maximum surface 1 750 psig At total 19. To be completed for Redrill, Re-entry, and Deepen O Present well condition summary Total depth: measured feet true vertical feet Setting Depth Top Bottom MD I TVD J MD TVD 35' J35' J 115' 115' 35' J35' /4147' 2956' )erations. Plugs (measured) psig Quantity of cement (include stage data) ±200 cf 11oo sx AS III & 400 sx Class G blend 6184' 200 sx Class G(minimu~ O' above top of Kuparuk Effective depth: measured feet true vertical feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size measured true vertical Cemented Measured depth True Vertical depth 20. Attachments Filing fee ~ Property plat - BOP Sketch X DiverterSketch ;~ Drilling program X Drilling fluid program ~ Time vs depth plot ~ Refraction analysis Z Seabed report :~ 20 AAC 25.050 requirements 21. I hereby cert, J,f~at the foregoing js true and correct to the best of my knowledge · ? / . Signed ~ . _ ¢,-6~-;-~-' Title Regional Dr11 1 ing Engineer / ' ¢ ~ / Commission Use Only (AWM) PD2/72 Date Permit Number APl number 50-- IApproval date 01/29/88 Conditions of approval Samples require, d ~ Yes Hydrogen sulfide measures ~ Yes ~No Directional survey required z"Yes Required working pressure for B~PE ~2M;~3M; C 5M; ~ 10M; ~ 15M Other: ...~~ ~_,,,.~ ~~;i_.~..~* Approved by ~~ Commissioner Form 10-401 Rev. 12-1-85 ~' ISee cover letter for other requirements ~No Mud log required ~ Yes E'r'-No ~ NO by order of the commission Date Submit in triplicate GENERAL DRILLING PROCEduRE KUPARUK RIVER FIELD DEVELOPMENT WELLS I. Move in rig. 2. Install FMC diverter system. 3. Drill 12¼" hole. to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" casing. 5. Install and test blow out preventer. Test casing to 2000 psis. 6. Drill out cement and 10' new hole. Perform leakoff test. 7. Drill 8½" hole to logging point according to directional plan. 8. Run open hole logs. 9. Continue drilling 8½" hole to provide 100' between plug back total depth and bottom of Kuparuk sands. 10. Run and cement ?" casing. Pressure test to 3500 psiS. I1. Downsqueeze Arctic Pack and cement in 7" x 9-5/8" annulus. 12. Nipple down blow out preventer and install temporary Xmas tree. 13. Secure well and release rig. 14. gun cased hole loss. 15. Hove in workover rig. Nipple up blow out preventer. 16. Pick up 7" casing scraper and tubing, trip in hole to plus back total depth. Circulate hole with clean brine and trip out of hole standing tubing back. ~, 17. Perforate and run completion assembly, set and test packer. 18. Nipple down blow out preventer and install Xmas tree. · 19. Change over to diesel. , 20. Flow well to tanks. Shut in. 21'. Secure well and release rig. 22. Fracture stimulate. DEGASSER MUD CLEANER SHALE SHAKERS STI STIR STIR MUD CLEANER CENTRIFUGE LWK4/ih TYPICAL MUD SYSTEM SCHEMATIC Density PV DRILLING FLUID PROGRAM Spud to Drill out 9-5/8" Surface Casing to Weight Up 9.6-9.8 8.7-9.2 Weight Up. to TD 10.3 15-30 5-15 9-13 YP 20-40 8-12 Viscosity 50-100 Initial Gel 5-15 10 Minute Gel 15-30 Filtrate API 20 pH 9-10 % Solids 10± 35-40 2-4 4-8 10-20 9.5-10.5 4-7 Drilling Fluid System: - Triple Tandem Shale Shaker - 2 Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual & Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - 8-12 35-45 3-5 5-12 9.5-10.5 9-12 Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (Kuparuk average) and a gas gradient of .11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test our BOP equipment to 3000 psi. After 200' of departure, there are no well bores within 200' of this proposed well. In accordance with Area Injection Order No. 2, excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shutdown in disposal operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of the fluid disposal. LWK5/ih~ KUPARUK RI VER UNIT 20" D IVERTER SCHEMATIC ii DESCRIPTION 1 .16" CONDUCTOR 2. FMC SLIP-ON WELD STARTING HEAD ,5.FMC DIVERTER ASSEMBLY WITH TWO 2-1/16" 2000 PSI BALL VALVES 4. 20" 2000 PSi DRILLING SPOOL W/lO" OUTLETS 5. 10" HCR BALL VALVES W/10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION. 6. 20" 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 2 t 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. 2. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES J6 11-3-86 , ! 6 DIAGRAM #1 13-5/8" 5000 PS:[ RSRRA BOP STACK I. 16" - 2000 PSI TAI~O0 STARTII~ HEAD 2. II' - 3CX~ PSI CAS~N~ HEAD 4. 15-5/8" - 50~ PSI PIPE RAM~ 5. 15-5/8" - 5000 PSI DRILLIN~ SPOOL ~¢/O'K~E ~ KILL LTI~ES 6, 15-5/8" - 5000 PSI DOtSLE RAM W/PIPE ~ ON TOP, ?. 15-5/8." - 5000 PSI AltAR ACC~ATOR CAPACITY TEST I. Q-ECK ~ FILL ~TOR RESERVOIR TO PROPER LEVEL WITH HYDRAiJ_IC FLUID. 2. ASSURE THAT ACCtI~iI. ATOR Pf~ IS 3000 PSI WITH 1500 PSI ~TREAM OF THE REGULATCR. 3. OSSERVE Tlli~ Tt-.I~ CLOSE ALL L.I~TS SIMJLT/~OJSLY AN3 RECORD ]]-E TINE AhD PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING ~ OFF. 4. RECO~ ON N~C REPORT,. THE ACCEPTABLE LOVER LIMIT IS 45 SE~ CLOSING TIM[ A~ 1200 PSI REI~INING 5 4 , > 13-5/8" BOp, STACK TEST I. FILL BO:> STACK ~ O-EKE MN~FCLD WITH ARCTIC DIESEL. 2. a..ECK THAT ALL LOCK DOi~ SCREItS IN NiLFE/~ ARE FULLY RETRACTED. SEAT TEST PLUG IN WELLHEAD WITH ~ING JT AN:) RUN IN L~ 5. CLOSE ~ PREVE~ N~D ~ KILL ~ CH[XE LIhE VALVES ADJACENT TO BCP STACK. ~ OT~ER VALVES ~ C~3(ES SHCU. D BE ~ 4. PRE~ UP TO 250 PSI /~D H~LD F~R I0 MIN. IN- CREASE PRESSLRE TO ~3(Z) PSI N~) HOLD FC~ I0 MIN. BLEED PRESStRE TO 0 PSI. 5. OPEN AN~ULAR PREVENTER ~ MN~4JAL KILL ~ Q-~KE LINE VALVES. CLO~E TOP PIPE RAIVB ~ HCR VALVES ON KILL N~) CHCKE LIliES. 6, TEST TO 250 PSI ~ 5000 PSI AS IN STEP 4. 7. CONTIN.E TESTING ALL VALVES. LIliES, ~ CI-13(ES WITH A 250 PSI LOW ~ ~ PSI HIGH. TEST AS IN s'rEP 4. DO NDT PRE~. TE~T ~ ~ THAT NDT A FULL CLOSING POSITIVE SEAL CH~. C~LY ~i ION 1EST Q-E~ES THAT DO ND-[ FULLY CLOSE. 8. OPEN TOP PIPE RAM~ ~ CLOSE BOTTOM PIPE RAIV~. TEST BOTTOM PIPE RAM~ TO 250 PSI ~ 5000 PSI. 9. OI=EN BOTTOM PIPE RAI~ BACK OUT ~NG J-r PLLL OJT OF HOLE. i0. CLOSE BLII~D ~ AhD TEST TO 250 PSI ~ 5000 PSI. II. OPEN BLII~) RNV6 ~ RETRIEVE TEST R.UC~ ~ SURE M~NIFCLD ~ LIliES ARE FLI. L OF NON-FREEZING FLUID. SET ALL VALVES IN ERILLING POSITI~ 12. TEST 5-'rAI~I~PIPE VALVES. KELLY. KELLY coa<S, DRIU. PIPE SAFETY VALVE, AI~ INSIDE B~ TO 250 PSI ~ PSI. 15. REC{3~ TEST IhF~TION CN BLOI~IIJT PREVENTER ]'EST FORM. SIGN, AhD SEhD TO DRILLING SUPERVI~. 14. PERF(]~ 03vPLETE BOPE TEST AFTER NIPPLING UP AN) V~EKLY THEREAFTER FLI~TICNN. LY OPERATE BCPE QAILY. 51008400 ! Kuperuk F'.:teld,. North Slope, Alee'ka ~ 1.000~ ._;5000 RKB .ELEVAT [ ON t 7'6' 9 BUILD 3 DEG 15 PER 100 FT .... 3~ B/PERHAFROST TVD-~ 591 ....rPID-1 T1'8 'DEP-502 · [ . 6000 .... I 0 ~ 000 ZOO0 5157 T/ UONU SNDS TVD=1876 THD"'2154 DEP"831 EOC ~TYD- 1 906 iTIID~220Z..DEP-BZ6 T/ W SAK !SNDS TVD"2556 Tf'ID-3~$08 DEP" 1 885 K-12 TVD'2756 THD'3ZZ8 DEP'2196 9 5/8" CSG PT TVD-2956 THD-414Z IDEP'2507 ,IrVD-4~2~-THD-Oeee DE -COL-¥ILLE -,.TVD-3006--lrHD-4239 -DEP-2~84 ..... : T/ ZONE ':D TVD-5981 THD-9Z34:" :DEP-?203 T/ ZONE!C TVD-5985 THD-97411 DEP-.;7'2]Or T/'ZONE ! A '-TVD"6006 'TI~"9780i-DEP'72 TARGET CNTR TVD-6031 THD-9826 DEP-Z281 B/ KUP SNDS TVD-6OZ6 THD-9909 DEP-7$5:I TD (LOG ~PT) TVD,~;! 84 -THD- 2000 3000 "1.000 5000 · :- VERTICAL SECTION ' ! sooo rooo 3000 2000 z , ! 000 1000 HORIZONTAL PROJECT[ON SC~.E I tN. - tO00 FEE]' ARCO ALASKA. INC. P.d 3H, Well Ne, 18 Pre~eeed Kupe¢uk Field, #eeth Sle~e, Aleeke 8000 ZOO0 6000 5000 I ! WEST-EAST 4000 3000 ZOO0 ~ 000 0 1000 ~ i SURFACE LOOAT[O#, rD L~AT N 70 DEC; 57 VII N 7281' (TO TARGET): ~ , 150 200 250 ~00 ~50 100 ~50 ........... ~ ............................................ ~ ....................... ~ .................... t ........... II 12 I COORDINATES ARE A.S.P., ZONE 4. ALL WELLS LOCATED IN SEC. 12, T. 12 N.,R.8 E., UMIAT MERIDIAN. 'X' ASPs LATITUDE LONGITUDE 6,ooo,11o.73 6,ooo, 135. $1 6,ooo, 16o. 57 6,000, 185.28 6, OOO, 210.66 6,000,255.50 $, OOO, 26 O.34 6,000,285.82 6,OOO,310.30 $,000,335.43 G, 000,450.51 6,000,4?$.46 $,OO0,500.4! 6,000, 52.5.44 6,OOO,$OO.44 6,000,650.45 6,OOO,675.40 6 ,OOO, 7OO.47_ 498,655.44 498,655.43 498,655.39 498,655.43 498,655.47 490,655.40 498,655.41 498,655.44 498,65§.45 498,655.44 4 90,655.44 496,655.3~ 498,655.4Z 98,655.4 498,655.4T 498,655.55 4 98,655.49 498,655.63 498,655.?$ TOe 24'41.$3t" 7De 24'41. ?T~" ?Oe24'42.O2Z'', ;~4 42.514" ~44~. ~, TO~ 24'45.~3' 70~ ~4'43.494, 70eZ4'43.T41' 7~24'44.6~' 70~24'44873'' 7~24' 4 ~.119" 70~4'45.610 70o24'45.e~'' ~0024'46.1~'' REGISTERED ANDLICENCEDTO PRAC- TICE LAND SURVEYING IN THE STAT[ OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BYME ORUNDER MY SUPERVISION, AND THAT ALL DIMENglON~ AND OTHER DETAILS ARE CORRECT AS OF 6/9/87. 70024'46.840" ?0024 '47.085" 150° 00' 39.416" 150°00' 39.417'~ 1500 OO'~9.418' 150000, 39.417" 15o* oo' 39.4 ~s" I ~° oo; 150° O0 ~cJ.418' 150e O0' 39.417"1 15o° oo', 150° OO, 39.411".] 15o°oo 39.4181 15OO OO'39.43~'1 I§Oe OO'39.419'1 150° O0' 39.4lQ' t 50e OO' 39.419' 150000, 39.417' 15oOoo'39.415" 13oOoo')9.414- 15OEOO'$9.418'' I § DODO' 39.41 ~" ?0024'47.331'' 1500OO'~9.41(~ I HEREBY CERTIFT THAT I AM PROPERLY .,,t'~'~lkl* t 11~ .~.... ~,,,,.,,,.,., ..... .Y.J.C[~I I.T Y SCALE i ; iMmLES ~. ALL DISTANCES SHOWN ARE TRUE. $. ELEVATIONS ARE B.P.M.S.L. 4. REFER· FIELD BOOK L-17-19,35-441L-~I'-II, L~9-$2. B. O.g. ELEVATIONS FROM CED-RlXX- $41'1~ 6. HORIZONTAL POSITION BASEDON ~H CONSOL ,, · AIjG f ~ I~,,/ , ~4 6' ;e,' ~.r ~e.e' ,4zz' ze,: ~,r: ~8e', 1397' 2e~ 33.6 · 38.9 281' 261', 281' 291' 2 261: 261 261' 26 2' 262' 282' 282' 292' 33.6~ 33.6, 33.6 33.6', 33.8 33.8' 33.8' 33.9' $3.9' 33.9' CO Alosko Inc. 36.$, 36.6 36.7' 36.6' 38.8' 38.7 36.?' 36.6' 38.9' 58.7' $ 8.6' D.S. 3H WELL CONDUCTOR AS-BUILT LOUNSBURY Associoles 1322 1232' 1207' 118Z' 1082' 1057' IOO?' 982' 957' AR ANCHORAGE ALASK, A. OWN BY: PJW CHK BY: -- CHECK LIST FOR NEW WELL PERMITS Company ~ ~ ~O Lease & Well No. ITEM APPROVE DATE YES NO (1) Fee %,r~ ;]zF~ 1. Is the permit fee attached .......................................... ~ (2) Loc.., (2 thru 8) (8) (3) Admin ~,~, 7-~-~$ 9. (9 thru 13) 10. ,lzr 11. (10 and 13) 12. 13. (4) Casg ~,~.~< 7-;2~-~e (i4 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 2?. 28. 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~ Is a conservation order needed ...................................... '~ Is administrative approval needed ................................... A~ ,, Is the lease number appropriate ..................................... v~ Does the well have a unique name and number ......................... v~ ........... Is conductor string provided ........................................ ~' Will surface casing protect fresh water zones ....................... -~ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... -~ Is the drilling fluid program schematic and list of equipment adequate~ ,,~ Are necessary diagrams and descriptions of diverter and BOPE attached. ~ Does BOPE have sufficient pressure rating - Test to 2Ooo psig .. ~ Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. /~ REMARKS (6) OTHER (29 thru ~1)' (6) Add: For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented Additional requirements ............................................. o .Geology: Engiqeering: WWB Wv~ LCS ?{~ BEW ~ WVA / ~~ RAD ,,'-}~ rev: 01/28/87 6 Dll iNITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file 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. .o * .... SC~h~J~BERGER .... * DATE O~IGIN :CSU REEL CO~;~Et~TS :SC)-~I~Uq~iRC;ER ,';Ebb S~:]PVIC~S CGU TAPE: SERVICE t)ATE :881031O9 ORIGIN :CSU 'i'A~ E hAME : PREVIOU6 TAPE :. CO~t~E~tT5 :SCH[,~BE:I~GE~ ~%I..,L SERViCgS CS~ TAPE ** FI[,E HEADER FIbE NAaE :DD6HC ,o41 SERVICe: ~AME :bUG VERSION # :30.4 DATE MA×!~UN bENGTH :8192 F'ILE TYPE PREVIOUS FILE DATA F'ORiZAT RI~:Ci?,RD ** T ,fPE i P[.UC ESo (~,~CT A t.. } 0 3b 63b ~ 3b I 50 Ul 0 010 120 12 V Z; U 1, 20 31 0 5~0 560 52O 522 522 522 5~.i u 522 522 5 © 0 J 0 0 0 0 o 0 0 {) 0 (> 0 U 0 o 0 0 0 4 2 4 2 2 2 4 4 4 2 2 2 2 1. u24 1024 4 1024 1024 2 4 2 2 2 2 2 2 2 2 2 2 2 101 OUO0 i 1000t~O00000000 10 1 OO(tO0000000 1 UUOOU OOOOOOoO ] uOOO000000000 loO0000o4uo000 t OOUO000~OOoO0 1 ugOooOU()OOOOt) 10000000400000 l ] 000000~,400000 I OOOOOOU4OOOOO 1 102000(;0000000 1060()00~ 000000 10000000000000 10200000000000 10200t)O0000OO0 1 OOOOOOOqOOO00 ! 0200000000000 1100uuuUOOOUOO 1 11000 1 I OOO(;OO{;O00OO llO000000OOOOO 1 lOOOOOo,~oooo0 11 [ IOOO(~O0000000 1100000OOUO000 11000OO000()OVO I oO0(~OOO<~UOOOO lOOO000000000O 100g()uOOOOOOO() 1000000OOO000O 49 49 10200000()0000(? 49 10()00000000000 3 4 5 i ~ ~ 4 k i< P i~ '13 73 SPFC IFICAT 1.0;'; SERVICE &iEXv'tCE t~,i] API ;,i.:i APl bL)bHC S u7 Ut(~ Of U [.,DBHC ~.~ 07 63t 21 0 4l DDBHC 8 07 ~3~ 2 1 0 o 1 D 0 B N C [' / H F~ 07 636 21 (.'~ 41 [.>ObHC [ O? 63t, 2i Pt) BHC F (:/ 150 O1 0 ~1 [) D B H C 0~ v 07 0 f 0 01 () 41 D t) B H C ~'.', v u 7 u I U u 1 u 41 [>DBNC a V o7 01U O 1 0 P D B H C ~" '~ 0 'i 010 u 1 o 4:1 D O L:g H C ~'~ ,-, h b u I I 20 44 u 41 DDBHC ~ ..... hL, 07 12o 4~ O i') B H C [.) l,~ ~.,~ p: 0 '1 2 2 2 u i o ~t 1 [} D B H C F} Fi ~5,~ a07 22 0 i) 1 u 41 DDBHC OHms.: 07 I 2J~ 44 PDBHC rv~ p{{"~ 07 I ~ ~ 4~ L, 41 DDBHC F3 07 2F2 Ol ~.~ 41 DDBMC GAP1 07 310 Ol 0 41 D D ~ H C G ~:~ P l u 7 3 i 0 0 1 u 4 ODB~C o7 5H[; 02 0 41 b D ~ H C t) 7 5 f; o 01 0 4 DDBHC b 07 5~ 1 O1 O 4l [} i,) a H ~ F u 7 5 ~ I, u 2 u ~t i O i} B H C 07 582 02 o ,i 1 ODBHC 07 b 80 (;4 DDBHC F 0 I 5R 1 03 (') 41 DDBfiC g (.~ 7 5 0 i U 4 O 4 1 DDF:.~HC i~'7 ~2 C3 o 41 0 0 4230 1 1 I~CH 00 . lin 1 1 ,, 1 5j, 25~5 SPL 4 2 4 2 4 2 2 2 2 2 2 4 4 4 4 a 2 2 2 2 '[02~ !024 4 4 4 1024 i024 4 4 PROCESS ( L~CT A b ) 10 1 UuuOOUOO000 1000uOUO000000 lOOUOuuOgOOUO0 10 100000000000 i 000000u400000 I0000o00o00000 I O000oOooOO000 10000000400000 10000Ouu400OO0 lO40000O 000000 i OOOOOO0~oO00O 1 uO{)O00O4UO000 IO{,2UUUUu/.~O0000 100OOO00&OOOOO 10700UOU,.gu{')O00 1 49 I 49 1 79 1 79 5 22 63 0 41 522 F, 3 0 5?2 63 o 41 5 ? 2 u 3 0 4 ! 522 ~b 0 41 b2~ 32 0 522 ~3 O 4I 522 t, P l~ F 0 (, a.t. 49 68 49 49 49 49 49 49 49 49 49 49 49 49 49 DATA ** I. 'J 776. (> ('~ 00 254U. - 33,7 t ~ ~ S'P ~,i V 2 '~ t::,. ! 61> 7 8 F [, A 24b. 5456 i i~ 2.0 t~ 25 G R 0. t.} 25 () ¢~F2N t 261.,r)01.)o 3.3 7 7 {) (,: B t'., I 3. 7780 o. o U u 0 -337,2500 ~, 0945 4,O560 105,7500 0;025O {}. u25() t. 048 0.0 I 06. TOD [>IFF ~sPa RIL~ IC'V WF2D ~F4D ITT TO TTSL 58386652 TI~:~E '1 '1<),(>0oo 39.1.75u0 SP -27. 259o 248,~392 RIhL) 2,~5.3935 3.8I.q4 (]!LD 267. '176~ 00u()'o R(;R I,<}7 ~'"i~5 U, o 193 .t; T 1 1248, {..: <.} u {: 1254. ttOOt; A)v~pL 1 10.0 [} {) (} $ ~'~ A T o. 5 '[ a [ 1 ! ! OOt30t;O 0 10000 o u o lO00000o 1(}000o00 lO00()uou 1o20o000 lO00{~O00 1 0 0 0 000 0 10000000 't {} 0000 g 0 lUoOUuOu 1 u 000 t., 0 U 10100000 O00OO o O O 0 () 0 O 000 OOO00 00000 00000 00000 0 000 0 00000 <)uO00 00000 00000 00000 00000 (:) O 00 n GO000 O 000 (} 13o, 6.250 30.~, 25000 256. 499 u, O0(}O b939 4326 6940 , 5752 1 'J7. 2500 o · 000.0 !, 28 O, J, 7 3 90 t~, OOOO 676 , 410 108 ~ 7500 0,1147 U. RSPA 472. 1500 SP -10. IC~~ O.uooo R(;k 127. WF21~ 6562.5~3U ~F4D 6563.541V wF3l~ v ITT O. 11 ] 5 TT~ I ~9~' T T 4 1298.9 o f.; (, ~' 0 J, 0.0 () i; 0 S R ~ '1 (:,. TOD 583~817a TI ~[~: J 429 b IFF 0, o O (¢ 0. T E,: r~ S 215 U. RSPh 313.~000 SP -3I R1L~ ~23.4821 R,161, I C v 0.00 ~ o R ITT O. 1335 :lTl 127~, TT4 1.2a4.{;OOu T 0 10, u u 00 5 TTSL {1. vUO{~ FCk:.L T 0 D 5838890b T I t~: E ! 35 f:. RSPA. 261.75Ov 5~ -2a. k ILr¢~ 222.bOOu RI I..5 212. I.L~ 4,2642 CI.L~: 239. ~CV c, vogu R.Gg 135. ~F4I; 616~ 5156 ITT 0 1554 T'FI 1246. 00 u d A ~1 P L 0 TT4 1251, "O 0 TO ll,U~.OU TTSL (3, OOOu F'C~L u. FEFT TOD 5838958¢,; DI.FF O, v00o TENS 2190. U () 0 O (; 0 t) t') (;o 3768 3750 bUiB ~..~ ~: i:? 5000 h 2 b 0 U{) 5C U 0 5 v 9 {) 00 2~91 (>982 O229 0.0000 -3.~7.2500 2. 445'1 2.6016 125.9375 0,0050 0.0050 066 o 0000 t:, 00~9 0.0 000 ] 1 $. 0 :) 0 CS ~SP ~SFL SFLJ TT3 C~L 2196.0488 9, (,, 9 0 0 -] 37,2500 4.2141 4.1905 .1. 29. 0.0 06i. O.O229 CS NSP RSFb ,J 1"6 U b T b TT3 Chh5 CBS6 0 E P 0 0 u6 O 25O0 ~785 2511 b25(; o 05 (:.. 0 () 50 I;010 {) 0 o o i~89.76,00 ~LTERS 1828.8000 ET£~ 3606.35~9 CS aaR~ O.UO00 RSP 1299,0000 32'1,2500 452,857! 0,0000 ~b61,~248 6562.bb7b 115,7500 1524.0000 0,0566 1285.0000 3O5.750O 2~7.b785 4,23~7 O,O000 0~61,5830 6362,5332 109,0000 149B.000O u. O00O 1~2'1.0000 ¢09.vOUO 4,2153 o~0000 ~!62.5410 0,~547 b. . 123;t, 0000 ii i... 00 d () bWP .010,~{02 ¥~;~i[, l, CA'itO~,~ biSft~,i(; PAGE 7 TOD 5~139031 RSPA 426.75~o ~I[,{~ 353,b714 I L N 2 WF2D b76~.591S ~,F4D 5763 ITT ('). 2'~1 ~ T T 4 1256 T 0 I 1 TOP 5839100'! ) .I [;.' F 0, o 00 o T E h 5 SPA b3B 0 {'~ Ot.~ SP ]LM 2.74bf.~ Cll~u ICV 0. ouuo ~F~D 5562.5752 ~F4b 5563. s332 ~,~ F' 3,c~ ITT O. 2241 TTI TO 1i...OOOt; TTSL O. O()Ou FCSL TOD 58391693 DIFF O, t;i~Ou 427,5000 SP ~SPA ib~ 3,207~ C1!,9 I C V 0, u ,: 00 WF2D 536~. t~t;~t,i ~?.F4t~ 53 ~:~3,5576 0 i C. UO U (t ;vi At{ F; -i6,5900 SPNV )12.5~92 365. 2664 ILO ~, 0.3125 G R 0.0(~5 C, 251. oOi~O TT2 ;;,, 2578 C ~:i 1,, 0.5654 Y~ ETF,.R S ! 7 o 7,8400 ~332,0Jl1 0,0 C 0 {; -337.2b00 2.580~ 2.7371 90. 0. 0050 ,. 0050 102 . 000o 0,0005 o. 107.25OO o. i) 00 c~ 1395.0000 kJ",!' I N ,' t 3.7500 SPF!V 303.9285 /SF!~A ~54. i. R52 I 02. 125u GP 0. ~ 0 i b q' 7' 0. ~"~ 264 D T 170O.aSUO 5025.891f, f,~. - 337. 2500 2.b;~99 2,B234 I (.~'1. i ~75 f'), 00 b {) 0. 0050 I i 03.000 0 0, O000a 1bg5.9200 5711.8672 ., .2 3 , 03 67 3.27 't 2 93, o, 0 6 5 () 0. 0050 5FLU i H V ,[ r 3 CS RSP ;SO1.2499 i,4812 0oO000 59~1.432~ 5962.5752 1~'1.2500 15o8.0000 0,01~1 0,0000 124~,0000 ,i20,7500 404,6428 2,b89~ 0.0000 5"1ol.432~ 5'162.5664 105.2500 1484.0000 0.025. u.O000 1274.0000 ;J2.J,St.)t)O 42o.t785 2.4938 o.0000 5bOl,b99b 5562.5576 11'1.75o0 1572,0000 0,0000 b2UO ~OOC ti! 158~, 9600 1335. (~C, 0i? Eq' 1 b b402. 8604 1 155. C'Ou u PARK O. (.)000 -23.2500 SP~,t V -337.2500 1 ~, 75(,)U S~: LA 4,2964 2! '~.q8,t4 i].C 4.6623 ~J2.UOuo G[< 90.7bO(.) n 0050 ,,.gO50 v~'f 4~,. U.OU50 121~3. 000<: '1'5' 2 !004.5000 !,74b! :). 5908 1"~ O. 000(> u. C: 054 ** FILF TRt~II,:ER SEPVICF ~; a :,'~ E; :LOG vERSIOn4 ~ :3u.~ DATE: :88103/09 ~'II..,E TYPE :PR D~EXT FILE ~;A~E ; DATE :88/0,~Iu7 REEL ~,; A. H E :156794 CONTINUATION n :01 PREVIOUS RE:EL : CO~ME:NTS :SCH~,U~SER(;ER Sf~:Rv'[CE, 5 CS~ ."JAPE C3Lb :j 49a-. 0000 u. U249 O, 00 00 1347 , OOOO 31~.0000 25:1,571~ g,1379 U,OOOO 5161,591~ 5162. 5410 i0o. 1435,0000 ~.U239 0, OOO0 *'* TAPE:. HEADER SERVICE N A ~,~ ~': : FDOBH, C D~TE 188103/{)7 D IGIN :CSU 1, : 15 TAP NAt4E PREVIOUS TAPE C{}~ ~EN3' S :8CHLdH~3EHGKR DATA Ei,~TRY 2 3 4: 5 7 13 16 o SERVICE AP1 bOG u 7 o 7 07 o 7 07 (., '1 0 ? 07 07 O7 07 o 7 0 7 07 9 '7 {} 7 o7 Si, Z .A T¥ 0 6 KF:[ A CU[)E 66 79 66 73 65 73 o5 66 65 6~ .:56 0 0 4226 1 t IFICH o 0 1 l 7] 1 0 Pi AP1 AP1 FILE S]ZE n 0 00 o 1 6 4 36 21 0 ].b 2 36 2j 0 16 ~4 36 21 t) 1 o ~ 35 21 0 16 2 150 Ol 0 10 2 o I 0 0 1 0 16 2 (.)IH Ui 0 I o 2 01 u 01 0 15 2 010 Ol o 16 2 22O Ol 0 I6 ~ !, 20 44 0 16 g 120 46 0 lb 4 222 U~ (~ I~ 4 ~2(~ u1 0 lb 4 12. u 44 0 1 o 4 110 a6 u 16 4 l 2 u 46 0 I 6 4 2 ~ 2 u ], n 16 2 SP 1 49 I 49 t 68 1 1 1 10400000000u00 1ooo7oo04o0ooo t. 00 O 000 O 4 O 00 O O lO 000 U 0 U 40 t, 0 v .) lO00('~O00 '40u0' 0{. 10700UOuC)O0000 I0200UgUO00000 10200000000000 10600000000000 10000UO0000OOo 49 q9 I {)2U OC~UOOOO(~O0 4,9 10U00(}004:000 O~ 5~2 520 522 522 522 524 524 522 522 524 520 ** DATA FOR~-,~A7 RECORD ENTRY BLUCKS TYPE 1 2 3 7 13 15 I 2 1 4 1 1 ! 1 b J5 J6 lo 16 COOE 79 b b 73 2 1024 t024 lU24 ! a24 4 ,4, 4 4 2 2 2 2 2 2 2 2 2 2 2 2 4226 30 .ilN 1 1 .lin 1 1 CS DiFF RSP SP RSFt, RiLN SFL~ 8 F L u I C I L D wF 1 ~FI D ~P2O ~F1N ~F2N wF4 WF,4D rT2 AMPL CSL C {~ L 5 TO ~AT TT C6Sb TTSb ~CSL OT f;' b 7 i 'o u 0 4 V 0 '1 (l l 0 0 1 0 ;: v ,J '1 U t ;2 0 i O ::, v 9 7 0 i U 0 l "-) ~..'V O 7 t, ,t ,,) u ! 0 ,x ~ ~ H (} 0 '1 220 01 n ,~ ,';~ ~; 07 120 4e 0 t, r, ,,': :,: t: 7 222 0 i 0 U h (, 7 22 b 01 0 F 3 u7 282 ul 0 F 3 u 'l 282 u 1. 0 g A P i 0 'l 3 .t 0 F 07 5~1 O1 0 f' 0 'l 581 02 0 0 I 5~2 01 0 07 582 02 07 SRO 04 F 07 581 o3 0 F 0 '7 5 81 0 ~ 0 o7 5~2 {)3 0 07 582 04 0 IJS / F" ()7 520 ~ 1 0 U ::3 o 7 522 B 3 u8 07 522 ~3 0 iJS 07 522 d3 0 U 8 ~) 7 5 22 83 0 ?~V 07 522 85 0 '~'! 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S 07 $ 22 CBSL PDBHC ;,,,. ~ 07 524 86 0 F C b t, r) D b H C v~ ~ u 7 524 86 0 19 l; T r, ', ,., [, E~ H C (, b / F t.; '1 5" 0 ~:t~'I' R Y BLL,;CK b T ~ ~'.' ¢:; SIZE ~,.l l'k CODE ~ ,! 2 ~ 3 2 79 b i 6 4 73 'l 4 ~ 5 8 4 '73 9 ~ 6 5 t 3 " 1. ~ ~r ~5 15 ~ ].b I 66 o ! 6 ~ DATU¢ SFECi F I C A'i'iot'.~ I~E~ ,.%"~;f4VlCS; SERVICE Ut'~l'.[ APl Apl t¢~F'I API FIt.,E ID OROEiR ~ 1.,fJ)G T~F[:: C.bAS¢~, WOk) T O O D P B B C 5 07 00 u o O 0 19 TI.~E t>DB~C kS 07 b3~'~ 21 o E'l'I ~ DDBHC 8 u7 ~36 21 O t9 CS TsDB~C Fi~4R o~ 63b 21 0 BIFF DDBBC E 07 ~, 36 21 0 19 MAR~ DDBgC F 07 ] 5o 01 0 19 RSP {)DBHC ~. V 07 () 1. o u 1. 0 19 :R S P h D D B ~ C ~.: v 0 7 () 1, U 01 .O 1. 9 SP I') i) i:~ H C ~::V 07 Olu UI 0 SP~iV DDtSaC t~'lV 07 010 OI 0 19 S F L A D D 8 H C i; H :-¢~ ~"~ ,, 7 222 t ~ l (-~ :t 9 F Lt.,I i>Di?~H C C r'~ :: :~;07 22(: i.> l 0 i9 2 I .9 2 i q. 9 2 I 49 2 t 49 2 1 49 2 i 49 2 i 49 2 i 49 2 1 49 2 I 0,9 0 0 422~ 1 3 u I ,ll.a 73 t SiZE SPb REPR CODE 4 I 73 2 i 49 4 1 68 2 I 49 2 t 49 2 I 49 2 I 49 2 't 49 2 1 2 I 49 4 t 68 q ] 68 4 I 4 ! 6 a IHV ICY ~~F2 WFlg ~ F 3 H ~,~ F4 D '~ F 3 N DTL TTI TT~ TT3 TT4 A~PL C aL TO BRAT TT CBS b TTSb FCBL DT TOD DIFF RSPA Wl~ 2O AMPL SRAT I>Di~HC F S C7 2a~, DOHNC GAP! 07 3~t~ Ol !ii)bbC GAPt 07 31u f3 D B H C 07 5 ~ V 52 Obb~;C u'l 5~ u 0 1 DDGHC [' {j7 5~ 1 0 ] t? O a H C ~' () 'l b H 1 02 CDBHC U7 58~ DD~HC u7 5H2 02 DD[~IiC U7 5HO 03 DDB~C F 07 5~1 0 D a h C F 07 5 ~ 1 04 DDBHC 07 5~f2 0 D L) B H C o 7 5 ~ 2 () 4 !)DBHC US/F u7 570 DbtJ~C b~ u7 5~2 ODI.~HC t~S 07 522 L)I]BHC b:j 07 522 83 DOBHC uS u7 522 83 DDBHC i~,V u7 522 ~5 DDBHC ~.'V U7 524 86 t)DBt'{C r~% 07 524 Di)BHC ~ v 07 524 32 DD~::~HC 07 5aU DDBHC US O7 522 83 DDB}.t C US o7 522 H D D B fi C h V U 7 52,1 ~.,{ 6 DDBHC US/F u7 52f) I U00U U O~,)OU000 102 (.> 0 () (, O 00 u 0 00 1. OZOUUOUOUOOuu i UOOOC~004OOOU0 1 O2oouuoouoouo 11000000000000 11 uuOuOuoo000O I ~ O00OO0OO0000 11 uoOOOOOOOoo0 11000O0U000000 110UOUOO:}OOO(,U 1 1 11 0 O (> i.) 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OB ~ 1 68 4 I 68 4 1 b8 2 I 49 2 I ~9 2 I 49 2 t 49 1024 t 79 102~ I 1~ ~ 1 68 4 I 68 4 1 68 I02~ i 79 !,024 I 79 4 I 08 4 I o~ 4 1 68 2 I 49 2 1 49 2 I 49 2 I ~9 2 1 49 2 1 49 2 i 49 2 1. ~9 2 1 49 2 L 49 2 I 49 2 t 49 2 I 49 2 1 49 2 I 49 (.OCTAL:) lOlOOOuOOOOuuO 1 OO00GOOO000OO 1UOUOdOOO00000 10100uoOOO00OO lOOUOOOv400000 luOOOUObO00000 l OOOO00L~O00000 10000uOu400000 lOOUOOO(~qO0000 10400000000000 IOOUOUOU~O0000 1000OOOU4, 00000 10000009400000 1000t)O00400000 1070uuOOOOO000 10200000000000 1020o009000000 I O~OOOOOoO0000 10000000o00000 10200000000000 102o00000o0000 100o0000400000 1 o20o000000000 1 lOuOOOUO00000 ! 1000uOOO00000 1 100000000000o I IOOVOO000OOO0 llOOuO00000000 1, 10UOO()uO00gOO t 1000000000000 l 1 oOooO0000000 I 1000000000000 I 00000000( 000 1,,, 000000000000 1, 1 O0 O00uO00000 lO000OO0000000 .100o0000000000 I0000000000000 fO0000 '-~ O U . 900000 020 000000 () 000 10gO(>oouO00OO0 i OOOOOOOO00000 I OOO 1000()000000000 lOOOOu[lOOO0000 i 00 u O09 t) () t~ 0000 I O00t)OOOOOOO00 10000ot)O000000 10lO000OoO0000 ICE u :',; I '1 AP1 ~Pi AFl AFl FILE S!Z~; SPh REPR [.,(.~G TYPE Ci,ASb hOD t'~iO, CODE 07 000 C 0 0 21 4 I 73 07 636 21 0 21 2 1 49 u7 630 21 0 21 4 I 68 o7 636 21 0 Zl 2 I 49 07 636 21 0 21 4 I 68 07 635 21 0 21 2 1 49 07 I 50 o i u 21 2 1 49 07 o i G () 1 0 21 2 1 49 07 010 01 0 21 2 I 49 07 0!~ O1 0 21 2 I i9 07 o I 0 O 1 0 21 2 I 49 0 '1 22 t; (~ 1 0 21 4: I 6 6 0'7 120 44 0 21 4 t. 68 o '? 1, 2 (, 45 ti 21 4, I 68 u 7 222 u 1. 0 21 4, I 68 o 7 2 2 0 t; 1 0 2 1 4 1 68 0 '1 12 (} 44 0 21 4 I 68 o '1 i 1 o 4 b 0 21 4 I b 8 O7 120 4e, 0 2 t. 4 i 68 07 2a2 Oi 0 2i 2 I q9 07 2!i2 O1 0 21 2 I 49 07 310 ~, 0 21 2 I 49 07 31 () Ol O 21 '2 1 49 () 7 5 & 0 u 2 0 21 i ~:~ 24 i 79 07 58t t)l, 0 21 lo24 I 79 07 5~; t v1 3 2t 4 I bE4 07 5kl 02 0 21 ~ I 6~ O 'l 5 a 2 o 1 0 21 4 1, 6 8 07 5~'2 o2 u 2l 4 1 68 () '7 5 ~ V 04 0 21 1 t 24 t. 79 o7 580 ()3 0 21 1024 I 79 (nCTAL) 10100o00000000 lOOOOOOvOOoO00 10000000000000 1 O 1GOOOUOOO000 10000000400000 I O000UOu~uoOUO 1. 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